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Home My WebLink About212-196 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: Schlumberger Wireline Backlog – Exploration DATE: 12/19/2023 Transmitted: North Slope, Exploration Via hard drive data drop Exploratory Cassin 6 50-103-20666-00 212196_CASSIN- 6_IBP_11Mar2022 DLIS LAS PDF 1 of 1 Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 PTD: 212-196 T38307 2/29/2024Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:52:55 -09'00' D:HOO6WDWXV2LO 63/8* 2WKHU $EDQGRQHG 6XVSHQGHG E:HOO&ODVV $$& $$&'HYHORSPHQW ([SORUDWRU\ *,1- :,1- :'63/1RRI&RPSOHWLRQVBBBBBBBBBBBBBBBBBBB 6HUYLFH 6WUDWLJUDSKLF7HVW 2SHUDWRU1DPH'DWH&RPS6XVSRU 3HUPLWWR'ULOO1XPEHU6XQGU\ $EDQG $GGUHVV'DWH6SXGGHG $3,1XPEHU D/RFDWLRQRI:HOO*RYHUQPHQWDO6HFWLRQ'DWH7'5HDFKHG :HOO1DPHDQG1XPEHU 6XUIDFH 7RSRI3URGXFWLYH,QWHUYDO)LHOG3RROV */ %) 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" # $%& "' (() ' * + ((), +' -.- . . . /./ +.+012 $" 3 .456$ 4.4 .&.,72&$ .$$ * .2 - 8 +.+012 $ 3 "."!$# 6$ 0 " ,'9: ;(0<6 = '' 0 ;; 2>6 ( 80 $ - 8*2' $21'+/663?- 2@81()3 !" # # $$ $%& % '() !##A %#*?'+/66 $ A %#*? 0% A %#*$0 8$A %#* 41,* 2;B3 6 = $13: : 2022-0316_Surface_Abandon_Cassin-6_ll Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:3/16/2022 P. I. Supervisor FROM:Lou Laubenstein SUBJECT:Surface Abandon Petroleum Inspector Cassin #6 ConocoPhillips Alaska Inc PTD 2121960; Sundry 321-328 3/16/2022:I traveled to the Cassin #6 well and met with CPA representative Phil Rafferty for the wellhead cut-off inspection. CPA had constructed a temporary ice pad for the work. The wellhead had been cutoff and casing stub was deeper than the 3-foot minimum depth. Cement depths were as follows: - conductor had cement to surface; - outer annulus (casing-casing) had a void of 37 feet; - inner annulus (tubing-casing)had a void of 10 feet, and - tubing was cemented to surface. The area was clear of any evidence of spillage or leaks. CPA will contact AOGCC to witness cement tops and installation of the abandonment marker plate after completing remedial cementing. Attachment:Photo 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.03.24 20:34:51 -08'00' 2022-0316_Surface_Abandon_Cassin-6_ll Page 2 of 2 Surface Abandonment – Cassin #6 (PTD 2121960) Photo by AOGCC Inspector L. Laubenstein 3/16/2022 5HJJ-DPHV%2*& )URP$SSOHKDQV$DURQ)DLUZHDWKHU//&$DURQ$SSOHKDQV#FRQWUDFWRUFRQRFRSKLOOLSVFRP! 6HQW)ULGD\0DUFK30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*&:DOODFH&KULV'2*& &F:LHVH7\VRQ0&RQNOLQ$P\$ 6XEMHFW5(&0,77HVW5HSRUW $WWDFKPHQWV&DVVLQ3RVWFHPHQW[OV[ 'ŽŽĚĂĨƚĞƌŶŽŽŶ͕ /ĞŶƚĞƌĞĚƚŚĞǁƌŽŶŐĞŶĚŝŶŐƉƌĞƐƐƵƌĞƐĨŽƌƚŚĞKŽŶƚŚĞϭϬͲϰϮϲ͘,ĞƌĞŝƐƚŚĞĐŽƌƌĞĐƚĞĚŽŶĞ͘^ŽƌƌǇĨŽƌƚŚĞŝŶĐŽŶǀĞŶŝĞŶĐĞ͘ dŚĂŶŬǇŽƵ͕ ĂƌŽŶƉƉůĞŚĂŶƐ ƌŝůůŝŶŐͬtĞůůƐ^ƵƉĞƌǀŝƐŽƌ ϵϬϳͲϵϴϮͲϭϳϵϬ ƉƉůĞŚĂΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &ƌŽŵ͗ƉƉůĞŚĂŶƐ͕ĂƌŽŶ;&ĂŝƌǁĞĂƚŚĞƌ͕>>Ϳ ^ĞŶƚ͗&ƌŝĚĂǇ͕DĂƌĐŚϭϭ͕ϮϬϮϮϭϭ͗ϰϱD dŽ͗ũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀ͖K'͘/ŶƐƉĞĐƚŽƌƐΛĂůĂƐŬĂ͘ŐŽǀ͖ƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀ͖ĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀ Đ͗tŝĞƐĞ͕dǇƐŽŶDфdǇƐŽŶ͘D͘tŝĞƐĞΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖ŽŶŬůŝŶ͕ŵǇфŵǇ͘͘ŽŶŬůŝŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ͲD/ddĞƐƚZĞƉŽƌƚ 'ŽŽĚĂĨƚĞƌŶŽŽŶ͕ ,ĞƌĞŝƐƚŚĞϭϬͲϰϮϲƉŽƐƚ/WǁŝƚŚϮďďůƐĐĞŵĞŶƚŽŶƚŽƉͲD/dƚĞƐƚ͘,ĂǀĞĂŐƌĞĂƚǁĞĞŬĞŶĚ͘ dŚĂŶŬǇŽƵ͕ ĂƌŽŶƉƉůĞŚĂŶƐ ƌŝůůŝŶŐͬtĞůůƐ^ƵƉĞƌǀŝƐŽƌ ϵϬϳͲϵϴϮͲϭϳϵϬ ƉƉůĞŚĂΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH &DVVLQ 37' -5HJJ ĐŽƌƌĞĐƚĞĚŽŶĞ͘ 37' Submit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 212-196 Type Inj N Tubing 0 2000 1925 1925 Type Test P Packer TVD NA BBL Pump 1.6 IA 0 2000 1950 1950 Interval O Test psi 2000 BBL Return 1.3 OA 0 0 0 0 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al In t eg r i t y Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov ConocoPhillips NPRA Exploration/Bear Tooth Unit Cassin #6 Aaron Applehans 03/11/22 Notes:Sundry 321-328 C-MIT post IBP with 2 bbls cement on top. Witness waived by Austin Mcleod (AOGCC); Witnessed by Quinn Sawyer (BLM) Cassin #6 Form 10-426 (Revised 01/2017)2022-0311_Plug_Verification_Cassin-6 9 9 9 9 -5HJJ03/11/22 Sundry 321-328 C-MIT ! " # $! % " &&&&&&&&&&&&&&&&&&& '$("" )*$ +,*# - #./$ 0/ 1$$ " ## ! 2 ,2 3 $ 4* 56 $7895 7 * :*5 7 * ;*5 7 + #* :* + #* ;* :5 7 5:*7<=5:*7 .'8->$$+ " / 6 = ;= ;:*5 7;*5 7 ' -" != * ?= +, *# # (+ * ) != " /6 /$<*6 .;#*@@ @ 6A@ " #@/$< ! "$ "+ " * " #$ " #! $ /? : / 6" //B:/ >23 $ +, 23 $ ;+*?3 # ":://$+ C+":://$ * " " + @ + /# + ! D 54807'.)%.84- E 0/ # ! # ! !# E $$+ ..1> -99'8'' -%9'FG =$$+ ;$$+ @ ''10> .4-> * :*5 7 81> '-(> .4'>0F .F 4%)91F 18> 6%18 '--.> $9 $ +,9? A .'8-> +6G 6G/6$*@"$+ ;/$":://$ '8"')'18 %84.0) .'8-> !"!#"$ ?,88-.8H H =44)8 %&#"&'#!&#&&#&& " =H/ * ;*5 7 E .'8-> $$+ (()( * + 81> '-(> ( E$ :*5 7 $$+ =$9 ;$9 8%(8- # -9'8'8 , - .,-/"!0*/0* - / ,1 By Samantha Carlisle at 1:10 pm, Jul 01, 2021 321-328 Tyson Wiese Digitally signed by Tyson Wiese Date: 2021.07.01 12:48:03 -08'00' AA-081833 X XX 10-407 AOGCC inspection is required after cutoff and before any remedial cementing. SFD 7/1/2021 SFD 7/7/2021 DSR-7/1/21VTL 8/4/21 dts 8/5/2021 JLC 8/5/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.05 12:29:00 -08'00' RBDMS HEW 8/6/2021 !!" # $ %& '(&&) && ) && % ( *+,%-#*$ .!+ %'*$".. +++../ 0 1 *+0& ( & 1-00 ( 0 &1-2 0 &) 1-00 0 34)5& 1 06%701*+ (& ( ) 81 ) 9 4:+ 1.9,/0);2<5 & ( 1# )0 0( 0 ) %&& & 1 -& & %=& 0 )0&& ) & & && ))%= & 1 00< )&& > " ) 1 $ % & % ( % & ') < <)) & !. +".+!, ))/ !. ."88,/1 - ))? & & & & 00< )&& > " ) 1) & -2 0 &) 1 !" # !"#"$!%&'())) ' *+ '',' -.,.'/+$/0!'1/(2))03' 4'' .5 $%&'( !6'7/)+!'' 6'78" '! '9 # :" & -" ' ' 64' '.5 !) &*+,#-+./ %& !"#$"%& ''(%(' !6'7 4 /0/;< = ' ' '7!9 /(-/03' () *+ -.5,)--"-) ."')$'$")(%/(' !-00 ,!'0)'''1(!6'7 4 ' <"59 *+ > 7 ' !"#"$!%&<'())) ' $%&'( !6'7/)+!'' 6'78" '! '9 2 # $*/046 7& !) &-1,#-+./ %& !6'7 4 )0/;< = ' ' '7!9 (-;*03' () ?5274<" "'<-67?5 2 345678 ' ''75% 6'7 746@ /)446 6 ' 4)447 ? 7 /44A? )44 '/*< ' ' )44/*< ' '6'7<8444 -/44 '/*< ' ' 6 ' ')44' ''' '5%74 6 -7' .6 ' 7' 5% : : ?52;7 2-) 5%.."#BA"&?'7 .."6 444 '5%' 5%"5 : '7'' '" 4: !*00 !6'7 4 ' <"59 !"#$%#&"!'()*%"+,%%"-./0 1"",02'"#1,","!0#3 !"#"$!%&<'())) ' - )446 '4 ' ' '7!%' ' '7<2 '4"$!%'C ''!% 2 940:% #8 ' ''7"4 (6'77 ' '' !%' '' A6'7 746@ /44A? 7 4;/44 '/*< ' ' - ' ' ' ' ' '/*<' ''7' 2.5?52;7 ,' D% 2 #:; 0< = &# / !"#'''")#3' > :,' 7 '' 67 : ' -.."0' 8'4 ) >0 6 67 : ' '4 ' 2' $ : '': 4$ '>$ : ' ' '/0 46 : ' '767 ' /'8:67 ' '-046 : E '' F4 '4 "5' ' *? ' 8;+6 7 ' ;. ' ' ? D% '6'7 7' 7 G $ : ' 6'7 : : ' ' )54' ' > : ' '.5 ,$$-4$5)-60 + +1 #$$' ''&7 (86 !*7 5&6+!+ ! +777!++!++ AOGCC inspection is required after cutoff and before any remedial cementing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ast Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CASSIN 6 osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Exploration New Well (tight hole) 4/23/2013 CASSIN 6 osborl Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 27.4 Set Depth (ftKB) 2,313.9 Set Depth (TVD) … 2,313.4 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description PRODUCTION 26#/29# OD (in) 7 ID (in) 6.28 Top (ftKB) 24.8 Set Depth (ftKB) 6,193.0 Set Depth (TVD) … 6,192.0 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-M Tubing Strings Tubing Description TUBING Kill String String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 24.6 Set Depth (ft… 2,336.0 Set Depth (TVD) (… 2,335.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.6 24.6 0.00 HANGER FMC TUBING HANGER 3.500 2,334.7 2,334.2 0.96 WLEG WIRELINE ENTRY GUIDE 2.992 Notes: General & Safety End Date Annotation 4/22/2013 NOTE: WELL SUSPENDED WITH KILL STRING ***NO PERFORATIONS*** VERTICAL, CASSIN 6, 6/30/2021 5:34:18 PM Vertical schematic (actual) PRODUCTION 26#/29#; 24.8- 6,193.0 SURFACE; 27.4-2,313.9 CONDUCTOR; 28.0-108.0 NAK EXPLOR KB-Grd (ft) 0.15 Rig Release Date 4/26/2013 CASSIN 6 ... TD Act Btm (ftKB) 6,203.0 Well Attributes Field Name Wellbore API/UWI 501032066600 Wellbore Status EXPLOR Max Angle & MD Incl (°) 1.44 MD (ftKB) 407.60 WELLNAME WELLBORECASSIN 6 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: From:Wiese, Tyson M To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]Cassin #6 P&A Proposal - No Perforations (PTD 212-196) Date:Wednesday, May 26, 2021 10:45:22 AM Victoria, Thank you for the feedback and alternative proposal. I’ll review the option. The challenging piece will be dump bailing 25’ of cement with limited bailer volumes through the Kill String, so I need to make some phone calls to see if we can locate larger or longer bailer systems. Thanks, Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. Desk Phone (907)-265-6093 Cell Phone (907)-230-5388 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, May 26, 2021 9:27 AM To: Wiese, Tyson M <Tyson.M.Wiese@conocophillips.com> Subject: [EXTERNAL]Cassin #6 P&A Proposal - No Perforations (PTD 212-196) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Tyson, While the regulations do not specifically address this situation, the Commission proposes the following changes to the procedure: 1. Place an IBP with 25’ of dump bailed cement at the Cassin reservoir top. State witnessed pressure test and tag. 2. Place another IBP at ~ surface casing shoe and fullbore TxIA cement plug to surface Thanx, Victoria From: Wiese, Tyson M <Tyson.M.Wiese@conocophillips.com> Sent: Thursday, May 13, 2021 2:18 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Cassin #6 P&A Proposal - No Perforations Victoria, I am drafting up a few P&A programs for the 2022 Winter season. One of the wells under consideration for P&A is Cassin #6. It is not often that we work on wells that have not been perforated so I wanted to run this proposal by you. Many of the cased hole plugging regulations are written assuming perforations exist. In this case the well was drilled and logged but the 7" production casing was never perforated. Based on the plugging regulations and requirements I believe the proposed P&A complies. The fluid below the IBP is 10.0 ppg Corrosion Inhibited KWF brine. Can you review and confirm if this is an acceptable P&A option for Cassin #6? Thanks, Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. Desk Phone (907)-265-6093 Cell Phone (907)-230-5388 From:Wiese, Tyson M To:Loepp, Victoria T (OGC) Subject:Cassin #6 P&A Proposal - No Perforations Date:Thursday, May 13, 2021 2:18:06 PM Attachments:Cassin 6 Proposed P&A Summary DRAFT tmw 5-13-2021.pdf Cassin 6 Proposed P&A Schematic DRAFT tmw 5-13-2021.pdf Victoria, I am drafting up a few P&A programs for the 2022 Winter season. One of the wells under consideration for P&A is Cassin #6. It is not often that we work on wells that have not been perforated so I wanted to run this proposal by you. Many of the cased hole plugging regulations are written assuming perforations exist. In this case the well was drilled and logged but the 7" production casing was never perforated. Based on the plugging regulations and requirements I believe the proposed P&A complies. The fluid below the IBP is 10.0 ppg Corrosion Inhibited KWF brine. Can you review and confirm if this is an acceptable P&A option for Cassin #6? Thanks, Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. Desk Phone (907)-265-6093 Cell Phone (907)-230-5388 Post Office Box 100360 Anchorage, Alaska 99510-0360 Proposed Cassin #6 P&A Summary: Slickline / LRS: – Well Prep for P&A: 1. Pull BPV and VR plugs. Hold PJSM. RU Slickline and LRS pump. 2. Perform C-MIT (TxIA) to 3,000 psi to confirm 7” casing integrity. Record Results. 3. Dummy Drift for 2.5” x 15’ IBP to ≈ 2,450’ KB to ensure no obstructions. RDMO. E-line – Set IBP in 7” Casing: 1. RIH with 2.50” IBP toolstring with Press/Temp sondes. 2. Set IBP mid-element @ approx. 2,414’ KB (100’ below Surface Casing Shoe) 3. Perform Press/Temp log to surface to confirm wellbore temperatures. RDMO. Slickline / LRS: – Dump Bail 25’ of 15.8# Cement on IBP: 1. RIH with 2.50” dump bailer (1.90 gallons per run) and dump 15.8# Class G cement on top of the IBP @ 2,414’ KB to a planned TOC of 2,389’ KB. Note: Estimate 20 runs in 2 days to achieve 25’ column of cement on top of IBP. 2. RDMO. WOC for 48 hours and notify AOGCC/BLM to witness Plug #1 Tag and Test. Slickline / LRS: – Plug #1 Tag and Pressure Test: 1. With AOGCC Inspector on-site to witness, RIH with sample bailer and tag Plug #1 TOC @ approx. 2,389’ KB. Ensure a hard tag and inspect bailer sample at surface. 2. C-MIT (TxIA) Plug #1 to 2,000 psi. Record Results. RDMO. Ready for Plug #2. Post Office Box 100360 Anchorage, Alaska 99510-0360 Fullbore – OA down squeeze (Plug #2): 1. RU Cement Pump to the OA and follow the pump schedule below: a. 50 bbls warm Seawater b. 10 bbls Chemical Wash c. 5 bbls FW spacer d. 10 bbls neat 15.7# permafrost cement e. 20 bbls 15.7# permafrost cement with 2#/bbl fiber LCM. f. 36 bbls neat 15.7# permafrost cement Note: 9 5/8” x 7” OA Volume to SC Shoe = 66 bbls. 2. Slow pump rate during last 20 bbls to min rate to mitigate OA shoe breakdown. 3. Shut-Down Cement Pumps. Shut-in OA casing valve and WOC for 48 hours. 4. Perform 30-min OA DDT (NFT). With a passing DDT lower plumb bob into OA to confirm OA TOC. Measure void depth to estimate Top Job volume if needed. Fullbore – T x IA Cement Plug to Surface (Plug #3): 1. RU Cement Pump to the Tubing, with hardline setup to take IA returns to tanks. 2. Follow the pump schedule below: a. 5 bbls FW spacer ahead b. 85 bbls neat 15.7# permafrost cement i. 2 bbls in 7” casing, 62 bbls in IA, and 21 bbls in Tubing) 3. Continue to pump cement until consistent 15.7# returns are measured at the tank. 4. RDMO. WOC for 48 hours. Ready to for Surface P&A. Post Office Box 100360 Anchorage, Alaska 99510-0360 Final Surface P&A – Excavate / Top Job / Marker Plate / Backfill: 1. Provide the AOGCC/BLM with a 72-hour notice to witness surface P&A operations. 2. Ensure survey team has documented tundra and wellhead elevations. 3. Perform DDT’s to confirm all casing/tubing pressures read 0 psi and LEL’s allow for wellhead removal steps to be completed. 4. Use trimmer and excavator to remove cellar box and plate. Excavate at least 5’ below original ground level in preparation for the wellhead cut. 5. Cut/Remove wellhead at least 3’ below original ground level. 6. Perform cement top job if needed to bring TOC to surface in all strings. 7. Weld on marker plate and drill an 1/8” weep hole as per BLM regulations. 8. Document all steps in WSR and a final surface P&A report with photographs. 9. Backfill excavation with approved gravel and original tundra material. 10. Obtain final site clearance from Environmental Coordinator. RDMO. Post Office Box 100360 Anchorage, Alaska 99510-0360 Current Cassin #6 Schematic: Post Office Box 100360 Anchorage, Alaska 99510-0360 Proposed Cassin #6 P&A Schematic: Cassin #6 Proposed P&A Schematic PTD: 212-196 Conductor: 16" Conductor 108' KB/TVD Surface Cement: 170 bbls 10.7# Arctic LiteCRETE Lead (160 bbls back to surface) 125 bbls of 11.1# Arctic LiteCRETE Lead 72 bbls of 15.8# Class G Tail Item Depth - tops (KB) 1 3-1/2" FMC Tubing Hanger (w/ BPV)25' 2 3 1/2" 9.3# L-80 Tubing 2,335' 3 WLEG 2,337' Base of Permafrost: 1,100' KB/TVD (from geo logs) Production Casing Cement: 51 bbls of 15.8# Class G Production Casing TOC @ 4,606' > 500' above Cassin Reservoir (4/21/2013 CAST/CBL) 1 Production Casing: 7" 26# L-80 BTC-Mod to 4,703' KB/TVD 7" 29# L-80 BTC-Mod to 6,193' KB/TVD Surface Casing: 9-5/8", 40#, L-80, BTC Set @ 2,314’ KB / TVD Shoe LOT = 13.5 ppg Kill String: 3 ½”, 9.3# L-80, EUE 8RD R2 @ 2,337' KB 2 3 Cassin Reservoir Top = 5,315' KWF and Cement Plugs: KWF:10.0 ppg Corr. Inh. Brine (primary cement job displacement fluid) Plug #1:Inflatable Bridge Plug with 25' of 15.8# Class G Cement 7" 26# Casing Capacity = 0.03826 bbl/ft Plug #2:OA Downsqueeze. 65 bbls of permafrost cement to SC Shoe 9 5/8" x 7" Casing Capacity = 0.02823 bbl/ft. Plug #3: Fullbore TxIA to surface. 82 bbl of permafrost cement. 7" 26# Casing x 3 1/2" 9.3# Tbg Capacity = 0.02636 bbl/ft. 3 1/2" 9.3# Tbg Capacity = 0.008696 bbl/ft. Wellbore Temp/Pressure Information: Plug #1 Temp = 60 deg F / Pressure = 1,000 Plug #2 Temp = 59 F / Pressure = 1,900 psi (Rig LOT = 13.5#) Plug #3 Temp = 60 deg F (bottom) / 20 deg F (top) Pressure = 1,900 psi (bottom) / Surface TMW 5/13/2021 Plug #1 TOC @ 2,389' KB No Perforations in Production Casing 4/21/2013: PT’d on-rig to 3,500 psi ! 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" !# $ %#&' &# ( & )*)*+*,+)*--./*0 12 #13 /!,!* By Jody Colombie at 8:29 am, Jul 21, 2020 SFD 3/16/2021 VTL 5/5/21 RBDMS HEW 7/21/2020 -00 SFD 3/16/2021DSR-7/21/2020 !"# $% "&$ '((() &$* & (+ ! , ( - . / 0 10 !2* ". 0, . , 3, %., . , *&$ &4$ & $ $.$.5 .5 & $ &$* 6$ # , ,$ 5 $ . 5$, /% ,.$ %5 (#,.,, ., , $$ ., $ $ $ * $ &$$ . $ $ " 5&, 5 &2 ,.,2 # ,$$ .,7 , 6$ # , ,,5(#$ .5,%5 )#,.,, .,, ,// 5 ! ,,,$7*2 ,$., . 8 ,7 5 5$ &7 $ ,9$ %/$ 7 -: ,$/% %%5$,$,% . 7 . !$% .$ . $% .#%5$% .,34 7 $$$%5 and OA have VR plugs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laska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Mr. Shon Robinson Alaska Wells Manager PO Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-20-057 ConocoPhillips Alaska, Inc. (CPAI) Well Plug and Abandonments for 2021 and 2022 Ice Road Seasons Dear Mr. Robinson, By letter dated November 23, 2020, CPAI proposed well plug and abandonment (P&A) programs for the 2021 and 2022 ice road seasons. The Alaska Oil and Gas Conservation Commission (AOGCC) approves the P&A programs for the wells listed below for the 2021 and 2022 ice road seasons with the P&A work to be completed by May 31, 2021 and May 31, 2022 respectively. May 31, 2021 Lookout 1 (PTD 201-003) KRU 1M-17 (PTD 201-230) Kuparuk 28241-1 (PTD 181-035) May 31, 2022 Scout 1 (PTD 204-006) Cassin 1 (PTD 212-182) Cassin 6 (PTD 212-196) Wells KRU 1M-17 and Kuparuk 28241-1 each require the submission and approval of an Application for Sundry Approvals for suspension renewal in January 2021. Approval of an Application for Sundry Approvals will be required for plugging and abandonment operations for each well. Approval is also granted for the deferral of the Scout 1 suspended well inspection to May 31, 2022. If you have any questions please contact Victoria Loepp at (907)793-1247 or at victoria.loepp@alaska.gov. Sincerely, Jeremy M. Price Chair, Commissioner cc Victoria Loepp, AOGCC JMPi Dear Commissioner Price, Due to low oil prices, budget constraints, and a need to minimize nonessential remote work considering spiking COVID-19 cases statewide, Conocophillips Alaska, Inc. is revising our winter 2021 ice road scope of work. Our initial plan was to execute the following P&A’s: x Lookout 1 x Scout 1 x Cassin 1 x Cassin 6 As has been discussed with AOGCC staff, we now propose to perform the following P&A’s instead, staying closer to infrastructure, in 2021: x Lookout 1 x 1M-17 x Well 28243-1 (for Exxon) With that change, we expect to perform the following P&A’s in 2022: x Scout 1 x Cassin 1 x Cassin 6 The Scout 1 well is overdue for its 5-year suspended well inspection under 20 AAC 25.110(e) because of last year’s early ice road exit due to measures taken to project against the COVID-19 pandemic. We do not believe that deferral of inspection until 2022 would present a safety or environmental risk. For the reasons described above, we seek modification of the inspection deadline for this well to May 31, 2022, as allowed under 20 AAC 25.110(n). Thank you for your consideration, Sincerely, Shon Robinson Manager, AK Wells Shon Robinson Alaska Wells Manager 700 G Street, ATO (99501) P. O. Box 100360 Anchorage, AK 99510-0360 Phone (907)-265-6306 STATE OF ALASKA ALA.,,.A OIL AND GAS CONSERVATION COMMio ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate E Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other Stimulate Alter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspend Well Inspect FoT 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory ' 212-196 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20666-00 7.Property Designation(Lease Number): 8.Well Name and Number: FED AA 081833 Cassin 6 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s). Wildcat/Exploration 11.Present Well Condition Summary: Total Depth measured 6203 feet Plugs(measured) none true vertical 6203 feet Junk(measured) none Effective Depth measured 6193 feet Packer(measured) none true vertical 9192 feet (true vertical) none Casing Length Size MD TVD Burst Collapse Conductor 80 16 108 108 Surface 2287 9.625 2314 2314 Production 6168 7 6193 6192 SCANNE , REQ EV EO Perforation depth: Measured depth: None ��15 True Vertical Depth: None \JL 2 . ,OGO Tubing(size,grade,MD,and TVD) 3.5" Kill String, L-80, 2336' MD,2335 TVD Packers&SSSV(type,MD,and TVD) No Packer, No SSSV 12.Stimulation or cement squeeze summary: NA Intervals treated(measured). Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA _ NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,825 283) 15.Well Class after work Daily Report of Well Operations Exploratory r Development r Service In Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r I GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0.Exempt NA Contact MJ_Loveland/Martin Walters Email N1878(a cop.com Printed Name MJ Loveland Title WI Project Supervisor Signature //J'r P ne:659-7043 Date Z/ �//C ----...„ 71 7 ( RBDMS - AUG - 2 2015 AO, � Form 10-404 Revised 5/2015 ;,-f Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 26, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Cassin 6 (PTD 212-196) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. well Cassin 6 (PTD 212- 196). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well continues to be held for future development of the area. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, fig/ — MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Cassin 6 Field/Pool: Wild Cat/ Exploration Permit* (PTD): 212-196 API Number: 50-103-20666-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 4/22/2013 Surface Location: 5091 FSL 1996 FWL Section: 27 Township: 12N Range: 1W Nearest active pad or road: Alpine CD5 Meridian: UM Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Tundra Pad or location surface: Clean Tundra Location cleanup needed: None Pits condition: None Surrounding area condition: Clean Tundra Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: NA Samples taken: None Access road condition: Helicopter Photographs taken (#and description): Aerial of surronding area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Tree Clean. Valve Stem bent on OA valve. IA valve appeared to be in good working order, but could not be cycled due to chicken wire Cellar description, condition, fluids: Cellar full of water no sheen Rat Hole: None Wellhouse or protective barriers: Bird Barrier with chicken wire. Well identification sign: None Tubing Pressure (or casing if no tubing): Not taken as swab valve was not accessible due to barrier Annulus pressures: ✓ OA pressure 75 psi, IA not accessible Wellhead Photos taken (#and description): Photo of tree with bird barrier. Work Required: None Operator Rep (name and signature): Matt Miller, Jim Holley, MJ Loveland AOGCC Inspector: Waived (Matt Herrera) Other Observers: Dave McKnight Inspection Date: 7/25/2015 AOGCC Notice Date: 7/16/15 &7/23/15 Time of arrival: 1000 Time of Departure: 1015 Site access method: Helicopter _" "" MILNAK CASSIN 6 ConocoPhillips ,,, 8.W Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status !noi(°) MD(ftKB) Act Btm(ftKB) Cq,.;.,,,,,;,,r, 501032066600 NORTH ALASKA TIGHT HOLE EXPLOR 1.44 407.60 6,203.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ---Well Coniq:VERTICAL-CASSIN 6,42320131039:52 AM SSSV: Last WO: 0.15 4/22/2013 Schematic.Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:Exploration New Well(tight hole) osborl 4/23/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.250 28.0 108.0 108.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 27.4 2,313.9 2,313.4 40.00 L-80 BTCM <' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,25 PRODUCTION 7 6.276 24.8 6,193.0 6,192.0 26.00 L-80 BTC-M ' 26#/29# Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd t. TUBING Kill String 3 1/2 2.992 24.6 2,336.0 2,335.5 9.30 L-80 EUE8RDM Completion Details Top Depth (TVD) Top Incl Noon... Top(ftKB) (ftKB) (°) Item Description Comment 10(in) 24.61 24.6 -0.01 HANGER FMC TUBING HANGER 3.500 2,334.7 2,334.2 0.96 WLEG WIRELINE ENTRY GUIDE 2.992 Notes:General&Safety End Date Annotation 4/22/2013 NOTE:WELL SUSPENDED WITH KILL STRING""NO PERFORATIONS"" , CONDUCTOR. 26-108 SUR27F-2,31ACE,4 l I WLEG,2,33514 PRODUCTION 26#/299, 25-6,193 TD,6,203 • REV 'DATE BY CK APP DESCRIPTION REV DATE BY I APP DESCRIPTION 1 3/22/13 CZ GD TB ISSUED PER K130003ACS 1 tail HARRISON BAY oral NOTES: I p _ RIVER A� '* gots�V�� UNI l�' 1. BASIS OF COORDINATES: OPUS SOLUTION 9a o .• O JEin, �� OF GPS STATIC OBSERVATIONS 2/14/2013. "' �r ° 2. COORDINATES ARE NAD83,ALASKA STATE jj .� " m, PLANE ZONE 5. ii\ °�� td fii 'C� �r'�t� ��" �. 3. ELEVATIONS ARE CONVERTED FROM OPUS NAVD88 �r- ` e! fl� I TO B.P.M.S.L.VERTICAL DATUM.(-3.5'± DIFF.) I ; Mt ' 4. DISTANCES ARE TRUE. ALL DISTANCES • ?) 01ii� ir AND ELEVATIONS ARE IN US SURVEY FEET. �" a, AO o II p© , 5. DATE OF SURVEY 3/21/2013. •''y 1!! ' 4 ° 7 it V c' KUUKPIK )0; 0 co N ^Q LT ` id �.iMOOSES �� of roa. ©b��f/ N • �, t o LL�i if UNIT © © �.0- Q 4R'.,l 139 E.51st Ave.•Anchorage,Alaska 99503•(907)273-1830 , - •- Alpine Office (907)6704739 r<' �� * (r' t7 _ -'.,�..I Z A Alpine Survey Office 4 Vicinity Map NOT TO SCALE PREVAILING N WIND Z\-2. LCMF 0 SEC. 22, T 12 N., R 1 W. N SEC. 27, T 12 N., R 1 W. •p rd 189' -cen �U o. 0 200 \ 0 1996' i'"'" •° o, SCALE IN FEET 10 2p0 o � � \ \G/ Z z / '5-'CASSIN #6 CASSIN 6 -- , LOCATED WITHIN PROTRACTED 05 N N a SECTION 27, T. 12 N., R. 1 W. 0 UMIAT MERIDIAN, ALASKA w w 50° 189' FNL 1996' FWL !n N s GND ELEV. = 62.2' BPMSL �p• Oo 00 ICE PAD ELEV. = 65.6' BPMSL TOP OF COND. ELEV. = 66.02' BPMSL R � BOE OPO NAD83 Datum NAD27 Datum � N 70022'17.801" N 70°22'19.100" W 152°07'01.005" W 152°06'49.573" ASPC ZN5 ASPC ZN5 (Y) 5,988,944.134 (Y) 5,989,227.894 (X) 1,872,071.478 (X) 732,051.500 'IV' ALPINE MODULE:APOO UNIT: AP Conoc.Phillips CASSIN 6 EXPLORATORY WELL CONDUCTOR Alaska, Inc. AS—BUILT LOCATION CADD FILE NO. DRAWING NO: I PART: REV: 12-12-15-1A 3/22/13 CE—AP00-1120 1 OF 1 1 1 f 3 I ih i II f 1 CE .in 6 PTD 212-196 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or ;cif y� published without express written consent of ConocoPhillips Alaska Ff•. � ��4^.t'm �6c 1 f ' . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. al (a - 4_ 5 (ci Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Col Items: zaps: INPEX Grayscale Items: gs: ❑ Poor Quality Originals: Other: Got?E DE,5C,R I I T/6 N S ❑ Other: BY: Maria Date: 514g1 1g /s/ OE ID Project Proofing BY: Maria . Date: Eil a„gi j5 /s/ Illf ScanningPreparation 7 x 30 = a I D + =TOTAL PAGES a 1 S p f) (Count does not include cover sheet) BY: l Maria)_ Date: 5o A /s/ Production Scanning Stage 1 Page Count from Scanned File: a I tO (Count does include cove eet) Page Count Matches Number in Scan ing Pre � ' ration:ti" YES NO BY: 411. Date:S Zi `-' /sl wp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: 132-- Digital version appended by: Meredith . Michal Date: 5/ ((S /s/ Final Page Count: Stage 1 Stage 2: TOTAL PAGES: 34- r Scanning is complete at this point unless rescanning is required. 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Z V) m Q www �0 t0 COco N M LO N 0 0 0 0 0 0 0 0 o oCN N N C0 YO CO O 000 O @ w = O /� I^///`��\ NN p 0 0 0 0 0 0 0 E GNN \`�}J� v cn o j I'.co w w w w w w w w w 1 W o )- o r ~ V V V V V V V V C co U c N N cn co co co co co co co u') II a I YJ E a O ✓ N N N N N N N N N m 1 y 1E' W O O N N rnU' 2 c Z I O. m '. m' 0re 2 N a E `) p Cr N 10 CO ai G• M 1 CI y Z U U c 1— m c co o N m Q O Q 00 0 U (0 0 0 0 0 0 0 0 0 0 m .0 J a) crn y ) E 0. E0o — p oo 2 a' 2wwwwwwwwo 3 u. 0cea - z 0 a 0 0 U 0 I 0 o NI o 0 co `tl N Z c U >'' o 0 0 C 1 Z �VJJ 4 a D C.) of '4.) Z_ en N w m CL J W = Ce a O W z V 0 O D Z 8 cn QcoEn d = J a CL C O Gg o O O a E & M 0 U d o —I E E V < o 0 a I— M E. 2 N N COW N V tO N d coz ro 10 V/ y p G ictco I— V O lik Q a °_ Q d 0 E 2 a) NJ 1I co rn co > m N 3 N d N d ce • MC d r iri • CO a d m U E E 0 • 0 a M ° (..) 0 Release of Confidential Data Coversheet Well Name: CASSIN 6 PTD: 212-196 E-Set: 22390, 22391, 22578, 22579, 23023, 23024, 23032, 23299, 25155, 25428 ✓ Physical data labeled with PTD, E-Set# Conf. entry: various ✓ Import CD data to RBDMS via GeoLogs tab ✓ Confidential (incomplete)entry in Well Data List notes "mport to DigLogs via E-Set tab Scan labeled data .1/Apply OCR text recognition ave to Well Log Header Scans V New"complete" entry in Well Data List notes Logged by: Meredith Guhl Fully logged: 5/26/2015 Guhl, Meredith D (DOA) From: Alvord, Chip [Chip.Alvord@conocophillips.com] Sent: Friday, May 08, 2015 10:02 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA); Davies, Stephen F(DOA) Subject: RE: Cassin 6, PTD 212-196, Notification Meredith, Thanks for the reminder but ConocoPhillips is ok letting the data be released as scheduled. Rgds, Chip Alvord From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, May 07, 2015 3:54 PM To: Alvord, Chip Cc: Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: [EXTERNAL]Cassin 6, PTD 212-196, Notification Chip, In preparing the well file for Cassin 6 for release after 5/22/2015, I came across the attached documents. On page 2, ConocoPhillips notes that the emails described are not to be released without permission. We have reviewed the attached emails and request ConocoPhillips provide support for additional confidentiality past 5/22/2015, as related to Statute AS 31.05.030. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 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.guhl@alaska.gov. 1 al a-/q(4, LonocoPhillips RECEIVED TRANSMITTAL MAY 05 2015 CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT00346 TO: Makana Bender AOGCC ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7'h Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: Cassin 6 Permit: 212-196-0 DATE: 05/04/2015 Transmitted: _ f North Slope, NPRA, Alaska Cassin 6 (501032066600) 1 color log print each: ✓/Fluids and Minerals Preliminary Evaluation log(electronic file name: CASSIN_6_FRS_FAME.tif) ✓,1RIL T1-T2 Porosity log (electronic file name: CASSIN_6_FRS_MRIL.tif) V Laminated Sand Analysis, Hydrocarbon Identification from RT Scanner log(electronic file: Cassin 6_610y5200_rtxlsa_rev_LamSand_f_RTscan.pdf) Hostile Rotary Sidewall Core Tool log (electronic file: Cassin 6_Sidewall corereport_HRSCT.pdf) l� '1 color eport print: Reservoir Testing Studio- RTS Report(electronic file: CPAI_CASSIN_6_RDT_REPORT.pdf) *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to SandraD.Lemket&COP.com CC: Cassin 6-e-transmittal well folder Receipt Oc Date: 5( 7 / 13— V 111111111111111111r, AK/IT-Technical Data Management I ConocoPhillips I Anchorage Alaska [Ph: 907.165.6947 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, April 29, 2015 3:33 PM To: 'Lemke, Sandra D' Cc: Bettis, Patricia K(DOA) Subject: Cassin 6, PTD 212-196, Data Required Hello Sandra, I'm completing the pre-release review of the data received for Cassin 6. During my review I noted that the following items were missing from the data delivered to date: 1. Fluids and Minerals Preliminary Evaluation log(electronic file name: CASSIN_6_FRS_FAME.tif) 2. MRIL T1-T2 Porosity log(electronic file name: CASSIN_6_FRS_MRIL.tif) 3. Laminated Sand Analysis, Hydrocarbon Identification from RT Scanner log (electronic file: Cassin 6_6108_5200_rtxlsa_rev_LamSand_f_RTscan.pdf) 4. Hostile Rotary Sidewall Core Tool log(electronic file: Cassin 6_Sidewall corereport_HRSCT.pdf) 5. Reservoir Testing Studio- RTS Report(electronic file:CPAI_CASSIN_6_RDT_REPORT.pdf) Please provide the four logs printed on log paper. Please provide the data by May 13, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 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.guhl@alaska.gov. 1 Guhl, Meredith D (DOA) From: Lemke, Sandra D [Sandra.D.Lemke@conocophillips.com] Sent: Tuesday, April 28, 2015 12:28 PM To: Guhl, Meredith D (DOA) Cc: Brown, David W. Subject: Status of Cassin 1 and Cassin 6 AOPA is aware these wells will release shortly. We applied for tax credits on these wells so are aware they will release under the 25 month confidentiality parameters. Land Manager David Brown confirmed this to me today. I know you were waiting on a response from drilling, but David Brown's response is definitive. Thanks for checking with me when I did my data delivery this morning. 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 1 RECEIVED t..onocoPhillips SEP 0 4 2013 AOGCC 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 99501-3539 RE: Cassin 6 Permit: 212-196-0 DATE: 09/04/2013 Tr.n mitt-•: North Slope, NPRA, Alaska Cassin 6 (501032066600) ANRIG Final well report; mud logging data, Cassin 6, Canrig, 04/13/2013; distributed 8/20/2013; Table of contents, Equipment and crew, general well files, geological data, pressure/formation strength data, drilling data, Show reports, daily reports. Log prints: Formation Log(MD) Formation Log(TVD), LWD Combo Log(MD), LWD Combo Log(TVD), gas ration log(MD), gas ratio log (TVD), drilling dynamics(MD), drilling dynamics(TVD); CD 1 contains daily reports, DML data, final well report, las files, log pdf files, log tiff files, show reports, and sample cuttings photos 5310-6203' and 'The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra D.LemkedCOP.com CC: Cassin 6- e-transmittal well folder Receipt: Date: -,*'swilifiNillik& AK/IT-Technical Data Management i ConocoPhillips !Anchorage, Alaska.I Ph: 907.265.6947 Guhl, Meredith D (DOA) From: Shellenbaum, Diane P (DNR) Sent: Wednesday, April 22, 2015 10:19 AM To: Guhl, Meredith D (DOA) Cc: Decker, Paul L(DNR); Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: RE: Cassin 6, PTD 212-196, Extended Confidentiality? Meredith, We have not received any request for extended confidentiality for Cassin 6. Also,our records show this well is located on federal lands. Regards, Diane Diane Shellenbaum Petroleum Geophysicist Alaska DNR Div Oil and Gas wk(907)375-8241 cell(907)331-9678 Diane.ShellenbaumCa)alaska.gov From: Guhl, Meredith D (DOA) Sent: Wednesday, April 22, 2015 9:12 AM To: Shellenbaum, Diane P (DNR) Subject: FW: Cassin 6, PTD 212-196, Extended Confidentiality? Hello Diane, See below,thank you. Meredith From: Guhl, Meredith D (DOA) Sent: Wednesday, April 22, 2015 8:45 AM To: Decker, Paul L(DNR) Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Cassin 6, PTD 212-196, Extended Confidentiality? Hello Paul, Has extended confidentiality been requested for Cassin 6, PTD 212-196, due for release after 5/22/2015? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant 1 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 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.guhl@alaska.gov. 2 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, April 22, 2015 8:45 AM To: Decker, Paul L(DNR) Cc: Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: Cassin 6, PTD 212-196, Extended Confidentiality? Hello Paul, Has extended confidentiality been requested for Cassin 6, PTD 212-196, due for release after 5/22/2015? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 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.guhl@alaska.gov. 1 Co .2.51 2-1) ConocoPhillips RECEIVED TRANSMITTAL FEB 182015 DATALOGGED CONFIDENTIAL DATA ' /201 AOGCC M.K.BENDER 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 RE: Cassin 6 Permit: 212-196-0 DATE: 01/27/2015 Transmitted: North Slope, NPRA, Alaska Cassin 6 (501032066600) With this delivery all anticipated geotechnical data will have been delivered to your agency on this well. CD/digital data Conventional Core folder(10 .xls files); 2E PcRI & RI star data reports, FF&CoCw data report, SS KwKo, SS KgKo, Cation exchange capacity, FF PcRI- 17 samples, USBM 07-01-2014, Cores 1, 2, 3 Chip descriptions. Rotary Sidewall Core folder; MICP-Individual files folder(4 .xls files); Rotary Core description_corr(.xls); MICP Data, run 2, Combo files (.xls) *The information provided hereunder by ConocoPhillips Alaska, Inc., as Operator of the Bear Tooth Unit("ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@COP.com CC: Cassin 6 -e-transmittal well folder ReceiptAL-#84L117) O 'ate: gyp' AK/IT-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 --, f.) ,,,I 11 C0/7 . GP' ,P en,, . CSsi Per u rill/2 -206 , 40GCC 72-196 6600) 0 copy Jen, ,fary 2., rec./47.0.4 1 , s,9°):26.5?6(91:7*etem -ndre.0,4 97 andgeme_ o e'nke@CO "t CONF. P.com . / fftial data , 1 5/es fo 4?oton,Csiopvent. or e en cietva/Pc'sie/Cor Lassin 6 _e 4...a ah,...... 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(. a. a i. a... a. 3T cr. _ I a 3 I.C: 0 r 10 Pc 7c 03 33 C 33 CD 0 CO 0 L . i--1- 4.7f7' I 1,,!, , I ; .........„0 ; „ . , * n CI a .... 7...: ,-t. .7.- cu EL: - i ISI, L'' ; 1 ra .,•,. ro- 0 ,I i In ' .., r-t. • .40,,,,..... .1•••=-= , , n ., 0 3 cr a.. . c. . , -r! ; < i...< . . . rt 4/ I ' n tal . 0 ...., 0 /--,..k..,, 0 U..) 1EL' 411111,11... I r.--, _..,„ rr= • , • n .,,,i,,,..:.:,-.:-..;.;;-::.f..i..N.i: 3 3 0 : f, r 0 lgE. ft, LrrT,....„) l n rr .,...... , . ,. n ; rr= w 77 77 07 07 1......, , 1 : eel ConocoPhillips 2-s\ 5 TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT00340 TO: Makana Bender RECEIVED ConocoPhillips Alaska, Inc. AOGCC DEC 11 2014 P.O. Box 100360 333 W. 72'Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 AOGCC RE: Cassin 6 Permit 212-196-0 DATE: 12/09/2014 Transmitted_: tiNorth Slope, NPRA, Alaska Cassin 6 (501032066600) 1 CD-digital data well sample analyses, photomicrographs, photos; 20 folders, 32.xls files, 1 word doe. 3 .pdf See attached index of files names on CD. 11 1 1 11 p _ � 'The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke000P.com CC: Cassin 6-e-transmittal well folder Receipt ii �.< /.4 ,e^;te, ,As .!„ IT-Technical Data Management I ConocoPhillips I Anchorage,Alaska I Ph:907265.6947 • C6for AOGCC 12_14 r Include in library- 'Share with• - Burn 'New folder Name Date modified Type Size -i,Cassie 6_RSWC End 7zims_OWE 12/9/201411:28 AM File folder KO 4.Cassin6_RSWC Longitudinah_TWF 12;9.201411:28 AM File folder Is ix new-Casein 6!ACP 12:9/201411:23 AM File folder . new-Cassin 6 RSWC Petrography_MWilson_01NOV13 12.9/2014 11: AM File folder NEW-Cassin6_HH-63567_ConocoPhsfips_RSWC_SEM_Inages 12;320141122 AM File folder its new-Cassin6 HH-63567 longitudinal plugs_invasion 5366-5825 12'9,201411:27 AM File folder . new-Cassin6_M Wilson final petrographic data_Photomicro_G5-PC_desc_sand comparis.., 12 9 2014 11:23 AM File folder new-Cassin6_Photomicrographs_additionaisamples__descriptions_GS_PC 12- _11__:A AM File folder nor.-Casein 6_SCAL Plug CT Scans 12.9,2014 11:23 AM File folder New-Cassin_6_hh-63567_cc_Igsa_graphs 12.9.2014 11:28 AM File folder 4)j Cassin 61GSA_Stats and Summaryxlsx 7:17/2013 4:46 PM Microsoft Excel i... 284 KB ':) E Cassin6 Grain Size Data 10-2013x1ss 10;23,2013 3:04 PM Microsoft Excel'A... 120 013 \\anna05)(Pr) j Cassin6 HH-63567 Native 01 to i-T1 NNE Set,,whole_coee_plugs.lds 1028:2013 3:13 PM Microsoft Excel 97... 1,540 KB i(\\conoco.net)(Si) Cassie 6 HH-63567ccXRDadss 9;224,20133 4:23 PM Microsoft Excel;7... 35 KB r\ancap33)'(V:) j Cassin6 Point Count Data 10-2013x1st 10/23;2013 3:05 PM Microsoft Excel'.'i... 112 08 (Aanna05)(Z:) 30j C1531116_SOXHLET_HH-63567 131024_geoch_chipsxhs 18:28%2013 3:17 PM Microsoft Excel W... 33 KB E Cassin 6_ALLGC_HH-63567_130911xlsx 9.122013 3:40 PM Microsoft Excel l's,., 144 KB 12.Cassin 6_BLM permit.pdf 2/7,2313 5:07 PM Adobe Acrobat D... 247 K8 (,Cassin6 GC data_sample plots by_num_depth.zip 9/11:2013 6:23 AM Compressed:ipp... 13.090 08 1.Cassin6_hh.63567 CC CT_Scan images_vertical.zip 1.'15,20145:25 PM Compressed izipp... 5,191 013 Cassia 6)sh-63561 CC_CT_Scan videos_venicalzip 7:3'20132:45 PM Compressed i*fop... 2,317 0B Cassin6 HH-63567 Plug CT Scan_Videos.zip 8,'2:20131:6 PFS Compressed iziop... 39,997 KB 'j Cassin6 LGSA__Stats and Summary Rotary_HH-635679-26-13xlsx 9%20'2013 2:29 PM Microsoft Excel W... 125 KB _1,Cassin 6_Sequential GC dsips.zip 10124.'20136:54 AM Compressed pp... 693 KB j Cassin6 Saddet_HH-63567 9102013xisx 9!122013 33:41 PM Microsoft Excel W... 36 03 4)Cassin6_SRP1309028)nvasion samples_HH-63567_final 141013.xh 1028/2013 3:06 PM Microsoft Excel 97._ 53 KB t Cassin6_SRP1309028_invasion sansples_report_expro_HH-63567.pdf 10/28;2013 3:08 PM Adobe Acrobat D... 202 KB 4)Cassin6-HH-63567 RCA Core123 MINI Gamma Profile completexlsr 6.%%21/201310:39 AM Microsoft Excel'+V... 391 KB 4'new-Cassin 6_HH-63567 2E Preliminary FormFactor-16 samples_updatedxtsx 4/8.'2014 3:00 PM Microsoft Excel W... 39 08 _.__. 41 new-Cassin No.6 HH-63567 01 Te 100%NMR-ids 6/30,2014 10:04 A61 Microsoft Excel 97._ 1,325 KB 4)NEW-Casein No.6 HH-63567 Effective Permeability to Oil12-11.13433 12,17/2013 6:35 PM Microsoft Excel P::.. 26 08 ')new-Cassin No.6 HH-63567 Post Ref K Core Data 6-24-14xlsx 6;80.2014 933 AM Microsoft Excel W... 64 KB 4)NEW Cassin 6 HH-6356717inkenberg Rotary Core Data 11-26-13xlso 12;10:20131:18 P1.1 Microsoft Excel W... 146 KB 4)New_Cassin6 HH-63567ccXRD revised Volumesxisx 1%20:'20113:07:AF.1 Microsoft Excel l':... 47 KB 4)NEW_Cassin 6_ALL_GCxls 11/19:201;5:00 PM Microsoft Excel 97... 105 KB _],:NEW_Cassin 6_Extract GC Soxhlet Onty.Sp 11;19;201=5:08 PM Compressed izipp... 739 08 ji new_Cassin6_hh-63567_CC_SEM_Images Annotated_)PG.zip 3:13.201410:31 AM Compressed i:rpp._ 23,005 KB 4,new_Cassin 6_revized_HH-63'•S7rswc XRDxfss 23,2014 5:49 PM Microsoft Excel;!i... 32 KB E NEN_Cassin6_SOXHLET_HH-63567_131024xlsx 11.19.20135:03 PM Microsoft Excel,N... 33 KB • 4)new-_Cassin No.6_HH-63567 SEM Descriptions_CC.doc 1.20.20113:44 PM Microsoft Word 9... 106 KB ))new_ConocoPhillips Alaska Cassie No.6 HH-63567 Invasion Plugs Core Data 4-25.14xisx 5.%22014 1023 Atd Microsoft Excel W._ 154 KB 4j nervi-Cassin 6 Core Spl Grain Size Data_MW1SON 4-2014xls 4:3!2014 3:13 PM Microsoft Exc ei 97.... 1,066 KB E new-Cassin 6 Core Spi Point Count Data_MWilson/_2014xis 4;8.2014 313 PM Microsoft Excel 97... 1,032 KB 4]New-Cassin 6 HH-63567 01 Te SWI NMRxh 2.%17:2014 3:52 PM Microsoft Excel 97... 1,581.KB 4j new-Casein 6 HH-63567 Core Data EP_I-15R onesmpl_10-22-13xhx 11/5:2313 2:22 PM Microsoft Excel'1i... 17 KB 4 new-Cassin 6XRDResults Wtand Vo109MAri4xlsx 313,2214 7:41 AM 1,licroocft Excel 1; 58 0.8 t NEW-Casein 6 ExproIodide and Major Cations_SRP1311015 final mud-Invasion report cot- 12/1712013 6:29 PM Adobe Acrobat C... 166 KB • 1]new-Cassin 6_LGSA_Cassin No.6 Stats and Summary_20140113xlsx 1,14;2014 632 Ah1 Microsoft Excel Y:_. 322 KB 4]NEWN-Cassin 6_SRP1311015 final Mud_'nwasion_corrected 121213xds 12i17/2013 0:29 PM Microsoft Excel 91... 60 KB 4_j new-Cassin No.6 HH-63567 Post-NMR Core Data 3.24-14xlsz 4,8;2014 3:09 P1.3 Microsoft Excel':':.. 75 KB 4]New-Casein No.6 HH-63567_AW_Pd_capillay pressure.:ds 1.24:201412:30 PM Microsoft Excel 97... 1,631 KB -];revised_HH-63567_Cassin_No6 Cl Photos_6.12-13.zip 6,12.20130:56 AM Compressed izicc... 98,083 KB _1i revised_HH-63567_Cassin Ne6_CI Photos 6-12-13.tip 6/11,2013901:,.1 Compressed.zipp... 120,191 KB j,revised_HH-63567_Cessin_No6_C3_Photos 6.12-13.zip 6/12-20139:05 AM Compressed'zipp... 79,965 KB a updated_Cassin No.6 HH-63567 Conventional Core Data 11-14-13xtsx 5/5%2014 3:59 AM Microsoft Excel t^c.. 113 KB (,,updated_Cassin 6_HH-63567cc2XRD.X1SX 5/2'2014 3:46 API Microsoft Excel'/.,.. 57 KB i items - _ max-.._-a-. _ ... • T .' ___________---- - Conoco �rrrrps Cassin 6 (501032066600) Permit Well Data Sub 12-196-0 mittal to AOGCC CQNFIUEA[ December 9 , 2014 \ The information a iProvided hereunder q�s�,Ina, as Operator of the Dear Tooth Unit lgilinammixt Sandra,D,Lemke (ConocoPhilli Technical Data a�propneta 7,is codential to Mana ment end is not t contains i'hillips Sandra.D.Lemke@COP.com because it co to disclosure stains information 907.265-6947 disclosure data hat is exerypted from under 20 AAC 25.537(b), -well sample analyses -photomicrographs -photos 20 folders 32.xls files 1 word doc detailed list o aransmittal a STATE OF ALASKA • ALS ,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon I— Repair w ell J'-" Rug Perforations I- Perforate r Other 1 Remote Site Alter Casing f Pull Tubing f Stimulate- Frac J-- Waiver I" Time Extension �` Inspection Change Approved Program p Operat. Shutdown I— Stimulate- Other J` Re-enter Suspended Well p 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory j✓ 212-196 3.Address: 6.API Number: Stratigraphic P Service C- P. O. Box 100360,Anchorage,Alaska 99510 50-103-20666-00 7. Property Designation(Lease Number): 8.Well Name and Number: AA 081833 Cassin 6 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Wildcat 11.Present Well Condition Summary: Total Depth measured 6203 feet Plugs(measured) none true vertical 6203 feet Junk(measured) none Effective Depth measured 6193 feet Packer(measured) none true vertical 6192 feet (true vertical) none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2287' 9.625" 2314' 2314' Production 6168' 7" 6193' 6192' RECEIVED OCT 30 2014 Perforation depth: Measured depth: none �®��A (C True Vertical Depth: none Tubing(size,grade,MD,and TVD) 3.5"kill string, 2336' MD and 2335'TVD Packers&SSSV(type, MD,and TVD) no packer no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory 1r Development f Service I Stratigraphic 1-- 16.Well Status after work: Oil I— Gas i— WDSPL 1-- Daily Report of Well Operations XXX GSTOR I-- VVINJ I- WAG (— GINJ I— SUSP f SPLUG 1- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none ,---'' Contact Tom McKay @ 263-4980 Email Tom.W.McKayconocophillips.com Printed Name Tom McKay Title Principal Drilling Engineer Signature �/ W Phone:263-4980 Date ' (ic. /V�'vh� /o— 2 ,Z, /l/a•1Y Form 10-404 Revised 10/2012Ocy Submit Original Only A SC MS OCT 3120 t r RECEIVED OCT 302014 AOGCC ConocoPhillips Box 100360 Alaska 99510-0360 October 29, 2014 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Well Inspection 10-404 Sundry Cassin #6 (Exploratory Test) Surface Location: 189' FNL, 1996' FWL, Sec 27,T12N-RO1W, UM X=732,052 &Y=5,989,228 ASP5 NAD27 Target Location: NA Bottom Hole Location: 260' FNL, 2043' FWL, Sec 27,T12N-RO1W, UM Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a status update for the field inspections of the Cassin #6 location performed on various dates in 2013 as required by 20 MC 25.110. Please find attached the following information: • The following inspections have occurred since the well was suspended in April of 2013: o Stickpicking took place at Cassin #1 & #6 from 7/4-7/7/2013 and again on 7/22/2013 at Cassin #6- no anomalies noted. o The NSB inspected the Cassin locations on 8/31/2013, but did not land-flyover only. • In addition the BLM performed surface inspections at the Cassin #6 location on 9/21/2013 and again on 9/3/2014- inspection reports attached. • The"as-built"plat. • Aerial photographs taken on 8/27/2013 and email reporting no anomalies. • The wellbore status has not changed since filing the 10-407 Sundry. This well is not perforated or completed- a kill string is installed. • The 10-404 Sundry Sincerely, J4 Tom Brassfield Consultant Drilling ngineer for ConocoPhillips cc: CONFIDENTIAL—Cassin #6 Well File ' REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 3/22/13 CZ GD TB ISSUED PER K130003ACS c HARRISON BAY NOTES: °u _�� .., RIVER ° 1. BASIS OF COORDINATES:OPUS SOLUTION '74 c> c P- ft JEC UNI &I to OF GPS STATIC OBSERVATIONS 2/14/2013. ,� s � 2. COORDINATES ARE NAD83,ALASKA STATES �V ''E,! , ,;: ,, PLANE ZONE 5. ' v o p 0 �- © T 1 ,, 3. ELEVATIONS ARE CONVERTED FROM OPUS NAVD88 ,\ * e cy ,-4 _e 10 !� . - eo 4, yip- . s 10 ,L- TO B.P.M.S.L.VERTICAL DATUM.(-3.5'±DIFF.) Q cf. °stir Ail♦� 4. DISTANCES ARE TRUE. ALL DISTANCES $ f) 1 ` d ' O - ! AND ELEVATIONS ARE IN US SURVEY FEET. )`D„.,, �v �r,�, b �r ` �� ... 5. DATE OF SURVEY 3/21/2013. 1 ;ti,,# _' �00 0 ° SCJ m crib w,ois KUUKPIK )04 ° o A co N Q T MOOSES �� 1 �4 i1 �'i (4°) II 770; '(�F LLC �c , . UNIT N fit, it 139 E 518 Ave.•Anchorage.Alaska 99503•(907)273-1830 , CZ: Alpin olr (907)670-4739 I; t5~+ Alpine Survey Office Vicinity Map NOT TO SCALE PREVAILING N WIND 2!2 LCMF 0 SEC. 22, T 12 N., R 1 W. N SEC. 27, T 12 N., R 1 W. 0 Z, o^ _ Y _ 189 / �`� Z No 0 200 o % \ 0 ■ ■ o ■ II . 1111 .4.'1996' � o' SCALE IN FEET • 'IO 2CO \'(S �(G/CC CL P o Z CASSIN #6 CASSIN 6 1- '- m LOCATED WITHIN PROTRACTED - o SECTION 27, T. 12 N., R. 1 W. UMIAT MERIDIAN, ALASKA L,.., 0 500 189' FNL 1996' FWL Cl, s GND ELEV. = 62.2' BPMSL BPMSL 65. 10•0d0° TOP OF COND. ELEV. 6 66.02' BPMSL Ft '''° NAD83 Datum NAD27 Datum 35 \G- N 70°22'17.801" N 70°22'19.100" W 152°07'01.005" W 152°06'49.573" ASPC ZN5 ASPC ZN5 (y) 5,988,944.134 (Y) 5,989,227.894 (X) 1,872,071.478 (X) 732,051.500 ALPINE MODULE:APOO UNIT: AP Conoc.Phillips CASSIN 6 EXPLORATORY WELL CONDUCTOR Alaska, Inc. AS—BUILT LOCATION CADD FILE NO. DRAWING NO: PART: I REV: 12-12-15-1A 3/22/13 CE—AP00-1120 1 OF 1 1 Brassfield, Tom (So!sten XP) Subject: FW: Pictures of Cassin locations From: 2L Pad Co-Man Sent: Tuesday, August 27, 2013 6:35 AM To: Brassfield, Tom 3 Subject: Pictures of Cassin locations Tom, Here are some overhead pictures I took of the two Cassin locations, they are really clean. Jim 111 Cassi 1.JPG Cassin 6.1PG Cassin 6 II.JPG Cassin 1 II.JPG Drilling Special Projects Dave Chapman/Russ Bybee/Jim Holley Office: 659-7318 Dave Cell: 659-0535 Jim Cell: 943-1035 Russ Cell; 232-0907 1 11 l'41) ' 4 I 11 Ced ci F°40 L 113 = LI. — -C1 0- CL (21 I [a DI c ° ILj Lct ca -IL] T3 as c), co .C31 CCI cfj C.1. 413 1:71 ° CL I 1 1 0 c L"' = 0 X 11) -c3 @ N )fit 'w 7 4.a t4 s52 it,#,��_ 4 4, .,'I.,,,, , 4-^, , e., - ,i4 t ' ,::'Ili''''..;,:*:,:.1,:,74:71';'4'44''''''',,.'::;4,t'"!:'•'..,,,.,,i41,,,,,i i:?,,,.4:".,' : ° e .: 4e 404'"7;q. I le* t{ pX < „ f' `�L� .' ,' . W7 d. gA L' 1.,:',41...,..t.`,•,,!,4 5” y� w .>. a a ,- , 1,,,: ,„,:',., ier, ',. ,,•'„,,,,,,a o. • C 0.7 C ID GAJ t it O Fl 1. O 0 ., 4y L7 • d t1 .M `r..1 ii- 4,- 47 C d.7 C ' d5 0 s 0dil C C [l5 • 1 ¢ *s ,q„ m -C Y nt ? +f a et• BLM Arctic Field Office Surface Inspection ConocoPhillips Alaska, Inc. Cassin 6 N70° 22.318 W152° 07.063 September 21, 2013 A surface inspection of the Cassin 6 well site was conducted on the afternoon of July 16, 2013,by Donna Wixon,Natural Resource Specialist with the Bureau of Land Management. From the air,the winter ice pad location is barely discernible from the surrounding tundra, however,the ice road is visible and leads ones eye directly to the former pad area(photos 1 and 2). The tundra at this location consists of discrete polygons with high edges and low centers. Standing water was present in a portion of the low centers, consistent with the surrounding terrain. Vegetation is growing well in the lower areas of the polygons,but remains brown in the higher portions of the pad and road where the tussocks were compressed. A few tussocks were "scuffed"resulting in brown, dead sedge vegetation on the top of the tussock(photos 3 and 4). The wellhead and cellar are securely covered with plastic sheeting. The plastic sheeting has a small amount of bird droppings present(Photo 3),which could indicate perching by birds. A small amount of clay is present in the area immediately surrounding the cellar (Photo 5),but there is no standing water present and no evidence of trenching. The cellar is in good condition(photos 5, 6, 7 and 9). The only debris present on the well pad site was two cigarette butts and a small piece of lathe (Photo 8). The butts didn't look weathered so they could have been from the stick picking crew which had recently removed trash from the site. The site was visited again on August 29, 2013, and a picture of the wellhead was taken. By this time,the tundra had greened up nicely(Photo 9). Overall,the site appears to be in good condition with no issues requiring action. a c R ga. Photo 1: Northwest Aerial View of Cassin 6 Cassin6 2013 Surface Inspection Page 1 of 6 • �t • • S .16 Photo 2: West Aerial View of Cassin 6 * J rk' i : .Ml4 C 4Fw. a 1 �� . i a r, �s n' y r'!'y�*riK a"'."tt' 4A 47 � y �Sfi. xti P � °� �'+• ',� � " �' .'A�'�r x"'13 � �€,_ .r °Kr. Photo 3: Cassin 6 Wellhead Cassin6 2013 Surface Inspection Page 2 of 6 54,,,,,,,,', .4 t,S a a .- �' 944,' ,„ a 4� .' ., ••, " . . .. ° te e•* ? �4:. t ' , fi - 34.sy ` xt , v .+�,% ,.',„4. ' , � m, * ,,- -. :-.,.?...,.-c. - -. ?-6 -' :52y, afm �K t , s ,,,, �w.. # i.��3 p ` ,-.4,-'---,7,-* ' + 3 - _ 4„s-,-:--e;....,--,..;,„,„;,,..,--,,-„-._:,,,,-,-, ,.....,„. .,..„..._-- ,..,, -. -4-. , .. . . - 4,,,, ‘,":'4•‘,":'4•� ; ' i a�- � ru '''';--4--11 � � .n_f� teaar- " ��,; .F 3, 's. r . " 3'lC ' Sk"r }§ 7s..M " �:z,4 - g r r ° r --„,t-. d" ; y; =dy- r',r .( e r 11.>=.- • 3.„ ._ ,, e.40- '-.;.-%p._... iplg - i 4 e ;Y t . .4,,.,-,,...4,, ss, v c+ R V. - a .5 ♦4! ,yL h} A;' i L � � t. S .3, 4 d 1Y � a� 1 •F ,--,„ rt 4 e' r+iT3" w= ' .' '..•.,eS, F4ice_ a§" t Photo 4: Tundra and Cassin 6 Wellhead _/:1:--".....,A1:::114i, 11111: ✓ �i 4/ f ' ''....k1.4::, "k° a . � �� * ..,ads� kir is taa , 141*��4f fiu .0r x i. 1 r 5a 43. -,-_S 1 • �, .4. 1'3 ;y ,r-- igfrter' h' �a �` ,,3 �` . .d*. - 'R t 4 fir, 4 ` , "`x 0. ,a. ga r,`_. V. :,� r4i „le Photo 5: Close Up of Cassin 6 Well Cellar Cassin6 2013 Surface Inspection Page 3 of 6 a a 44. -+- 12- ""L -i:- ^D ry r' r ° �•TSS �.$-....--.- +�As . .T,� L��++ • iR- t ,y+ �e!!&. fit-'47,1:41:, ,t_ .,t -- k,. ..`. `a , c' „ '3 - �, 3 r '�� k ,:. 7 s., ,a�„ a• +` l .....,°;�'^*r k` , ,>A-w,a., „„0...;" �#Y **t t�. �,�, �� 7.,:- rw'�.+c.. � •.,�''"- - v"'M�a!^ "'�' � ' " '�t"�aa '°'.`•`•.e+.t ' �' x`• ,#." r ♦ , k y� > h '.{ 1,:,,,L41„,-,- ra , ''j f.‘,...,...4,04,z,„,-,4,,,),-,,,..`,' .,,„'',\'.14.,, { 3 L*a� 4* .• ,'" 'A t � r�$+ r , 4,14totr e 7'4'"4itifeA' ti a r :gyp e �t At ''. Photo 6: Cassin 6 Wellhead and tundra „ s ‘1‘ ' �� 1 x `�yt 4 r axe .,'S �; -•" r , r"y ,.•ka t,,,"�e5. ++V ` • Photo 7: Cassin 6 Wellhead and tundra Page 4 of 6 Cassin6 2013 Surface Inspection • M-,.• 11 .+1a ,moi T � p�" _ � a: ;�[_ ' ,--•---% ,`,v� .-`- �, tom•. .Y `/^'f '�\/r„+. `7 4 j ,` > 2>a v , r' • �� .3,,..N.,,,--,-.--‘t.,:—.4...,,s : 'i t• ' � '--.pt" :AI- 1 l .7) Jea" •••-:• t 'yc - fv , 3 -, tY •`4,Z. S T[ ` x ‘t.,: - fs . 0 ,,,,,!.,,,,..0. „,/, V ' , • • "%:1C--:+awr S � a a ,a t'a i` f _�. "T cr1 31 y.. ; ". ;1 'le;.,-- � ,;"" • ,„.�?3:y a ' ?" -- \_ ,t • y.-4.. , r _ *'.r.. s" ew \; 4. / A ` Cl4 *� ,,�.�aE ,"s•}�r, },'.�* �� ` yam/ � `3� 1 � / ...t,- e'''. 'r' 4 14, .t . .sty►.,," ) �: +.'1 g , ; "� #� , s t ,. A i�rt k , = t 7. }._ elide,4 --t • ^y Y ,1 r �4P. ..,lw. :t ?r` i" • '< '';�; � ., Ft c " `- y'..-n � ,tale 1 '' ,)-, �''IfJJ z�' moi" ., �t x , -?apt _ • J '` ` �y t <:..,` e C y _ Y,•S lI ' i i1 "*...rte r ' i -.�,',` 't�lj t: ' '71* s „,__:Tyif 4 r Js . 7�,}'" ".� ' .1 fjf /� . ., i1 �' r rpt ,�r": y� f#r pJ' P, : '4p,� 7'` �* it,• ''�i' 9 7,--1, , rr.: 1' F.^' ♦ .'., ., .�. 7,. ,..1 .'l,,. �'-`'' 7.'.. _,i... •fie Photo 8: Cigarette Butt and lathe at the Cassin 6 Well Site Cassin6 2013 Surface Inspection Page 5 of 6 •4:f- U) 0 M O CV! 0) N CO Photo 9: Cassin 6 Wellhead August 29, 2013 Cassin6 2013 Surface Inspection Page 6 of 6 4 BLM Arctic Field Office Surface Inspection ConocoPhillips Alaska, Inc. Cassin 6 N70° 22.318 W152° 07.063 September 3, 2014 A surface inspection of the Cassin 6 well site was conducted on August 26,2014,by Donna Wixon,Natural Resource Specialist with the Bureau of Land Management(BLM)Arctic Field Office. Cassin 6 was drilled during the 2013/2014 winter season(see Figure 1 USGS Topographic map well location). From the air,the winter ice pad location is barely discernible from the surrounding tundra(Photo 1). The vegetation has turned to fall colors and cotton grass is plentiful (Photos 3 and 4). The area is blending nicely with the surrounding terrain. Many of the formerly-scuffed tussocks have vegetation sprouting(Photo 5 and 8), although there are still some remaining brown tussocks (Photo 7). The wellhead and cellar are securely covered with plastic sheeting(Photos 2 to 5), as required by the Arctic Field Office stipulations. The plastic sheeting appears to have more bird droppings present(Photo 6)than in 2013,which could indicate perching by birds. There are no visible tears in the sheeting. The cellar is intact, and there is no visible standing water near the wellhead. No trash was observed on the site. Photo 5 shows what might be drilling mud next to the well cellar, and is the only area of exposed soil on the site. Overall,the site appears to be in good condition with no issues requiring action at this time. r^i p .. „�"h"? `- ..ter �t.. Photo 1:Northwest Aerial View of Cassin 6 Well Site Cassin 6 Aug 26, 2014 Surface Inspection Page 1 of 6 V OP Photo 2: Site of former ice pad at Cassin 6 Well Site x,,. Lid LbLU4U r Photo 3: Cassin 6 Wellhead and vegetation Cassin 6 Aug 26, 2014 Surface Inspection Page 2 of 6 ' 08 26 2014 00 21 r 4 • Photo 4: Cassin 6 Former ice pad area //. . 'a tr •. �a �� *.„, ,fir t sa il ✓, ` y 4 v-;• ,, a . + s"''�• 'i �•' - • e�' ^" _a ,Rsa.% w. •,'it-r P , A S"�•'f *^,'A • �r ;"E '�+ r,..1 S.•.., �'4 "TM" �I d#�; 'A _ .'-- Photo 5: Cassin 6 Cellar Cassin 6 Aug 26,2014 Surface Inspection Page 3 of 6 N N • 0 N Co N fes., P ` { p, 9 Photo 6 Cassin 6 Wellhead covered in plastic sheeting Cassin 6 Aug 26, 2014 Surface Inspection Page 4 of 6 /1 7 , Photo 7: Cassin 6 covered wellhead r 08 26 2014 00 21 Photo 8: Cassin 6 former ice pad area Cassin 6 Aug 26, 2014 Surface Inspection Page 5 of 6 R t oev �R N Kaiik ik HOMO,.BA,18101.0AA.'+OIE /,, .♦n. a or ne CaMPI ctaaacu.7/..... "' 00 VR V Mia RonauiAinK .. CO,-.!,41,,,),,,-h., S+ 0 ka c . ,si -p-,qill, va - •. j. t A� t ' . 1� • u 'tt� �j'� +t d i� sr, "3 i. t s0 t l .4 !16511 `t!.e @ 'S l' t}'J•0 .4 ::,..,-.„.v).• :1 `� D Al ��L',f'i�i t qyy� ., kr xn Airvr,� .11 r x' r , , d ''-li .k?, .. fir :. k ,; P • 1 e.r . , ,„...,,i. ,,, -,..' ,...___ .7.. ,., kg.1_,, -1...„,—,c,.1.. 5i.,,, •,. , „, 4*,i, . ,, _,....,, f -0. -7.t1,. :'`..'" - 4,, M 2i '� 3 " �' 1I5 ` .- � 1.1. isir , •m iJ.a ,rer,r "4417 }^ aw a resi ^� ').•.`" ..tikil '''.'" ,..,',_„9' ife..et...:f.- ,,,'-`-'1- a `1�s {{ h Mr • 1• w� � lid 4" '.} �_, f /rot 1vr ''--..4.1,--..„t `s ,l�'� q�j y J� ‘.. ...„,-,,141,-.: , , r ' 74 le j, ,.......f,....:41,,Y r-' - i � _O CHss,',6 + y' ..,.: r til i>,� �a •,• • �` o GasS n t ' ' 147i. i d z -h[L -Fki - iiL 4tat /�;1q , ,, _ �, .- k. ',1rl-Y,•i. "' ; [1\,, 4 I�- t ,,,,is.,,, Y • _-a ▪ 1 . r<i , -t }i N, ,(-G" 1 . 1 t f e •' 1 n ten. ( • �, i i. 12 Conoco Mid:'. f1 ,..'s 1 �4d_ f�Scout. n /' `! A i '\' 1• a ti ' 1 1 �,,, . ` 114-,e..2:11--- - 'C ? d r - , %, ''. 0,Moos•s 7. 'Tooth C; > '-'-'6""1"'"---Carbon g ."" ., owuw . ....w�.sA.v. .r...n wn „v' n< --7.-...•=1.-4.0:-..:-.••,-,«... .- } ""'""r.,':,.°:".2:1:,.Aurx. 'Harrison Bay B-4 63K;AK';Scale-1"=2.067Mi 3.327Mt 10,916Ft,1 Mi=0 484',1 cm=1.310Mt Figure I: Harrison Bay B-4 Alaska Map showing the location of Cassin 1 and Cassin 6 Page 6 of 6 Cassin 6 Aug 26, 2014 Surface Inspection 2/y - /�� Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, August 21, 2013 4:29 PM To: 'Lemke, Sandra D' Cc: Elgarico, Richard E; Okland, Howard D (DOA); Bettis, Patricia K(DOA); Heusser, Heather A (DNR); Clifton, Sean C (DNR); rebecca.isbell@anadarko.com Subject: RE: Final Logs--Cassin#1 & Cassin#6 Sandra, AOGCC understands that the well log plots and digital data delivered for Cassin 1 and Cassin 6 are final, composite data for archival purposes that were inadvertently marked as being"Field" copies. These plots and digital data satisfy AOGCC's well log reporting requirements for Cassin 1 and Cassin 6. To prevent confusion in the future, please ask your vendor to avoid using the term "Field" when labeling final, composite plots and digital data for distribution to AOGCC. Please contact me if you have further questions. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent: Wednesday, August 21, 2013 3:40 PM To: Davies, Stephen F (DOA); Heusser, Heather A (DNR); Clifton, Sean C (DNR); rebecca.isbell@anadarko.com Cc: Elgarico, Richard E Subject: FW: Final Logs -- Cassin #1 &Cassin #6 Halliburton has provided COP with a detailed verification that logs previously marked and distributed in June and July to agencies and a well partner on Cassin 1 and Cassin 6 are final deliverables. Please consider the e-mail below as the definitive verification that the Halliburton logs delivered for Cassin 1 and Cassin 6 that are marked `FIELD' are indeed the final composited logs. Delivery of other data types for these two wells are ongoing. Thank You for your patience on confirming the status of these logs. If you have any additional questions, please call or e-mail me. Please also provide a confirmation return e-mail that you have received and approve of the final status of the Halliburton logs delivered to you to date. Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhilhps Alaska 700 G Street,ATO 340 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.corn 1 From: Christopher Gullett [mailto:Chris.Gullett@ Halliburton.com] Sent: Wednesday, August 21, 2013 1:31 PM To: Lemke, Sandra D Cc: Matthew Cook; Elgarico, Richard E; Smith, Kent W Subject: [EXTERNAL]RE: Final Logs -- Cassin #1 &Cassin #6 To Whom it may concern, Regarding the open hole well logs for both the Cassin#1 and Cassin #6, all logs marked *FIELD COPY* are marked so to indicate that they represent the raw field data just as it was recorded in the well. This does not indicate that there will be any future log or *FINAL COPY* to replace it. Other logs that were submitted include or use the information from the field copies to create or calculate new models and data, but are not replacement data for the field copy. For example, a MRIAN log is a product log using the field inputs from a MRIL log. Even though the MRIL log is marked *FIELD COPY*,the processed MRIAN log in no way changes the MRIL log. In all examples of both Cassin wells, every log marked *FIELD COPY* is the final revision of itself and marked as such to distinguish between actual recorded well data and computed modeling product log data. In the case of both Cassin#1 and Cassin#6, please accept all log copies marked *FIELD DATA* as the final composited data. No revisions are to be made to any log submitted with the *FIELD DATA* mark. Examples: WSTT(Field Data) => Semblance and Anisotropy (Computed Data) MRIL(field data) => MRIAN (computed data) GEM/CSNG (field data)=> FAME (computed data) Please contact me if there any further clarification is needed Thanks, Chris Gullett Technical Professional—Log Analyst Halliburton Wireline and Perforating Anchorage,AK Mobile: 907-350-8453 Office: 907-273-3527 2 z /Z -/?7 Davies, Stephen F (DOA) From: Christopher Gullett[Chris.Gullett@Halliburton.com] Sent: Wednesday, August 21, 2013 4:09 PM To: Davies, Stephen F (DOA) Subject: RE: Final Logs--Cassin#1 & Cassin#6 Steve, You are correct,these logs are final well data. Each of the two wells were logged in a single logging run and represent 100%of the data acquired. Chris Gullett Technical Professional—Log Analyst Halliburton Wireline and Perforating Anchorage, AK Mobile: 907-350-8453 Office: 907-273-3527 From: Davies, Stephen F (DOA) [ma ilto:steve.davies@alaska.gov] Sent: Wednesday, August 21, 2013 4:03 PM To: Christopher Gullett Subject: FW: Final Logs -- Cassin #1 &Cassin #6 Chris, Just so I understand correctly, these well logs and data are the final data that are fit for archival purposes? To AOGCC, a composite log is a concatenation of all field runs into a single, merged log that extends from the shallowest logged depth to the deepest logged depth in the well. It is the best and final log data recorded in that well. Am I correct? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Gullett Christopher [mailto:Chris.Gullett@Halliburton.com] [ ] Sent: Wednesday, August 21, 2013 1:31 PM To: Lemke, Sandra D Cc: Matthew Cook; Elgarico, Richard E; Smith, Kent W Subject: [EXTERNAL]RE: Final Logs -- Cassin #1 &Cassin #6 To Whom it may concern, Regarding the open hole well logs for both the Cassin#1 and Cassin#6, all logs marked *FIELD COPY* are marked so to indicate that they represent the raw field data just as it was recorded in the well. This does not indicate that there will be any future log or *FINAL COPY* to replace it. Other logs that were submitted include or use the information from the field copies to create or calculate new models and data, but are not replacement data for the field copy. 1 For example, a MRIAN log is a product log using the field inputs from a MRIL log. Even though the MRIL log is marked *FIELD COPY*, the processed MRIAN log in no way changes the MRIL log. In all examples of both Cassin wells, every log marked *FIELD COPY* is the final revision of itself and marked as such to distinguish between actual recorded well data and computed modeling product log data. In the case of both Cassin #1 and Cassin #6, please accept all log copies marked *FIELD DATA* as the final composited data. No revisions are to be made to any log submitted with the *FIELD DATA* mark. Examples: WSTT(Field Data) =>Semblance and Anisotropy (Computed Data) MRIL(field data) => MRIAN (computed data) GEM/CSNG (field data) => FAME (computed data) Please contact me if there any further clarification is needed Thanks, Chris Gullett Technical Professional—Log Analyst Halliburton Wireline and Perforating Anchorage,AK Mobile: 907-350-8453 Office: 907-273-3527 This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient(or authorized to receive information for the intended recipient), please contact the sender by reply e-mail and delete all copies of this message. 2 iG.L.Alvord • RE ` h e d Alaska Drilling Manager Drilling&Wells A iU G 1 5 20'3 P.0.Box 100360 yv Anchorage,AK 99510-0360 ConocoPhi l l i ps A GCC Phone: 907-265-6120 August 15, 2013 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Revised Completion Report for Cassin 6 Dear Commissioner: Attached for your review is the revised completion report for Cassin 6. 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 all three 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. If you have any questions, please feel free to call me at anytime. Sincerely, 4i . ei G. L. Alvord Alaska Drilling Manager CPAI Drilling G LAND L/skad •i"'. • STATE OF ALASKA AUG 1 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND oCC la Well Status. Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑✓ lb Well Class 20AAC 25 105 20AAC 25.110 Development E Exploratory ❑✓ 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 or Aband.: April 22,2013 212-196/313-194 3 Address: 6.Date Spudded. 13.API Number P.0.Box 100360,Anchorage,AK 99510-0360 March 31,2013 50-103-20666-00 4a Location of Well(Governmental Section) 7.Date TD Reached 14 Well Name and Number Surface. 189'FNL, 1996'FWL,Sec.27,T12N, RO1W,UM April 13,2013 Cassin 6 Top of Productive Horizon 8. KB(ft above MSL): 93'RKB 15.Field/Pool(s). not available GL(ft above MSL): 66'AMSL Wildcat Total Depth: 9.Plug Back Depth(MD+TVD) 260'FNL,2043'FWL,Sec.27,T12N,RO1W,UM 6193'MD/6192'TVD Exploration 4b.Location of Well(State Base Plane Coordinates,NAD 27). 10.Total Depth(MD+TVD). 16.Property Designation: Surface: x-732052 y- 5989228 Zone-5 6203'MD/6202'TVD ADL AKAA081833 — TPI: x-n y- na Zone-5 11.SSSV Depth(MD+TVD) 17.Land Use Permit. Total Depth: x- 732101.5 y- 5989158 Zone-5 none 932568 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) 1080'MD/1080'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 MRIL/GEM/SGR not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 28" 108' 28' 108' 24" 24 bbls AS I 9.625" 40# L-80 27' 2314' 27' 2313' 12.25" 851 sx ALC,345 sx Class G 7" 26#/29# L-80/P110 25' 6193' 25' 6192' 8.5" 282 sx Class G 24 Open to production or injection? Yes 0 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) 3.5"kill string 2336' 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 none 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) suspended 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. 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. Formations cored: Brookian Torok, Cassin sands, Blackburn sands,Wickersham sands and Sanford sands Depths cored: Core#1:5330'MD-5500'MD Core#2: 5500'MD-5683'MD Core#3: 5683'MD-5826'MD Summary of Lithology:Attached core chip descriptions Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only • 29 GEOLOGIC MARKERS(List all formations and markers.,.,ountered) 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q 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 1080' 1080' needed,and submit detailed test information per 20 AAC 25 071 K-5 Marker 1721' 1721' Nanushuk 2652' 2652' Torok 3978' 3978' Cassin 5315' 5315' Cassin Base 5476' 5476' Wickersham 5506' 5506' Wickersham Base 5549' 5549' Blackburn 5572' 5572' Blackburn Base 5689' 5689' Sanford 5704' 5704' N/A Sanford Base 5930' 5930' Formation at total depth: Sanford Base 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. David Lee @ 263-3741 Email David.L.Leea.conocoohillios.com D• L Printed Name G. L.Alvord Title Alaska Drilling Manager Signature A.e. Phone 265-6120 Date e 4(C.t 3 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 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). 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C - -t -o -o . - o o - -o -o o -o -o -o 'o - t -c r -o -o -o ' -o -c -o• z`1.M I— LLI >- 0 111 Ov v _ z _17; a L a LLI 2 vv is Q ~ J • 1 TIN 32103 rr' r^ r', r'1 r'1 rr1 M M rr1 rf M r'1 r•1 rrl M rel r"+ r1 r^ r1 r•1 M r'1 r•l rr1 rh M en r•1 rrl _ V1 N O M ,0 0, N C C N CO -- 7 r` O M N 0, N ‘i-+ OC — 7 N O r•1 0• O r•1 `; a oo 0, O, 0, O, C 'r, O N N N M r•, k,-; M 7 7 7 ,n in in 0 ,.^, N N N ,O 'O �O ,O ,O r` O N r` N N N N r` N N M r` N rN N N N N N N ,cN N I- Q v1 ,n v1 n +n 4n N kr, V, ,n kr, V, V, +n in VN N ,n ,n in. V", in in in V1 ,n N in V1 ,n n OF/7/.4, THE STATE Alaska LA Oil and Gras dal � fl`�1L1�1S \1`1 Cse Fvatkkn Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFAnchorage, Alaska 99501-3572 A gD Main. 907.279.1433 Fax: 907.276.7542 August 2, 2013 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7009 2250 0004 3911 3385 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Subject: Incomplete 10-407 Well Completion Report for Cassin 6 (PTD No. 212-196) Dear Mr. Alvord, The Alaska Oil and Gas Conservation Commissioner (AOGCC) received on May 13, 2013 the Form 10-407 "Well Completion Report" for the Cassin 6 well. As submitted, the report is incomplete, see 20AAC 25.071. The purpose of Form 10-407 is to provide a concise, two page summary for AOGCC's well records. Entries such as "Not available" or "To be sent under subsequent report" or "N/A" defeat the purpose of the form; they are not acceptable. In order to complete the Form for Cassin 6, please submit - within 15 days - a revised copy of this Form 10-407 that contains the following data: Box 28: Core Data information. On the revised Form 10-407, list the formations and intervals cored and briefly summarize the lithology and presence of oil, gas or water. If additional space is needed, submit separate sheets with the revised form. When laboratory analyses are completed, submit detailed descriptions, photographs and, including core analysis determinations, if any, of porosity, permeability, and fluid saturations as specified in 20 AAC 25.071. Box 29: On the revised Form 10-407, include all formations and geologic markers that were presented on the planned wellbore schematic drawing submitted by ConocoPhillips in support of the Cassin 6 Permit to Drill application, specifically, "Well Details Plan" contained in the Halliburton Directional Plan. Include the actual measured and true vertical depths for each. The AOGCC's reporting requirements are found in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY • Complete items 1,2,and 3.Also complete A Sig re item 4 if Restricted Delivery is desired. X /? 0 Agent • Print your name and address on the reverse -Z` 0 Addressee so that we can return the card to you. . R ed by(Printedblarn C. Date of Delivery • Attach this card to the back of the mailpiece, or on the front if space permits. r' " °"i.e -P G _, -./ df,, D.Is delivef(address different from item 1? 0 Yes 1. Article Addressed to: If YES,enter delivery address below: 0 No Chip Alvord 3. Service Type Drilling Manager 0 Certified Mail 0 Express Mail ConocoPhillips Alaska,Inc. 0 Registered 0 Return Receipt for Merchandise Post Office Box 100360 0 Insured Mail 0 C.O.D. Anchorage,AK 99510 4. Restricted Delivery?(Extra Fee) 0 Yes 2. Article Number 7009 2250 0004 3911 3385 (Transfer from service label) PS Form 3811,February 2004 Domestic Return Receipt 102595-02-M-1540 Incomplete 10-407 Well Completion Report for Cassin 6(PTD No. 212-196) August 2,2013 Page 2 of 2 These requirements can be accessed on the Internet at: Statute AS 31.05.030: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwjnu01.legis.state. ak.us/cgi-bin/folioisa.d11/stattx07/query=31!2E05!2E030/doc/{t 13554} Regulations 20 AAC 25.070 and 20 AAC 25.25.071: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwj nu01.1egi s.state. ak.us/cgi- bin/folioisa.dll/aac/query={JUMP:'20+aac+25!2E070']/doc/{@ 1}?firsthit If you have any questions concerning the matter, please do not hesitate to contact me at (907) 793-1235 or at Howard.Okland@alaska.gov. alaska.gov. Sincerely, 24-1 (..14“ Howard Okland Geologist Assistant Page 1 of 3 Okland; Howard D (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, July 16, 2013 10:01 AM To: Lemke, Sandra D; Elgarico, Richard E Cc: Bender, Makana K(DOA); Bettis, Patricia K(DOA); Okland, Howard D (DOA) Subject: RE: Cassin 6 Well Log Information -Additional Request Sandra, Do you require re-delivery of the affected .las files? Yes, please. It would be a good practice to include the words "Final Composite" somewhere in the name of each final, composite image file or digital data file and in the title block of each final, composite well log plot. Thanks for your help. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent: Tuesday, July 16, 2013 9:46 AM To: Davies, Stephen F (DOA); Elgarico, Richard E Cc: Bender, Makana K (DOA); Bettis, Patricia K (DOA); Okland, Howard D (DOA) Subject: RE: Cassin 6 Well Log Information - Additional Request We will informed COPA vendors of these required changes. Do you require re-delivery of the affected .las files? We will also check back with Halliburton regarding the field data delivered. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 15, 2013 1:52 PM To: Lemke, Sandra D Cc: Bender, Makana K (DOA); Bettis, Patricia K (DOA); Okland, Howard D (DOA) Subject: [EXTERNAL]Cassin 6 Well Log Information - Additional Request Sandra, One more thing. I also note that the API or UWI numbers in many of the .las-format files are incorrect. They are currently listed as: UWI. 501032066660000: UNIQUE WELL ID (contains 15 digits, one too many "6s") Or UWI . 50-103-20666: API WELLHOLE NUMBER (10 digits with hyphens) 8/5/2013 Page 2 of 3 They should be: UWI. 50103206660000: UNIQUE WELL ID (14-digits, no hyphens) Please have the vendor correct these errors, and please ask all vendors to use 14-digits, no hyphens for API or UWI numbers in all future data files that will be submitted to the AOGCC. Thanks, Steve Davies AOGCC From: Davies, Stephen F (DOA) Sent: Monday, July 15, 2013 12:30 PM To: 'Lemke, Sandra D' Cc: Bettis, Patricia K (DOA); Okland, Howard D (DOA); Bender, Makana K (DOA) Subject: Cassin 6 Well Log Information Sandra, While reviewing well log plots recently submitted by ConocoPhillips for the Cassin 6 exploratory well, I noticed that several of these plots were marked as being field copies. (See the email concerning field-copy well log plots for Cassin 1, below.) Please submit final composite log plots, electronic image files, and data files for all well logs run in Cassin 6 within 90 days of the completion, suspension or abandonment of the well as required by AS 31.05.303(d)(2)(B). • Thanks for your help. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Davies, Stephen F (DOA) Sent: Thursday, July 11, 2013 5:29 PM T.: 'Lemke, Sandra D' Cc. :ettis, Patricia K (DOA); Okland, Howard D (DOA) Subje • Cassin 1 Well Log Information Hi Sandra, I noticed today that many o •- well log plots received for the Cassin 1 ex. •- ory well are marked as being field copies. In 2004, after discussions with BP, A' s ConocoPhillips and other - reporting period required by AS 31.05.303(d)(2)(B)was lengthened to 90 days for well logs and a iated digit. a to give operators and vendors sufficient time to compile single, composite well log plots and associated electro i es from all field runs. At that time, the operators agreed that 90 days was sufficient to allow generation of archival-. .. ity, comp. ' e log plots, electronic image files, and data files. So,field copies are not sufficient to meet AOGCC's r- -ing requirements. Please sub ' . , composite well log plots and associated electronic ima:; .nd digital data files for Cassin 1 and for all future ConocoPhillips wells and well branches. 8/5/2013 Page 3 of 3 Thanks for your help. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 8/5/2013 4 ew��\\I THE STATE A'aska Oil and Gas '"' °fA � Conservation Commission , 42 GOVERNOR SEAN PARNELLW1-4333 West Seventh Avenue O ALAS° *P- Anchorage, Alaska 99501-3572 Main: 907 279 1433 Fax 907 276.7542 August 2, 2013 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7009 2250 0004 3911 3385 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Subject: Incomplete 10-407 Well Completion Report for Cassin 6 (PTD No. 212-196) Dear Mr. Alvord, The Alaska Oil and Gas Conservation Commissioner (AOGCC) received on May 13, 2013 the Form 10-407 "Well Completion Report" for the Cassin 6 well. As submitted, the report is incomplete, see 20AAC 25.071. The purpose of Form 10-407 is to provide a concise, two page summary for AOGCC's well records. Entries such as "Not available" or "To be sent under subsequent report" or "N/A" defeat the purpose of the form; they are not acceptable. In order to complete the Form for Cassin 6, please submit - within 15 days - a revised copy of this Form 10-407 that contains the following data: Box 28: Core Data information. On the revised Form 10-407, list the formations and intervals cored and briefly summarize the lithology and presence of oil, gas or water. If additional space is needed, submit separate sheets with the revised form. When laboratory analyses are completed, submit detailed descriptions, photographs and, including core analysis determinations, if any, of porosity, permeability, and fluid saturations as specified in 20 AAC 25.071. Box 29: On the revised Form 10-407, include all formations and geologic markers that were presented on the planned wellbore schematic drawing submitted by ConocoPhillips in support of the Cassin 6 Permit to Drill application, specifically, "Well Details Plan" contained in the Halliburton Directional Plan. Include the actual measured and true vertical depths for each. The AOGCC's reporting requirements are found in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. 4' 4 Incomplete 10-407 Well Completion Report for Cassin 6(PTD No.212-196) August 2,2013 Page 2 of 2 These requirements can be accessed on the Internet at: Statute AS 31.05.030: http://www.lcgis.state.ak.us/basi s/folioproxy.asp?url=http://wwwjnu01.lcgis.state. ak.us/cgi-bin/folioisa.d11/stattx07/query=31!2E05!2E030/doc/{t13554} Regulations 20 AAC 25.070 and 20 AAC 25.25.071: http://www.legis.state.ak.u s/basis/fol ioproxy.asp?url=http://wwwj nu01.l egis.state. ak.us/cgi- bin/folioisa.dll/aac/query=[JUMP:'20+aac+25!2E070'J/doc/{@}?firsthit If you have any questions concerning the matter, please do not hesitate to contact me at (907) 793-1235 or at Howard.Okland@alaska.gov. Sincerely, LI 0/14 Howard Okland Geologist Assistant ConocoPhilips RECEIVED Jut 14 a'tii TRANSMITTAL CONFIDENTIAL DATA A0900 FROM: Sandra D. Lemke,AT00340 TO: Makana Bender I - ConocoPhillips Alaska, Inc. AOGCC l P.O. Box 100360 333 W. 7t Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Cassin 6 Permit: 212-196-0 DATE: 07/16/2013 Transmitted: North Slope, NPRA, Alaska Cassin 6 (501032066600) CD/digital data Halliburton digital API, header corrections for 10 .las files* CASSIt.6 FRS_FAME.Ias C ASSM_6_FRSMRI Llas — C ASSIN-6 ACE 21APR13.las CASSIN-6_03LMCASTM2I4PR13_MAIN.LAS CASS1N CBLM CASTM 21APR13_PIPE LAS CASSE!-6_CBLM,.CASTM,21APR13_REPIAT.LAS CASSW GEM_MAIN,,,17APRI3Jas CASSUN-6_RDT_MA1N 17APR13.1as CASS1N-6WSTT_MAIN,17APR13.las CASSIN-6XRMI17APR13.1as �—�� `-- *Data requested by Steve Davies,AOGCC *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Daern 'OP.com CC: Cassin 6-e-transmittal well folder /A Receipt: (a AL „El. /„/ Date: K/IT-Technical Data Management I ConocoPhillips !Anchorage, Alaska I Ph:907265.6947 1/a - / 94 ConocoPhillips Z c, �3 TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Cassin 6 Permit: 212-196-0 DATE: 07/12/2013 Transmitted: North Slope, NPRA, Alaska Cassin 6 (501032066600) CD/digital data Hallibu on digiti' RDT,Wavesonic,XRMI,GEM,MRIL,CAST-M, CBL-M,ACE (total 6 CD's) ;iiourton prints 1 eacn RDT, Wavesonic,XRMI, MRI Field, GEM, CAST-M_CBL-M, ACE (7 total) / ^" digital date Weatherford UV_WL Box 3'Core Photos 2_3702-47Z Schlumberger log pdf(laminated sand from RT scanner) 2. Z 3 Baker Hughes Core bit summary report " Weatherford Job HH-63567 Core 1, 2, 3, Gamma profile(4-14-13) i' Weatherford Job HH-63567 Core 1, 2, 3, Gamma Profile(5-19-13) if Weatherford Job HH-63567 Core 1, 2, 3, Mini Gamma Profile complete Weatherford Job HH-63567 CT Scan Image Vertical Weatherford Job HH-63567 CT Scan Video Vertical /r Weatherford Job HH-63567 Pyrograms Weatherford Job HH-63567 TOC_RE July 2, 2013 i/ Mudgas Analysis-Isotech Job 21443 (.xls and .pdf formats) 1/ Sidewall core tool log_HRSCT *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit('ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke()COPcom CC: Cassin 6-e-transmittal well folder , l Receipt: Date: /.. ` < ' -~� .. AK/IT-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph:907265.6947 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, July 15, 2013 1:52 PM To: 'Lemke, Sandra D' Cc: Bender, Makana K(DOA); Bettis, Patricia K(DOA); Okland, Howard D (DOA) Subject: Cassin 6 Well Log Information -Additional Request Sandra, One more thing. I also note that the API or UWI numbers in many of the .las-format files are incorrect. They are currently listed as: UWI. 501032066660000: UNIQUE WELL ID (contains 15 digits, one too many"6s") Or UWI . 50-103-20666: API WELLHOLE NUMBER (10 digits with hyphens) They should be: UWI. 50103206660000: UNIQUE WELL ID (14-digits, no hyphens) Please have the vendor correct these errors, and please ask all vendors to use 14-digits, no hyphens for API or UWI numbers in all future data files that will be submitted to the AOGCC. Thanks, Steve Davies AOGCC From: Davies, Stephen F (DOA) Sent: Monday, July 15, 2013 12:30 PM To: 'Lemke, Sandra D' Cc: Bettis, Patricia K (DOA); Okland, Howard D (DOA); Bender, Makana K(DOA) Subject: Cassin 6 Well Log Information Sandra, While reviewing well log plots recently submitted by ConocoPhillips for the Cassin 6 exploratory well, I noticed that several of these plots were marked as being field copies. (See the email concerning field-copy well log plots for Cassin 1, below.) Please submit final composite log plots, electronic image files, and data files for all well logs run in Cassin 6 within 90 days of the completion, suspension or abandonment of the well as required by AS 31.05.303(d)(2)(B). Thanks for your help. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 1 Phone: 907-793-1224 Fax: 907-276-7542 From: Davies, Stephen F (DOA) Sent: Thursday, July 11, 2013 5:29 PM To: 'Lemke, Sandra D' Cc: Bettis, Patricia K (DOA); Okland, Howard D (DOA) Subject: Cassin 1 Well Log Information Hi Sandra, I noticed today that many of the well log plots received for the Cassin 1 exploratory well are marked as being field copies. In 2004, after discussions with BP, ARCO/ConocoPhillips and others, the reporting period required by AS 31.05.303(d)(2)(B) was lengthened to 90 days for well logs and associated digital data to give operators and vendors sufficient time to compile single, composite well log plots and associated electronic files from all field runs. At that time, the operators agreed that 90 days was sufficient to allow generation of archival-quality, composite log plots, electronic image files, and data files. So, field copies are not sufficient to meet AOGCC's reporting requirements. Please submit final, composite well log plots and associated electronic image and digital data files for Cassin 1 and for all future ConocoPhillips wells and well branches. Thanks for your help. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 2 ConocoPhillips RECEIVED MAY 2 2 2013 TRANSMITTAL AOGCC 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 99501-3539 RE: Cassin 6 Permit: 212-196-0 DATE: 05/22/2013 Transmitted: !North Slope, NPRA, Alaska Cassin 6 (501032066600) CD/digital data X 7 F Haliiburton digital Digital graphic logs; digital log data; logged 4/14/2013; ROP!CTN/ADL!DGR!EWR/MAD PASS 2"&5"MD and TVD; ROP/CTN/ALD/DGRJEWR/XBAT/MAD Pass 2"&5" MD and TVD; ROP/DGR/XCAL/MAD Pass 2"and 5" MD only; logs presented in CGM/DLIS+LAS, EMF, PDF and TIFF formats. Halliburton hardcopy color prints: ROP/CTN/ADL/DGR/EWR/MAD PASS 2"&5"MD and TVD; ROP/CTN/ALD/DGR/EWR/XBAT/MAD Pass 2"&5"MD and TVD; ROP/DGR/XCAL/MAD Pass 2"and 5"MD only 'PAl digital data R a_tJ 7 l ✓,Sperry Sun Waveform (.dlis) ✓Halliburton- Fluid and Mineral Prelim Evaluation digits and images(.las, .tif, ZIP/.las) ialliburton- NAD27_NAD83 definitive directional survey data (zip .pdf& .txt) Halliburton-MRIL T1-T2 Porosity (.dlis, .las, .tif, Zip/.dlis, .las) Schlumberger- Laminated Sand Analysis from RT scanner, run 1A; 4/17/2013(.pdf) / �/ Halliburton- RDT(reservoir description tool) report(.pdf) t. Weatherford- UV_WL core photos(Cores 1-3); 5330-5827' md)conventional core box photos ✓Halliburton-hostile rotary sidewall core tool log; 4/17/2013, run 1(.pdf) /Weatherford-Core Gamma, permeability, and prosoity profile plot(HH-63567)gamma profile 4-14-13(.xlsx) ✓ Baker Hughes-Core Bit Summary Report, April, 2013 *The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Bear Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D Lemk&'cOP.cc,n CC: Cassin 6-e-transmittal well folder p / 21...01"-Z, Receipt: ;��/ Date: J AK/IT-Technical Data Management[ConocoPhillips[.Anchorages Alaska [Ph:9072654.947 , 1a-- 19 � RECEIVED STATE OF ALASKA MAY 1 3 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND4®§CC la Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended O , lb Well Class �1� 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory t"J - GINJ El WINJ ❑ WAG El WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test 2 Operator Name 5.Date Comp,Susp., 12.Permit to Drill Number ConocoPhillips Alaska, Inc. • orAband April 22,2013 212-196/313-194 3 Address: 6.Date Spudded 13 API Number P.O. Box 100360,Anchorage,AK 99510-0360 March 31,2013 50-103-20666-00 ' 4a Location of Well(Governmental Section) 7.Date TD Reached 14.Well Name and Number: Surface' 189'FNL, 1996'FWL,Sec.27,T12N, RO1W,UM April 13,2013 Cassin 6 • Top of Productive Horizon 8. KB(ft above MSL): 93'RKB 15.Field/Pool(s): not available GL(ft above MSL): 66'AMSL ' Wildcat Total Depth. 9.Plug Back Depth(MD+ND) 260'FNL,2043'FWL,Sec.27,T12N,RO1W, UM t 6193'MD/6192'TVD Exploration 4b Location of Well(State Base Plane Coordinates,NAD 27). 10.Total Depth(MD+ND) 16.Property Designation Surface: x-732052 y- 5989228 Zone-5 6203'MD/6202'ND . / ADL AKAA081833 • TPI: x-n y- na Zone-5 11.SSSV Depth(MD+ND): 17 Land Use Permit Total Depth: x- 732101.5 ' y- 5989158 Zone-5 none 932568 18.Directional Survey Yes D 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) 1080'MD/1080'ND 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 MRIUGEM/SGR not applicable 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT — CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED i 16" 62.58# _ H-40 28" 108' 28' 108' 24" 24 bbls AS I - 9.625" 40# L-80 27' 2314' 27' 2313' 12.25" 851 sx ALC,345 sx Class G • 7" 26#/29# L-80/P110 25' 6193' 25' 6192' 8.5" 282 sx Class G 24 Open to production or injection? Yes El No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5"kill string 2336' _ none none 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC Was hydraulic fracturing used during completion? YesE No❑✓ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) suspended 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 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes b No in Sidewall Cores Acquired? Yes Q No El 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 UNDER SUBSEQUENT REPORT RBDMS MAY 13 201c Form 10-407 Revised 10/2012 Cw 4(f 2q/IS CONTINUED ON REVERSE / 7.30-13 Submit original only 29 GEOLOGIC MARKERS(List all formations and marker.,...countered) 30. FORMATION TESTS NAME MD TVD Well tested? E Yes a 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 1080' 1080' needed,and submit detailed test information per 20 AAC 25.071. Cassin 5315' 5315' Cassin Base 5476' 5476' Wickersham 5506' 5506' Wickersham Base 5549' 5549' Blackburn 5572' 5572' Blackburn Base 5689' 5689' Sanford 5704' 5704' Sanford Base 5930' 5930' N/A Formation at total depth: 31 LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey I l Vj 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. 14 N Contact: David Lee @ 263-3741 Email: David.L.Leea.conocophillios.com Printed Name / G.L.Alvord Title Alaska Drilling Manager Signature / 'L Phone 265-6120 Date SI( ( a`3 / 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 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 10/2012 AI NAK CASSIN 6 ConocoPhillips � Well Attributes Max Angle&MD TD /�,,I M1,Ii Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) gyNp6 ii 501032066600 NORTH ALASKA TIGHT HOLE EXPLOR 1.44 407.60 6,203.0 "" Comment HTS(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' _SSSV: Last WO: 0.15 4/22/2013 Well COWS VERTICAL-CASSIN 6,4,'23201310'.39'52 AM l'hems' Acwal Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:Exploration New Well(tight hole) osborl 4/23/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.250 28.0 108.0 108.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 27.4 2,313.9 2,313.4 40.00 L-80 BTCM '.:'.. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd HANGER.25 PRODUCTION 7 6.276 24.8 6,193.0 6,192.0 26.00 L-80 BTC-M i ;;� 26#/29# Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String..String Top Thrd !A TUBING Kill String 3 1/2 2.992 24.6 2,336.0 2,335.5 9.30 L-80 EUE8RDM Completion Details Top Depth 3 (ND) Top not Nomi... Top(ftKB) (ftKB) P( Item Description Comment ID(in) 24.6 24.6 -0.01 HANGER FMC TUBING HANGER 3.500 2,334.7 2,334.2 0.96 WLEG WIRELINE ENTRY GUIDE 2.992 Notes:General&Safety End Date Annotation k� 4/222013 NOTE:WELL SUSPENDED WITH KILL STRING"`NO PERFORATIONS"' t It k i 6 4 CONDUCTOR, 20-108 ,2 q t. 1 4 SU2RFA314CE, , 5 i 22qp k k l ti WLEG,2.335— b iii.,. PRODUCTION 251 26--8,1936,103 \ , ' TD,6,203 ConocoPhillips Time Log & Summary Wel/view Web Reporting Report Well Name: CASSIN 6 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 3/30/2013 12:00:00 AM Rig Release: 4/26/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/29/2013 24 hr Summary Move rig off Cassin#1, 1.5 mile to Cassin#6,then move rig camp to Cassin#6 and rig up.Accept Rig @ 24:00 Hrs,3-28-2013 00:00 03:30 3.50 0 0 MIRU MOVE MOB P PJSM, Prep rig for move, Blow down water,steam,Glycol,disconnect all inter-connect lines,electrical, move inviro-vac heater. 03:30 06:30 3.00 0 0 MIRU MOVE MOB P Move out rock washer,stage boiler and motor complex on pad. 06:30 07:30 1.00 0 0 MIRU MOVE MOB P Move pump and pit complexs to Cassin#6. 07:30 08:30 1.00 0 0 MIRU MOVE MOB P Move pipe shed and stage on pad, Move sub off Cassin#1 well. 08:30 10:00 1.50 0 0 MIRU MOVE MOB P Move Sub off Cassin#1 pad to Cassin#6 pad and spot over well. 10:00 12:00 2.00 0 0 MIRU MOVE MOB P Lay herculite and malts for pit and pump complexs,spot both of them, lay herculite for Motors and boiler complexs. 12:00 13:30 1.50 0 0 MIRU MOVE MOB P Spot motor and boiler complexs, spot rock washer and pipe sheds, hook up electrical,glycol,steam, water, air and mud lines in service connects. 13:30 16:00 2.50 0 0 MIRU MOVE MOB P Move camp from Cassin#1 to Cassin#6 pad, lay mails, lay herculite for sewer plant. SIM-OPS work on pre-rig check list. 16:00 00:00 8.00 0 0 MIRU MOVE RURD P Work on Pre-Rig check list& acceptance,tested gas alarms and calibrated, C/O demco valve on MP# 1.Accept Rig @ 24:00 hrs 3-29-2013 03/30/2013 Rigging up and take on spud mud in pits, N/U diverter system and load 5"dp and hwt in shed,strap same, Diverter test with State and BLM, Lou Grimaldi and Ton Zelenka witnessing the test. Helded Pre-spud meeting,C/O saver subs and P/U and rack back dp&hwt with jars, P/U Motor and bit, 00:00 03:00 3.00 0 0 SURFA( MOVE RURD P Work on rig acceptance check list, spot enviro-vac,spot pipe shed heater and berm up. load pits with spud mud. 03:00 09:00 6.00 0 0 SURFA( DRILL NUND P PJSM, N/U diverter system, load pipe shed with MWD tools and 96 joints of 5"dp. 09:00 10:00 1.00 0 0 SURFA( DRILL OTHR P PJSM,Change out saver sub Page 1 of 28 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:00 11:30 1.50 0 0 SURFA( DRILL BOPE P PJSM,C/O saver subs and perform diverter test,system pressure=3000 psi,pressure after closing=1850 psi, 200 psi attained=46 sec,full pressure attained= 180 sec,5 bottle avg=1950 psi,Time for bag to close=18 sec,Test gas&pit vol. alarms,(Test witnessed by State Rep. Lou Grimaldi and BLM Tom Zelenka.) 11:30 12:00 0.50 0 0 SURFA( DRILL OTHR P Continue C/O saver sub 12:00 13:00 1.00 0 0 SURFA( DRILL SFTY P Pre-spud meeting with crew. 13:00 16:00 3.00 0 0 SURFA( DRILL RURD P PJSM, C/O saver sub,install gasket in diverter line, load 14 jts 5"hwt in shed,strap all pipe. 16:00 20:00 4.00 0 0 SURFA( DRILL PULD P PJSM, P/U and rack back 96 joints of5"dp 20:00 21:00 1.00 0 0 SURFA( DRILL PULD P PJSM, P/U 14 joints of hwt and jars and rack back. 21:00 22:15 1.25 0 0 SURFA( DRILL PULD P Clear rig floor,Gert RKB's, Mobilze tools to rig floor. 22:15 22:30 0.25 0 0 SURFA( DRILL PULD P PJSM on P/U BHA 22:30 00:00 1.50 0 30 SURFA( DRILL PULD P M/U BHA#1,with Bit,Mtr and stabilizer,tagged ice at 30', layed down stabilizer and M/U cross over to hwt. 03/31/2013 Fill hole and surface check,Test lines to 3500 psi,Tagged cement @ 45'MD, circ thick mud out and drill to 108'MD and swap over to mud system.shut down and condition mud vis and mud wt., Drilled to 309'MD& POOH for rest of BHA, M/U BHA#2, SPT MWD, Drill to 414'MD,Clean shakers off due to packing off with clay, Drill to 790'MD,TVD=790'. 00:00 00:30 0.50 30 30 SURFA( DRILL PRTS P Fill hole and pressure test mud lines to 3500 psi(Good) 00:30 04:30 4.00 30 124 SURFA( DRILL DRLG P Tagged ice @ 35'MD, Break circ with 300 gpm and 250 psi, Rot=50 RPM, Drill ice F/35' T/45'MD observed cement in returns,could not circ because mud to thick,shut down and swap over togel water in pit #5, Drill F/70'T/108'MD,swap back to Mud system and drill F/108' T/124'MD,observed mud vis and mud wt was too low. P/U and cond& circ Mud. 04:30 06:00 1.50 124 124 SURFA( DRILL CIRC P Circ and Gond mud,work on raising vis and mud wt. 06:00 08:45 2.75 124 309 SURFA( DRILL DRLG P Drill 12.250"hole section F/124'MD T/309'MD,TVD=309',350 gpm, 300 psi,ART=2.72,ADT=2.72, Up wt=44K, S/O=44 K, Rot=44K, RPM=50,WOB=5/15 K,TQ= 1K 08:45 09:00 0.25 309 309 SURFA( DRILL CIRC P CBU with 400 gpm,475 psi, RPM= 50,Tq= 1K, 09:00 09:15 0.25 309 309 SURFA( DRILL OWFF P Monitor well, Blow down Top Drive. Page 2 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:30 0.25 309 32 SURFA( DRILL TRIP P POOH F/309'T/32'MD, Calc=2.34 bbls,Actual= 1.7 09:30 10:00 0.50 32 32 SURFA( DRILL PULD P PJSM, L/D BHA as per-halliburton DD. 10:00 12:00 2.00 32 105 SURFA( DRILL PULD P PJSM, M/U BHA#2 as per-Halliburton DD 12:00 13:30 1.50 105 105 SURFA( DRILL OTHR P PJSM, M/U BHA and up-load MWD tools 13:30 14:30 1.00 105 105 SURFA( DRILL PULD P Continue M/U BHA, P/U stab and 3 Flex DCs. 14:30 15:30 1.00 105 309 SURFA( DRILL CIRC P Shallow pulse test MWD with 500 gpm, 1000 psi, RIH to bottom. 15:30 16:45 1.25 309 414 SURFA( DRILL DRLG P Drill 12.250"hole section F/309'T/ 414'MD,TVD=414',ART= 1.15, AST=0,ADT= 1.15,Total jar hrs= 2.32, Bit hrs=3.95, P/U=59 K, S/O=60 K, Rot=60 K,Tq on=1 K, WOB=10-15K, GPM=478, PSI= 1050, ECD=10.5 ppg. 16:45 17:15 0.50 414 414 SURFA( DRILL OTHR P Shut down and circ.to clean shaker in the pits and rock washer, observed shakers packing off. 17:15 18:00 0.75 414 477 SURFA( DRILL DRLG P Drill 12.250"hole section F/414'T/ 477'MD,TVD=477',ART=.36, AST=0,ADT= .36,Total jar hrs= 7.46, Bit hrs=4.74, P/U=62 K, S/O=61 K, Rot=64 K,Tq on= 1 K, WOB=12 K, GPM=455, PSI=925, ECD=10.6 ppg. 18:00 00:00 6.00 477 790 SURFA( DRILL DRLG P Drill 12.250"hole section F/477'T/ 790'MD,TVD=790',ART=4.52, AST=0,ADT=4.52,Total jar hrs= 11.28, Bit hrs=9.26, P/U=73 K, S/O=73 K, Rot=75 K,Tq on=1.5 K,WOB=15 K,GPM=436, PSI= 436, ECD= 10.8 ppg. 04/01/2013 Drill 12.250"hole section F 790'T/2324'MD,TVD 2324', CBU for geologist and TD was called @ 2324'MD, Circ hi-vis&weighted sweep,followed by another bottom up.. 00:00 06:00 6.00 790 1,125 SURFA( DRILL DRLG P Drilling F/790'T/1125'MD,TVD= 1125',ART=5.72,AST=0.0,Total Jars=41.38, Bit hrs=14.98, P/U=80 K,S/O=80 K, Rot=83 K,Tq on= 1 K,Tq off= 1 K, ECD= 10.9,WOB=6 K, RPM=80, GPM=400, PSI=875. 06:00 12:00 6.00 1,125 1,460 SURFA( DRILL DRLG P Drilling F/1125'T/1460'MD,TVD= 1460',ART=3.94,AST=0.0,Total Jars=45.32, Bit hrs=18.92, P/U=86 K,S/O=86 K, Rot=88 K,Tq on=2 K,Tq off= 1 K, ECD=10.9,WOB= 20 K, RPM=80, GPM=528, PSI= 1410. Page 3 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 1,460 1,959 SURFA( DRILL DRLG P Drilling F/1460'T/1959'MD,TVD= 1959',ART=4.75,AST=0.0,Total Jars=50.07, Bit hrs=23.67, P/U=96 K, S/O=94 K, Rot=96K,Tq on=3 K,Tq off= 1 K, ECD= 11.1,WOB= 25 K, RPM=80, GPM=528, PSI= 1410. 18:00 22:15 4.25 1,959 2,324 SURFA( DRILL DRLG P Drilling F/1959'T/2324'MD,TVD= 2324',ART=3.46,AST=0.0,Total Jars=53.53, Bit hrs=27.13, P/U= 103 K,S/O=100 K, Rot=101 K,Tq on=2.5 K,Tq off= 1.5 K, ECD=11.3, WOB=25 K, RPM=80,GPM=600, PSI=2000. 22:15 00:00 1.75 2,324 2,324 SURFA( CASING CIRC P CBU for Geologist,survey on bottom, TD called @ 2324'MD, Pump hi-vis weighted sweep. (one pound over) sweep at surface 350 stks early, CBU another Bottoms up w/100 RPM, I K,610 gpm 1850 psi. 04/02/2013 Make wiper trip to 664'MD,good trip.Circulate hole clean and RIH t/2235'.Wash last stand to bottom, hole unloading clay. Circulate hole clean and POOH. Download and L/D BHA. R/U and run 9-5/8"casing to bottom, CBU @ 617',1170', and 1758'. Land 9-5/8"casing @ 2313.87'. Make up cement head and condition mud for cement job. 00:00 00:15 0.25 2,324 2,235 SURFA( CASING TRIP P PJSM, POOH f/2324'to 2235'. 00:15 00:30 0.25 2,235 2,235 SURFA( CASING OWFF P Monitor well, static. Blow down top drive. 00:30 01:15 0.75 2,235 664 SURFA(CASING TRIP P POOH f/2235'to 664'.Actual displacement=15.98 bbls, Calculated displacement=13.26 bbls. 01:15 01:45 0.50 664 664 SURFA(CASING CIRC P Circulate hole clean,stage pumps up to 450 GPM= 1000 PSI, 80 RPM's, Tq=1K,70%flow. 01:45 02:30 0.75 664 2,235 SURFA( CASING TRIP P RIH f/664'to 2235'.Actual displacement= 12.5 bbls,Calculated displacement= 13.26 bbls. 02:30 02:45 0.25 2,235 2,324 SURFA( CASING WASH P Wash and ream f/2235'to 2324'. Stage pumps up to 250 GPM=800 PSI, 100 RPM's,Tq=1K. Large amounts of clay observed at shakers. 02:45 05:45 3.00 2,324 2,324 SURFA(CASING CIRC P Circulate hole clean and condition mud to run 9-5/8"casing. Pump at 650 GPM=2100 PSI, 100 RPM's, Tq=1 K,79%flow. 05:45 06:00 0.25 2,324 2,324 SURFA(CASING OWFF P Monitor well,static. Blow down top drive. 06:00 06:45 0.75 2,324 664 SURFA( CASING TRIP P PJSM, POOH f/2324'to 664'.Actual displacement=26.86 bbls, Calculated displacement=21.76 bbls. 06:45 07:00 0.25 664 664 SURFA( CASING OWFF P Monitor well,static. 07:00 08:00 1.00 664 154 SURFA( CASING TRIP P Stand back 5 stands of HWDP and Jars, lay down 3 joints of flex collars. ,... Page 4 of 28 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:00 09:45 1.75 154 154 SURFA(CASING PULD P Download MWD tools as per Halliburton rep.SIMOPS, mobilize casing tools to rig floor. 09:45 11:15 1.50 154 0 SURFA(CASING PULD P PJSM, Lay down BHA#2 as per Halliburton rep,Total trip actual displacement=34.85 bbls, Calculated displacement=31.92 bbls. 11:15 12:30 1.25 0 0 SURFA( CASING PULD P Clean and clear rig floor. 12:30 14:45 2.25 0 0 SURFA( CASING RURD P PJSM, Rig up to run 9-5/8"surface casing. 14:45 15:15 0.50 0 0 SURFA( CASING SFTY P Hold PJSM on running 9-5/8"casing. Discussed working around power tongs and pipe shed safety. 15:15 17:15 2.00 0 617 SURFA( CASING RNCS P Make up shoe track and check floats. RIH w/9-5/8"L-80 casing to 617',Observed large amounts of clay at shakers and very thick mud, decision made to CBU. 17:15 17:45 0.50 617 617 SURFA( CASING CIRC P Circulate and condition mud,stage pump to 3 BPM=275 PSI. 17:45 18:45 1.00 617 1,170 SURFA(CASING RNCS P Run casing f/617'to 1170'.Observed improper hole fill,decision made to CBU. 18:45 19:30 0.75 1,170 1,170 SURFA(CASING CIRC P CBU at 1170',stage pumps up to 3 BPM=300 PSI. P/U=73K,S/O= 72K. 19:30 20:30 1.00 1,170 1,758 SURFA(CASING RNCS P Run casing f/1170 to 1758', 20:30 21:00 0.50 1,758 1,758 SURFA( CASING CIRC P Circulate and condition mud.Stage pumps to 4 BPM=280 PSI.SIMOPS, pick up cement head and XO to rig floor. 21:00 22:00 1.00 1,758 2,319 SURFA( CASING RNCS P Run casing f/1758 to 2285'. Make up hanger and landing joint, land 9-5/8" casing at 2318.87'MD. P/U= 100K, S/O=95K.Actual displacement= 35.55 bbls, Calculated displacement=36.6 bbls. 22:00 22:45 0.75 2,319 2,319 SURFA(CASING CIRC P Condition mud,stage pumps to 5 BPM=350 PSI. P/U=107K, S/0=104K. 22:45 23:15 0.50 2,319 2,319 SURFA(CASING RURD P Rig down Franks tool,blow down top drive and make up cement head. 23:15 00:00 0.75 2,319 2,319 SURFA( CEMEN-CIRCP Condition mud for cement job,stage pumps to 3 BPM=200 PSI. 04/03/2013 Condition spud mud for cement job.Cement surface casing,pumped 55 bbls mud push, 295 bbls of lead and 72 bbls of tail. 160 bbls of 10.79 ppg lead returned to surface. N/D diverter system and N/U wellhead and BOPE. Begin testing BOPE t/250/3500 PSI f/10 minutes. BLM rep Justin Miller witnessing test. 00:00 01:30 1.50 2,314 2,314 SURFA(CEMEN-CIRC P PJSM,circulate and condition mud for cement job.Stage pumps up to 6 BPM=300 PSI,46%flow.Condition Spud mud to under 20 YP. 01:30 01:45 0.25 2,314 2,314 SURFA(CEMEN-SFTYP Hold PJSM on cementing surface casing. 01:45 02:15 0.50 2,314 2,314 SURFA(CEMEN-CMNT P Schlumberger prime pumps with water and batch up mud push. Page 5 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 05:00 2.75 2,314 2,314 SURFA(CEMEN-CMNT P Pump 5 bbls of water and pressure test lines to 1000/2500 PSI. Pump 50 bbls of 10.1 ppg Mud Push II, drop bottom plug, pump 170 bbls of 10.79 ppg ALC lead cement followed by 125 bbls of 11.09 ppg ALC lead cement. Observed red dye Mud Push 414 II at shakers,swap to tail. Pump 72 t bbls of 15.8 ppg Class G tail cement, shut down. Drop top plug and pump 5 bbls of water on top of plug. Displace cement with 9.8 ppg Spud mud @ 6 BPM=200 PSI,slow pumps to 3 BPM=500 the last 30 bbls. Bump @ 1619 strokes,161.9 bbls. Pressure up to 1100 PSI, bleed off and check floats,good. Reciprocated casing throughout the entire cement job.9-5/8"L-80 casing shoe @ 2313.87'. 1¢0 bbls of cement returned to surface 05:00 06:00 1.00 0 0 SURFA(CEMEN-CMNT P Flush riser with black water and drain. Break off cement head and landing joint. Monitor well through annulus. 06:00 07:30 1.50 0 0 SURFA(CEMEN-RURD P Clean and clear rig floor. Lay down casing tools and franks tool. Remove cement head from rig floor. 07:30 07:45 0.25 0 0 SURFA(WHDBO SFTY P Hold PJSM on nipple down diverter. 07:45 12:00 4.25 0 0 SURFA(WHDBO NUND P Take apart diverter line and knife valve. Function annular and clean out cement. Remove annular and diverter spool.Clean off cement and clay around 9-5/8"casing hanger. Did not tag hard cement with plump bob, decision made to pick up conduit to find top of cement. 12:00 15:00 3.00 0 0 SURFA(WHDBO NUND P PJSM,make up conduit to find TOC. WOC,tagged top @ 7'below hanger. Clean and clear cellar. SIMOPS, clean pits and MOB tools into cellar. 15:00 16:30 1.50 0 0 SURFA(WHDBO NUND P Make up and torque speed head and casing spool. Lay down conduit and pick up mouse hole.Strap 5"drill pipe in shed. 16:30 19:30 3.00 0 0 SURFA(WHDBO NUND P PJSM, nipple up casing spool and test metal to metal seals to 1000 PSI for 10 minutes. Nipple up BOPE and double valve annulus. 19:30 21:00 1.50 0 0 SURFA(WHDBO RURD P Rig up to test BOPE. 21:00 21:15 0.25 0 0 SURFA(WHDBO SFTY P Hold PJSM on testing BOPE. Discuss working around high pressure test lines and using good communication Page 6 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code - :Subcode T Comment 21:15 00:00 2.75 0 0 SURFA(WHDBO BOPE P Test BOPE t/250/3500 PSI. hold test for 10 minutes each.Test#1: Top pipe rams, CV 1,12,13 and 14. Test#2: Upper IBOP, CV 9 and 11. Test#3: Lower IBOP,kill line check valve,CV 5,8,and 10. John Chrisp of the AGOCC waived witness of test. BLM rep Justin Miller witnessed test. 04/04/2013 Cont.to test BOPE to 250/3500 PSI, BLM rep.Justin Miller witnessed test. P/U and stand back 5"drill pipe in derrick. M/U BHA#3 AND RIH to 2174'MD. R/U and test 9-5/8"casing to 3000 PSI for 30 minutes. Drill out shoe track and 20'of new hole to 2344'MD.CBU, R/U and perform LOT to 13.5 ppg EMW. Displace well to 9.8 ppg Kla-Shield mud system and drill ahead. 00:00 04:15 4.25 0 0 SURFA(WHDBO BOPE P PJSM,Cont to test BOPE to 250/3500 PSI.Test#4: Dart valve, CV 4,6, and 7. Test#5: Floor valve and CV 2. Test#6: HCR choke. Test#7. Manual choke. Test#8 �(J Annular preventer. Test#9 Lower pipe rams. Test#10: Blind rams. ‹OrK Accumulator test:system pressure= 3000 PSI, pressure after closed= 1800 PSI,200 PSI attained after 40 sec,full pressure attained after 175 sec. Five bottle nitrogen avg=2050 PSI. BLM rep Justin Miller witnessed test.AOGCC inspector John Chrisp waived witness. 04:15 05:30 1.25 0 0 SURFA(WHDBO RURD P Rig down testing equipment. Drain stack and blow down lines. Install 8-3/4"wear bushing and get RKB measurements. 05:30 05:45 0.25 0 0 SURFA( CEMEN-SFTY P Hold PJSM on picking up 5"drill pipe. 05:45 06:30 0.75 0 0 SURFA( CEMEN-PULD P Lay down 1 stand of HWDP and C/O Jars on stand#2. 06:30 08:15 1.75 0 0 SURFA(CEMEN"PULD P Pick up 17 stands of 5"drill pipe,51 joints. 08:15 08:30 0.25 0 0 SURFA( CEMEN-SFTY P Hold PJSM on picking up BHA. 08:30 10:15 1.75 0 0 SURFA( CEMEN-PULD P Make up BHA#3 as per Halliburton rep. 10:15 12:45 2.50 0 155 SURFA( CEMEN-PULD P Download MWD tool as per Halliburton rep. Unable to get detection in one tool. Decision made to pump on tools to warm them up. Pump @ 120 GPM to warm tools up. Steam nuke tool and blow down top drive.Cont.to download MWD tools. 12:45 13:15 0.50 155 155 SURFA( CEMEN-PULD P PJSM on loading sources. Prep nuke ports and MOB sources to rig floor. Load sources as per Halliburton rep. 13:15 14:00 0.75 155 355 SURFA( CEMEN-PULD P PJSM, make up 3 flex collars f/pipe shed. Run in with HWDP and Jars out of derrick. Page 7 of 28 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:00 14:30 0.50 355 355 SURFA( CEMEN-DHEQ P Shallow pulse test MWD @ 475 GPM=1225 PSI,good. Blow down top drive. 14:30 16:30 2.00 355 2,174 SURFA( CEMEN-TRIP P PJSM, RIH picking up 5"drill pipe to 2174'filling pipe every 20 stands. Actual displacement=23.45 bbls, Calculated displacement=25.59 bbls. 16:30 17:15 0.75 2,174 2,174 SURFA(CEMEN-CIRCP Rig up cement hose for casing test. Circulate @ 220 GPM=700 PSI, 50% flow. 17:15 18:00 0.75 2,174 2,174 SURFA(CEMEN-PRTS P PJSM,Test 9-5/8"L-80 surface casing to 3000 PSI for 30 minutes, good. Blow down lines and rig down test equipment. 18:00 20:45 2.75 2,174 2,324 SURFA(CEMEN-DRLG P RIH and tag TOC @ 2204'.Wash and ream to 2222'and tag float equipment. Drill out float equipment, shoe track and shoe to 2314'. Drill out rat hole to 2324'@ 500 GPM=1500 PSI,60%flow,50 RPM w/1K Tq. 20:45 21:00 0.25 2,324 2,344 SURFA( CEMEN"DDRL P Drill 20'of new hole for FIT/LOT to 2344',TVD-2343'.ART=.16,AST=0, ADT=.16,Total Jar hrs=50.51, Bit hrs=.16, P/U=94K, S/O=95K, ROT=99K. Pump @ 500 GPM=1500 PSI,67%flow.50 RPM w/1.5K Tq on, 1.0 K Tq off.WOB=4-10K. 21:00 21:30 0.50 2,344 2,344 SURFA( CEMEN-CIRC P Circulate and condition mud for FIT/LOT,MW 9.8 ppg In/Out.Stand F back one stand and blow down top drive. �! 21:30 22:45 1.25 2,344 2,344 SURFA( CEMEN-LOT P PJSM,perform LOT t 13.5 ppg EMW on chart. R/D a d RIH bottom @ 2344'. 22:45 23:15 0.50 2,344 2,344 PROD1 DRILL DISP P PJSM, Displace well to 9.8 ppg Kla-Shield mud system. 23:15 00:00 0.75 2,344 2,344 PROD1 DRILL CIRC P Shut down clean under shakers. Obtain SPR's and base line ECD's. 04/05/2013 Drilled f/2344'to 2542'.Trouble shoot MP#2, POOH to shoe and repair pump. RIH and drill f/2542'to 4090' MD TVD=4090'.ART= 14.58,AST=0,ADT= 14.58. Pump @ 631 GPM=2400 PSI. ECD=11.3 ppg. 00:00 03:30 3.50 2,344 2,542 PROD1 DRILL DRLG P Drill f/2344'to 2542'TVD=2542'. ART=2.35,AST=0,ADT=2.35, Total Jar hrs=52.86, Bit hrs=2.51, P/U=95K,S/O=97K, ROT=99K. Pump @ 462 GPM= 1100 PSI,50 RPM w/1K Tq on/off.65%flow, ECD= 10.4 ppg,WOB 3-4K. Drilling on 1 pump while changing seats. 03:30 03:45 0.25 2,542 2,542 PROD1 DRILL CIRC T CBU and trouble shoot#2 mud pump,decision made to POOH to shoe. 03:45 04:00 0.25 2,542 2,542 PROD1 DRILL OWFF T Monitor well,static. Blow down top drive. Page 8 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 2,542 2,263 PROD1 DRILL TRIP T POOH f/2542'to 2263'.Actual displacement=3.82 bbls,Calculated displacement=2.34 bbls. 04:15 05:15 1.00 2,263 2,263 PROD1 RIGMNT RGRP T Work on mud pump#2.Change seats and expansion boot on charge pump line. 05:15 05:30 0.25 2,263 2,542 PROD1 DRILL TRIP T RIH f/2263'to 2542'.Actual displacement=2.16 bbls,Calculated displacement=2.34 bbls 05:30 06:00 0.50 2,542 2,634 PROD1 DRILL DRLG P Drill f/2542'to 2634'TVD=2634'. ART= .67,AST=0,ADT=.67.Total Jars hrs=53.63, Bit hrs=3.18, P/U= 98K, S/O=100K, ROT=99K.80 RPM w/1.5K Tq on, 1.0K Tq off, ECD= 10.9 ppg,73%flow,WOB= 2-4K, Pump @ 625 GPM= 1900 PSI. 06:00 12:00 6.00 2,634 3,092 PROD1 DRILL DRLG P Drill f/2634'to 3092'TVD=3092. ART=3.51,AST=0,ADT=3.51, Total Jar hrs=57.04, Bit hrs=6.69, P/U= 107K, S/O= 110K, ROT= 111K, 50RPM w/1.5KTgon, 1.0K,Tq off, ECD=10.9 ppg,73% flow,WOB=9-11K, Pump @ 630 GPM=1900 PSI. 12:00 18:00 6.00 3,092 3,653 PROD1 DRILL DRLG P Drill f/3092'to 3653'TVD=3653'. ART=4.74,AST=0,ADT=4.74, Total Jar hrs=61.78, Bit hrs=11.43, P/U= 117K, S/0= 120K, ROT= 123K,80 RPM w/4K Tq on, 1K Tq off, ECD= 11.1 ppg, 72%flow, WOB=8-12K, Pump @ 632 GPM=2250 PSI.Obtain SPR's @ 3653'TVD=3653 with 9.8 ppg mud. 18:00 00:00 6.00 3,653 4,090 PROD1 DRILL DRLG P Drill f/3653'to 4090'TVD=4090'. ART=3.31,AST=0,ADT=3.31, Total Jar hrs=65.09, Bit hrs= 14.74, P/U= 125K,S/O= 127K, ROT= 127K, 80 RPM w/1-5K Tq on, 1K Tq off, ECD= 11.3 ppg,72%flow,WOB 8-13K. Pump @ 631 GPM=2400 PSI. 34/06/2013 Drilled f/4090'to 5214'.CBU X 3 and OWFF. POOH t w/pump to HWDP due to well swabbing.Stand back HWDP and drill collars. Read MWD tools and remove sources. 00:00 06:00 6.00 4,090 4,673 PROD1 DRILL DRLG P Drill f/4090'to 4673'TVD=4673', ART=4.46,AST=0,ADT=4.46, Total Jar hrs=69.55, Bit hrs= 19.20, P/U= 136K, S/O= 137K, ROT= 149K,70 RPM w/2-5K Tq on, 1K Tq off, ECD= 11.4 ppg,74%flow,WOB 13-15K. Pump @ 650 GPM=2700 PSI. Page 9 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 4,673 5,140 PROD1 DRILL DRLG P Drill f/4673'to 5140'TVD=5140, ART=3.40,AST=0,ADT=3.40, Total Jars hrs=72.95, Bit hrs= 22.60, P/U=144K,SIO= 146K, ROT= 148K,60 RPM w/2-6K Tq on, 1K Tq off, ECD= 11.4 ppg,WOB= 10-15K,74%flow. Pump @ 650 GPM=2850 PSI.Obtain SPR @ 4856'TVD=4856'with 9.8 ppg mud. 12:00 12:15 0.25 5,140 5,214 PROD1 DRILL DRLG P Drill f/5140'to 5214'TVD=5214, ART=.72,AST=0,ADT= .72,Total Jars hrs=73.67, Bit hrs=23.32, P/U= 145K, S/0= 147K, ROT= 148K, 90 RPM w/2-6K Tq on, 1.5K Tq off, ECD=11.3 ppg,WOB= 10-15K,74%flow. Pump @ 650 GPM=2800 PSI. 12:15 13:00 0.75 5,214 5,214 PROD1 DRILL CIRC P CBU X 3, pump @ 650 GPM=2800 PSI. 13:00 13:15 0.25 5,214 5,214 PROD1 DRILL CIRC P Obtain slow pump rates @ 5214'MD TVD=5214'with 9.8 ppg mud. 13:15 13:30 0.25 5,214 5,214 PROD1 DRILL OWFF P Monitor well,static. 13:30 14:00 0.50 5,214 5,214 PROD1 DRILL TRIP P PJSM, POOH f/5214'to 4950', improper hole fill.Tripped back to bottom. 14:00 14:30 0.50 5,214 5,214 PROD1 DRILL CIRC P CBU, pump @ 500 GPM=1630 PSI. 14:30 19:00 4.50 5,214 2,267 PROD1 DRILL TRIP P POOH w/pump 10 stands.Attempt to pull on elevators, hole still swabbing.Cont.to POOH w/pump to inside casing©2267'. 19:00 20:30 1.50 2,267 592 PROD1 DRILL TRIP P Attempt to pull on elevators,pull 2 ✓ stands,swabbing. POOH w/pump to HWDP @ 3 BPM=325 PSI. 20:30 20:45 0.25 592 592 PROD1 DRILL OWFF P Monitor well, static. 20:45 22:00 1.25 592 152 PROD1 DRILL TRIP P Stand back HWDP and flex collars. 22:00 22:15 0.25 152 152 PROD1 DRILL SFTY P PJSM,on unloading sources. 22:15 22:45 0.50 152 152 PROD1 DRILL PULD P Unload sources from MWD tools. 22:45 00:00 1.25 152 152 PROD1 DRILL PULD P Plug into MWD tools and read tools. 04/07/2013 C/O BHA to move GR closer to bit. RIH to casing shoe and cut drilling line. RIH and drill f/5214'to 5330' TVD=5330'.CBU and POOH. L/D drilling BHA and M/U coring BHA. 00:00 00:30 0.50 152 152 PROD1 DRILL PULD P PJSM, read data from MWD tools as per Halliburton rep. 00:30 01:30 1.00 152 0 PROD1 DRILL PULD P Rack back BHA in derrick. L/D TM HOC,stab, mud motor and bit. 01:30 01:45 0.25 0 0 PROD1 DRILL PULD P Clean and clear rig floor. 01:45 02:30 0.75 0 344 PROD1 DRILL PULD P PJSM, P/U BHA#4 f/derrick. M/U bit sub and bit as per Halliburton rep. 02:30 04:30 2.00 344 344 PROD1 DRILL PULD P Plug in and download MWD tools. SIMOPS,grease swivel packing. 04:30 05:00 0.50 344 344 PROD1 DRILL DHEQ P Pulse test MWD tools @ 500 GPM= 775 PSI, 10%flow. Blow down top drive. Page 10 of 28 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 05:15 0.25 344 344 PROD1 DRILL SFTY P Hold PJSM on loading nuclear sources,discussed distance and shielding; having the proper people on the rig floor. 05:15 05:45 0.50 344 344 PROD1 DRILL PULD P Load sources into MWD tools. 05:45 06:00 0.25 344 570 PROD1 DRILL TRIP P RIH w/1 stand on flex and 4 stands 5"HWDP. 06:00 06:45 0.75 570 2,236 PROD1 DRILL TRIP P RIH f/570'to 2236'. Filling pipe every 20 stands. 06:45 07:00 0.25 2,236 2,236 PROD1 RIGMNT SFTY P Hold PJSM on cutting drilling line. Discussed using proper PPE for handling drilling line and using proper hand placement. 07:00 08:00 1.00 2,236 2,236 PROD1 RIGMNT SLPC P Slip and cut drilling line, 10 wraps. 08:00 09:45 1.75 2,236 5,108 PROD1 DRILL TRIP P RIH f/2236'to 5108',filling pipe every 20 stands.Actual displacement= 46.24 bbls,Calculated displacement=53.23 bbls 09:45 10:00 0.25 5,108 5,160 PROD1 DRILL WASH P Wash and ream f/5108'to 5160', pump @ 530 GPM= 1700 PSI,64% flow. 10:00 10:45 0.75 5,160 5,214 PROD1 DRILL SRVY P MAD pass f/5160'to 5214'@ 150 FPM,pump @ 600 GPM=2100 PSI, 74%flow. 10:45 12:00 1.25 5,214 5,245 PROD1 DRILL DRLG P Drill f/5214'to 5245'TVD=5245, ART=.70,AST=0,ADT=.70,Total Jars hrs=74.37, Bit hrs=24.02, P/U= 143K,S/O= 145K, ROT= 148K, 100 RPM w/2-4K Tq on, 1K Tq off, ECD= 10.56,74%flow,WOB 4-6K, Pump @ 600 GPM=2100 PSI. Obtain SPR @ 5214'TVD=5214' with 9.8 ppg mud. 12:00 13:30 1.50 5,245 5,330 PROD1 DRILL DRLG P Drill f/5245'to 5330'TVD=5330, ART= 1.91,AST=0,ADT= 1.91, Total Jars hrs=76.28, Bit hrs= 26.63, P/U= 146K, S/0= 150K, ROT= 153, 100 RPM w/2-6K Tq on, 1K Tq off, ECD= 10.6 ppg, 74%flow, WOB=4-7K, Pump @ 600 GPM= 2050 PSI. Obtain SPR @ 5330' TVD=5330'with 9.8 ppg mud. 13:30 15:30 2.00 5,330 5,330 PROD1 DRILL CIRC P Circulate hole clean @ 5330'. Pump @ 575 GPM= 1750 PSI, ROT @ 50 RPM while confirming top of sand the town. 15:30 15:45 0.25 5,330 5,330 PROD1 DRILL OWFF P Monitor well,static. 15:45 16:45 1.00 5,330 4,302 PROD1 DRILL TRIP P PJSM, POOH w/pump the 1st 10 stands to 4302'. Pump @ 125 GPM= 300 PSI. 16:45 17:45 1.00 4,302 2,293 PROD1 DRILL TRIP P Blow down top drive, POOH on elevators f/4302'to 2293'. 17:45 18:00 0.25 2,293 2,293 PROD1 DRILL OWFF P Monitor well,static. Page 11 of 28 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 18:00 18:30 0.50 2,293 570 PROD1 DRILL TRIP P POOH on elevators to HWDP @ 570'.Actual displacement=58.45 bbls,Calculated displacement= 53.71 bbls. 18:30 18:45 0.25 570 570 PROD1 DRILL OWFF P Monitor well,static. 18:45 19:15 0.50 570 175 PROD1 DRILL TRIP P Stand back 4 stands of HWDP and 1 stand of collars in derrick. 19:15 19:30 0.25 175 175 PROD1 DRILL SFTY P Hold PJSM on unloading nuclear sources,discussed distance and shielding; having the proper people on the rig floor. 19:30 20:00 0.50 175 175 PROD1 DRILL PULD P Unload nuclear sources from MWD tools. 20:00 21:15 1.25 175 155 PROD1 DRILL PULD P Plug into MWD tools and read tools. 21:15 22:15 1.00 155 0 PROD1 DRILL PULD P Cont to lay down BHA#4. 22:15 22:30 0.25 0 0 PROD1 DRILL PULD P Clean and clear rig floor. 22:30 22:45 0.25 0 0 PROD1 DRILL SFTY P Hold PJSM on picking up Baker coring BHA. Discussed how to safely handling Baker core barrels. 22:45 00:00 1.25 0 0 PROD1 DRILL PULD P Pick up Baker core barrels. 04/08/2013 Cont making up coring BHA. RIH to 5316'and displace well to 9.8 ppg coring fluid with .2 ppb tracer.Circ and cond coring fluid.Core Cassin sand f/5330'to 5498', 168'of core. CBU and POOH using trip speeds as per coring program. 00:00 01:45 1.75 0 180 PROD1 DRILL PULD P PJSM,cont.to make up Baker coring BHA. P/U 180'of core barrels. 01:45 02:00 0.25 180 687 PROD1 DRILL TRIP P P/U 1 stand of flex collars and RIH with 4 stands HWDP out of derrick. 02:00 04:15 2.25 687 5,315 PROD1 DRILL TRIP P RIH f/687'to 5195',filling pipe every 20 stands.Actual displacement= 47.6 bbls, Calculated displacement= 52.92 bbls. 04:15 04:45 0.50 5,315 5,315 PROD1 DRILL WASH P Wash f/5195'to 5315', pump @ 300 GPM=578 PSI,54%flow. Establish parameters. P/U= 137K, S/O= 143K, ROT= 135K. 04:45 05:00 0.25 5,315 5,315 PROD1 DRILL SFTY P Hold PJSM on displacing well to 9.8 ppg coring mud with .2 ppb K tracer. 05:00 07:15 2.25 5,315 5,315 PROD1 DRILL DISP P Displace well to 9.8 ppg coring mud with .2 ppb tracer,pump an additional 2 hole volumes to ensure tracer is spread evenly through mud system. Pump @ 300 GPM=600 PSI,40 RPM w/1 K Tq. 07:15 07:30 0.25 5,315 5,330 PROD1 DRILL CIRC P Drop ball and allow to fall for 10 minutes.Obtain SPR's. P/U 1 stand and RIH to 5330'. Pump @ 300 GPM=825 PSI,50 RPM w/1 K Tq. 07:30 12:00 4.50 5,330 5,436 PROD1 DRILL CORE P Core as per Baker rep.f/5330'to 5436'. Pump @ 300 GPM=1000 PSI,stage pump to 350 GPM= 1200 PSI, 75 RPM w/2-4K Tq, 53%flow, WOB=12-15K, P/U=137K, S/O= 143K, ROT= 135K. Page 12 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 16:30 4.50 5,436 5,498 PROD1 DRILL CORE P PJSM,Cont to core as per Baker rep.f/5436'to 5498'. Pump @ 300 GPM=1350 PSI, 75 RPM w/2-4K Tq.WOB= 15-23K,60%flow, P/U= 150K,S/O=151K, ROT=152K. P/U to 160K to break core. 16:30 17:30 1.00 5,498 5,498 PROD1 DRILL CIRC P CBU @ 530 GPM= 1200 PSI, Rot @ 20 RPM's.Obtain SPR's. 17:30 17:45 0.25 5,498 5,498 PROD1 DRILL OWFF P Monitor well,static. 17:45 18:30 0.75 5,498 5,223 PROD1 DRILL TRIP P POOH w/pump f/5498'to 5223'. 1st 3 stands @ 3-1/2 minutes stand, OWFF for 10 minutes. 18:30 22:00 3.50 5,223 2,213 PROD1 DRILL TRIP P Cont to POOH w/pump f/5223'to 4577'@ 3-1/2 minutes per stand. Line up on trip tank, POOH on elevators @ 3-1/2 minutes per stand to 4012'. POOH on elevators f/4012' to 2213'@ 4 minutes per stand. 22:00 22:30 0.50 2,213 2,213 PROD1 DRILL OWFF P Monitor well @ casing shoe for 30 minutes,static. 22:30 23:15 0.75 2,213 1,900 PROD1 DRILL TRIP P Cont POOH f/2213'to 1900'@ 4 minutes a stand. 23:15 00:00 0.75 1,900 1,860 PROD1 DRILL TRIP P Cont POOH f/1900'to 1860'@ 6 minutes a stand.Actual displacement=40.6 bbls,Calculated displacement=28.9 bbls. 04/09/2013 Cont POOH as per program. L/D inner core barrels. Recovered 170'of core,shipped to town on aircraft.M/U new inner barrels and RIH.Core shale above Blackburn and Blackburn sand to 5667'ND=5667'. 00:00 01:30 1.50 1,860 656 PROD1 DRILL TRIP P PJSM, POOH f/1860'to 656'@ 6 minutes per stand. 01:30 02:00 0.50 656 378 PROD1 DRILL TRIP P Stand back 3 stands of HWDP in derrick. 02:00 02:30 0.50 378 378 PROD1 DRILL OWFF P Monitor well @ last stand of HWDP, static. SIMOPS, hold PJSM on laying down core barrels. 02:30 03:00 0.50 378 180 PROD1 DRILL TRIP P Stand back 1 stand HWDP and flex collars. 03:00 03:45 0.75 180 180 PROD1 DRILL RURD P Rig up Baker Gamma unit for core barrels. 03:45 04:00 0.25 180 180 PROD1 DRILL PULD P Gamma ray 78'of core barrel as Baker rep. 04:00 05:30 1.50 180 90 PROD1 DRILL PULD P Lay down inner barrels as per Baker rep. 05:30 05:45 0.25 90 90 PROD1 DRILL PULD P Gamma ray 90'of core barrel as Baker rep. 05:45 06:30 0.75 90 0 PROD1 DRILL PULD P Lay down inner core barrels as per Baker rep. Recovered 170'of core after measuring core barrels in pipe shed. 06:30 07:00 0.50 0 0 PROD1 DRILL PULD P Stand back 1 stand of outer core barrels in derrick. Pull up to bit and inspect. Bit looked good, re-run bit. 07:00 07:15 0.25 0 0 PROD1 DRILL PULD P Clean and clear rig floor. 07:15 07:30 0.25 0 0 PROD1 DRILL SFTY P Hold PJSM on picking up inner core barrels. Page 13 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:30 1.00 0 180 PROD1 DRILL PULD P Make up bit and 1 stand of outer barrel as per Baker rep. 08:30 11:00 2.50 180 180 PROD1 DRILL PULD P Make up inner core barrels and space out as per Baker rep. 11:00 11:15 0.25 180 180 PROD1 DRILL PULD P Break float sub and inspect. Pull ball from diverter seat as per Baker rep. 11:15 12:00 0.75 180 291 PROD1 DRILL PULD P Pick up 1 stand of flex collars.Clean and clear floor, remove BHA tools. 12:00 14:45 2.75 291 5,380 PROD1 DRILL TRIP P PJSM,cont.to RIH f/291'to 5380' 14:45 15:15 0.50 5,380 5,500 PROD1 DRILL WASH P Wash and ream f/5380'to 5500'. Pump @ 300 GPM= 1350 PSI. Set down 5K @ 5500'. P/U and stand back 1 stand. P/U single and 1 stand. Drop ball and pump down @ 4 BPM=500 PSI, ball seated @ 800 PSI.Actual displacement=54.48 bbls, Calculated displacement=47.6 bbls. 15:15 16:15 1.00 5,500 5,500 PROD1 DRILL CIRC P CBU @ 350 PSI= 1400 PSI. Obtain SPR's @ 5498'TVD=5498'with 9.9+ ppg mud. 16:15 00:00 7.75 5,500 5,667 PROD1 DRILL CORE P Core f/5500.8 to 5667'TVD=5667', ART=7.75,ADT=7.75,Total Jar hrs=92.53, P/U= 149K,S/0= 151K, ROT= 151K,80 RPM w/2-6K Tq, 1K Tq off,54%flow,WOB= 18-24K. Pump @ 350 GPM= 1420 PSI. 04/10/2013 Cont. coring to 5683'. CBU and POOH as per coring program. L/D 183'of core, 100% recovery. M/U 180'of new inner barrel. RIH w/coring BHA,tag bottom @ 5683'.CBU and resume coring operations. Cored f/5683' to 5739'. 00:00 00:30 0.50 5,667 5,683 PROD1 DRILL CORE P PJSM,cont to core f/5667'to 5683' TVD=5683'.Total Jars hrs=93.03, ✓ P/U= 152K,S/O= 152K, ROT= 155K, 75 RPM w/2-4K Tq on, 1K Tq off. 82%flow,WOB=20-24K, pump @ 350 GPM=1400 PSI. Stop coring @ 5683',turn off rotary and P/U 165K to break core off.Core broke @ 13K over pull. 00:30 01:15 0.75 5,683 5,683 PROD1 DRILL CIRC P CBU @ 350 GPM= 1400 PSI,40 RPM w/1K Tq, 62%flow. No gas observed at bottoms. Obtain SPR's @ 5683'w/9.9 ppg mud. 01:15 01:45 0.50 5,683 5,683 PROD1 DRILL OWFF P Monitor well,static.SIMOPS, hold PJSM on POOH. 01:45 02:00 0.25 5,683 5,380 PROD1 DRILL TRIP P POOH @ 3.5 min/stand w/pump f/ 5683'to 5380'. Pump @ 150 GPM=575,22%flow. 02:00 02:15 0.25 5,380 5,380 PROD1 DRILL OWFF P Monitor well as per coring program, static. 02:15 03:30 1.25 5,380 4,730 PROD1 DRILL TRIP P POOH @ 3.5 min/stand w/pump f/ 5380'to 4730' . Pump @ 150 GPM=575,22%flow. 03:30 04:15 0.75 4,730 4,000 PROD1 DRILL TRIP P POOH on elevators f/4730'to 4000' @ 3.5 minutes per stand. Page'14 of 28 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 04:15 06:15 2.00 4,000 2,314 PROD1 DRILL TRIP P POOH on elevators f/4000'to 2314' @ 4 minutes per stand. 06:15 06:45 0.50 2,314 2,314 PROD1 DRILL OWFF P Monitor well @ shoe,static. 06:45 07:15 0.50 2,314 1,900 PROD1 DRILL TRIP P POOH on elevators f/2314'to 1900' @ 4 minutes per stand. 07:15 09:15 2.00 1,900 656 PROD1 DRILL TRIP P POOH on elevators f/1900'to 656'@ 6 minutes per stand. 09:15 09:45 0.50 656 280 PROD1 DRILL TRIP P Stand back Jars and HWDP in derrick, POOH @ 6 minutes per stand. 09:45 10:15 0.50 280 280 PROD1 DRILL OWFF P Monitor well @ last stand of HWDP, static.SIMOPS, hold PJSM on laying down core barrels. 10:15 10:45 0.50 280 180 PROD1 DRILL TRIP P Stand back 1 stand of HWDP and flex collars in derrick @ 6 minutes per stand.Actual displacement= 50.05 bbls,Calculated displacement=44.48 bbls. 10:45 11:45 1.00 180 180 PROD1 DRILL PULD P Break off top of core barrel and R/U Baker gamma unit. 11:45 12:00 0.25 180 180 PROD1 DRILL PULD P Gamma 93 of inner core barrel as per Baker rep. 12:00 13:15 1.25 180 180 PROD1 DRILL PULD P PJSM, L/D 93'of inner core barrels as per Baker. 13:15 13:45 0.50 180 180 PROD1 DRILL PULD P R/U and gamma the lower 90'of inner core barrel. 13:45 14:30 0.75 180 180 PROD1 DRILL PULD P L/D 90'of inner core barrels as per Baker. Recovered a total of 183'of core, 100%recovery. 14:30 15:30 1.00 180 180 PROD1 DRILL PULD P Stand back 90'of outer core barrel. Pull up and break bit. Inspect bit, good. Re-run bit, M/U outer barrel and RIH to 180'. 15:30 16:45 1.25 180 180 PROD1 DRILL PULD P M/U 180'of inner core barrels. 16:45 17:15 0.50 180 650 PROD1 DRILL TRIP P M/U float, RIH with flex collars and HWDP to 650'. 17:15 20:15 3.00 650 5,597 PROD1 DRILL TRIP P RIH f/650'to 5597',filling pipe every 20 stands.Actual displacement= 49.8 bbls,Calculated displacement= 55.3 bbls. 20:15 20:30 0.25 5,597 5,683 PROD1 DRILL WASH P Pick up single and wash/ream the last stand down to 5683'.Set down 5K @ 5683' 20:30 21:00 0.50 5,683 5,680 PROD1 DRILL CIRC P CBU @ 5683', pump @ 350 GPM=900 PSI. 21:00 21:15 0.25 5,680 5,683 PROD1 DRILL CIRC P Make connection and drop ball, pump down @ 165 GPM=500, observed pressure increase to 800 PSI once flow was diverted.Obtain SPR's @ 5683'TVD=5683'with 9.9 ppg mud. 21:15 00:00 2.75 5,683 5,739 PROD1 DRILL CORE P Core f/5683'to 5739'TVD=5739, ART=2.45,ADT=2.45,Total jar hrs= 95.48, P/U=151K, S/0= 150K, ROT= 150, 75 RPM w/2-6K Tq on, 1K Tq off,61%flow,WOB= 18-20K, pump @ 350 GPM=1400 PSI. Page 15'of 28 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04/11/2013 24 hr Summary Cored f/5739'to 5826',core barrel jammed. CBU and POOH using trip schedule. L/D inner core barrels, recovered 143'of core. R/U and test BOPE t/250/3500 PSI for 5 minutes.AOGCC rep Jeff Jones waived witness of test. 00:00 02:45 2.75 5,739 5,826 PROD1 DRILL CORE P Core f/5739'to 5826',TVD=5826'. ADT=2.75,Total Jar hrs=98.48, P/U= 151K,S/O= 151K, ROT=152K, 80 RPM w/2K Tq on, 1K Tq off,64% flow,WOB=22-25K, pump @ 350 GPM=1550 PSI. 02:45 03:00 0.25 5,826 5,826 PROD1 DRILL CORE P Observed weight not drilling off and increased pump pressure along with a drop in torque @ 5826'.Core barrel possibly jammed,decision made to POOH.Shut down rotary and pick up to break core, no over pull observed when attempting to break core off. 03:00 03:45 0.75 5,826 5,826 PROD1 DRILL CIRC P CBU @ 350 GPM= 1400 PSI,64% flow,40 RPM w/1K Tq.Obtain SPR's @ 5826'with 9.9 ppg mud. 03:45 04:15 0.50 5,826 5,777 PROD1 DRILL OWFF P Stand back one stand and blow down. Monitor well,static. 04:15 04:45 0.50 5,777 5,473 PROD1 DRILL TRIP P POOH w/pump f/5777'to 5473', pump @ 150 GPM=575 PSI, pull @ 3.5 minutes per stand. 04:45 05:00 0.25 5,473 5,473 PROD1 DRILL OWFF P Monitor well,static. 05:00 05:45 0.75 5,473 4,824 PROD1 DRILL TRIP P POOH w/pump f/5473'to 4824', pump @ 150 GPM=575 PSI, pull @ 3.5 minutes per stand.Actual displacement=10.15 bbls, Calculated displacement=7.8 bbls. 05:45 09:00 3.25 4,824 2,314 PROD1 DRILL TRIP P POOH on elevators f/4824'to 2314'. Pull @ 3.5 minutes per stand to ‘/ 4000', pull @ 4 minutes per stand V 2314'. 09:00 09:30 0.50 2,314 2,314 PROD1 DRILL OWFF P Monitor well @ shoe,static. 09:30 12:15 2.75 2,314 650 PROD1 DRILL TRIP P POOH f/2314'to 650'. Pull @ 4 minutes per stand to 1900',pull @ 6 minutes per stand to 650'. 12:15 12:30 0.25 650 650 PROD1 DRILL OWFF P Monitor well @ last stand of HWDP, static. 12:30 13:15 0.75 650 180 PROD1 DRILL TRIP P Stand back last stand of HWDP and flex collars. 13:15 13:30 0.25 180 180 PROD1 DRILL SFTY P Hold PJSM on laying down core barrels. 13:30 14:30 1.00 180 180 PROD1 DRILL PULD P Lay down upper empty core barrel. Gamma 52'of core as per Baker. 14:30 15:00 0.50 180 180 PROD1 DRILL PULD P Lay down 60'of inner core barrels. 15:00 16:30 1.50 180 180 PROD1 DRILL PULD P Gamma 90'of inner core barrel. Lay down inner core barrel. Recovered 143'of core. 16:30 17:30 1.00 180 0 PROD1 DRILL TRIP P Stand back 2 outer core barrels in derrick. 17:30 17:45 0.25 0 0 PROD1 DRILL PULD P Clean and clear rig floor. Page 16 of 28 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:45 18:30 0.75 0 0 PROD1 WHDBO SEQP P PJSM,drain stack, pull wear bushing and set test plug. 18:30 18:45 0.25 0 0 PROD1 WHDBO SFTY P Hold PJSM on rigging up and testing BOPE. 18:45 19:45 1.00 0 0 PROD1 WHDBO RURD P Rig up to test BOPE. 19:45 00:00 4.25 0 0 PROD1 WHDBO BOPE P Test BOPE with 5"test joint to 250/3500 PSI for 5 minutes.Witness waived by Jeff Jones of the AOGCC. Test#1:Top pipe rams, CV 1,12,13,14&manual kill. Test#2: Upper IBOP, HCR kill,CV 9&11. Test#3: Lower IBOP, Kill line check, CV 5,8&10. Test#4: Dart valve,CV 4,6&7. Test#5: Floor valve&CV 2. Test#6: HCR choke. Test#7: Manual choke. Test#8:Annular preventer. Test#9: Lower pipe rams. 04/12/2013 Cont testing BOPE to 250/3500 PSI.for 5 minutes. M/U BHA#8 and RIH to 5330',wash and ream to bottom @ 5826'. Drill ahead to 5978', lost MWD detection.Trouble shoot tools, no go. Drill ahead blind to 6038'. Lost 500 PSI pump pressure. POOH looking for wash out. No wash out found,debris found in puler. 00:00 00:45 0.75 0 0 PROD1 WHDBO BOPE P Cont.to test BOPE V 250/3500 PSI f/5 minutes each.Test#10: Blind rams&CV 9. Accumulator test: 1v� System pressure=2950 PSI, 1 Pressure after closing= 1800 PSI, 200 PSI attained after 43 sec, Full pressure attained after 176 sec. Nitrogen 5 bottle avg.=2000 PSI.Jeff Jones of the AOGCC waived witness of test. 00:45 01:45 1.00 0 0 PROD1 WHDBO RURD P Rig down testing equipment. Blow ✓ down choke,choke manifold and kill line.Secure cellar area and install wear bushing. 01:45 02:00 0.25 0 0 PROD1 DRILL SFTY P Hold PJSM on picking up BHA#8. 02:00 03:30 1.50 0 98 PROD1 DRILL PULD P Pick up BHA#8 as per Halliburton rep. LWD tools w/GR near bit, no mud motor. 03:30 05:45 2.25 98 98 PROD1 DRILL PULD P Plug in and download MWD tools as per Halliburton. Steam off Nuke collar and download same. 05:45 06:15 0.50 98 198 PROD1 DRILL DHEQ P Shallow hole test tools @ 400 GPM= 1000 PSI,57%flow. Blow down top drive. 06:15 06:45 0.50 198 198 PROD1 DRILL PULD P Prep and orient source ports. Mobilize sources to rig floor. 06:45 07:00 0.25 198 198 PROD1 DRILL SFTY P Hold PJSM on load nuclear sources into tools. 07:00 07:15 0.25 198 198 PROD1 DRILL PULD P Load nuclear sources in tools as per Halliburton rep. 07:15 07:45 0.50 198 570 PROD1 DRILL TRIP P RIH with 1 stand of flex collars and 4 stands HWDP. Page 17 of 28 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 07:45 10:30 2.75 570 5,330 PROD1 DRILL TRIP P RIH w/5"DP f/570'to 5330',filling pipe every 20 stands.Actual displacement=54.25 bbls, Calculated displacement=57.93 bbls. 10:30 12:00 1.50 5,330 5,826 PROD1 DRILL WASH P Wash and ream f/5330'to 5826'. Pump @ 400 GPM=1700 PSI, 100 RPM w/1-2K Tq. P/U= 149K, S/O= 150K, ROT= 150K. 12:00 16:00 4.00 5,826 5,978 PROD1 DRILL DRLG P PJSM, Drill f/5826'to 5978'TVD= 5978',ART=3.56,ADT=3.56,Total Jar hrs=102.04, Bit hrs=29.49, P/U= 158K,S/O= 162K, ROT= 161K, 100 RPM w/2-3K Tq on, 1.5K Tq off, ECD= 11.01 ppg,66%flow, WOB=6-10K, Pump @ 450 GPM= 2200 PSI. 16:00 18:45 2.75 5,978 5,978 PROD1 DRILL CIRC T Lost detection,trouble shoot tools. Cleaned suction screens on both pumps and adjusted pulsation dampener, no success. Decision made to add 1%Lube 776 in the mud and circ around, no improvement.Confer with town, decision was made to drill ahead blind to—6085'. 18:45 20:45 2.00 5,978 6,038 PROD1 DRILL DRLG P Drill f/5978'to 6038'TVD=6038', ART= 1.69,ADT=1.69,Total Jar hrs=103.73, Bit hrs=31.18, P/U= 159K, S/O=162K, ROT=161K, 100 RPM w/2-3K Tq on, 1.5K Tq off, ECD= 11.01 ppg,66%flow,WOB= 6-8K, Pump @ 450 GPM=2250 PSI. 20:45 21:00 0.25 6,038 6,038 PROD1 DRILL CIRC T After making connection @ 6038', pump pressure was 500 PSI lower than before making the connection. Pressure decreased f/2200 PSI t/ 1700 PSI @ 540 GPM.Trouble shoot all surface equipment,good. Decision made to POOH on elevators. 21:00 21:15 0.25 6,038 6,038 PROD1 DRILL OWFF T Monitor well,static. 21:15 00:00 2.75 6,038 2,100 PROD1 DRILL TRIP T POOH on elevators f/6038'to 2100', good hole fill. 04/13/2013 Cont to POOH. Found debris in pulser. Recorded MWD data showed no Brown sand. L/D Baker core barrels from derrick. M/U drilling BHA and RIH. Drill f/6038'to TD @ 6203'TVD=6203'.CBU X3, POOH making wiper trip to 9-5/8"casing shoe. 00:00 00:15 0.25 2,100 2,100 PROD1 DRILL TRIP T Monitor well,static. 00:15 01:00 0.75 2,100 570 PROD1 DRILL TRIP T POOH t/570'. Monitor well,static. Actual displacement=30.8 bbls, Calculated displacement=28.9 bbls. 01:00 01:30 0.50 570 105 PROD1 DRILL PULD T PJSM,stand back HWDP and flex collars in derrick. Debris that looked like hard cuttings found in the pulser. The debris looked as if they jammed the popit part way open. Page 18 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:00 0.50 105 105 PROD1 DRILL PULD T PJSM, remove nuclear sources from MWD tools. 02:00 03:30 1.50 105 105 PROD1 DRILL PULD P Read MWD tools. Recorded log did not show any sign that we drilled into the Brown sand. Decision made to pick up mud motor and drill to TD of -6188'MD. 03:30 04:00 0.50 105 0 PROD1 DRILL PULD P Break bit,stand back MWD tools in derrick. 04:00 04:30 0.50 0 0 PROD1 DRILL PULD P Clean and clear rig floor. 04:30 06:00 1.50 0 0 PROD1 DRILL PULD P PJSM, lay down 2 stands of Baker core barrels from derrick. 06:00 06:30 0.50 0 0 PROD1 DRILL PULD P Clean and clear floor, remove Baker coring equipment. 06:30 08:00 1.50 0 138 PROD1 DRILL PULD P PJSM,M/U BHA#9 as per Halliburton rep. Mud motor and LWD/MWD tools. 08:00 10:00 2.00 138 138 PROD1 DRILL PULD P Down load MWD tools as per Halliburton rep. 10:00 10:45 0.75 138 138 PROD1 DRILL DHEQ P Shallow hole test MWD tools, pump @ 500 GPM=1000 PSI. 10:45 11:15 0.50 138 155 PROD1 DRILL PULD P PJSM, load nuclear sources into MWD tools as per Halliburton rep. 11:15 12:00 0.75 155 601 PROD1 DRILL TRIP P RIH w/jars, HWDP and flex collars to 601',Actual displacement=13.3 bbls,Calculated displacement= 14 bbls. 12:00 14:30 2.50 601 5,973 PROD1 DRILL TRIP P PJSM,Cont tripping in the hole w/ drilling BHA f/601'to 5973'.Actual displacement=48.3 bbls, Calculated displacement=56.9 bbls. 14:30 14:45 0.25 5,973 6,038 PROD1 DRILL REAM P Wash and ream last stand to bottom @ 6038', pump @ 525 GPM=2025 PSI. 14:45 15:30 0.75 6,038 6,038 PROD1 DRILL DISP P PJSM,displace well over to 9.8 ppg Kla-Shield mud. 15:30 20:00 4.50 6,038 6,203 PROD1 DRILL DRLG P Drill f/6038'to 6203'TVD=6203'. ART=3.46,ADT=3.46,Total Jar hrs= 107.19, Bit hrs=32.64, P/U= 165K, S/0= 166K, ROT=166K,55 RPM w/4-8K Tq on, 1.5K Tq off, ECD= 10.6 ppg,69%flow,WOB= 5-10K,pump @ 560 GPM=2250 PSI. 20:00 21:15 1.25 6,203 6,203 PROD1 EVALFN CIRC P CBU X 3, pump @ 560 GPM=2075 PSI,55 RPM.Obtain SPR @ 6203' TVD=6203'with 9.8 ppg mud. 21:15 21:30 0.25 6,203 6,203 PROD1 EVALFN OWFF P Monitor well,static. 21:30 00:00 2.50 6,203 2,268 PROD1 EVALFN TRIP P PJSM, POOH on elevators f/6203'to 2268'.Actual displacement=34.68 bbls,Calculated displacement=31.2 bbls. 04/14/2013 RIH to TD @ 6203'after making wiper trip to 9-5/8"casing shoe, no tight hole observed.CBU and POOH MAD passing f/6203'to 5300'.Cont POOH to surface and L/D BHA. R/U HES E-line and M/U RDT tools. Test tools, no go.C/O E-line tools and RIH to log. Page 19 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode --T Comment 00:00 00:15 0.25 2,268 2,268 PROD1 EVALFN OWFF P Monitor well @ casing shoe,static. 00:15 02:30 2.25 2,268 6,203 PROD1 EVALFN TRIP P PJSM, RIH to 6158'. Establish circulation,wash and ream last stand to bottom @ 6203'. Pump @ 500 GPM=1725 PSI.Actual displacement=32.1 bbls, 02:30 03:15 0.75 6,203 6,203 PROD1 EVALFN CIRC P CBU X 2 @ 6203'. Pump @ 550 GPM=2000 PSI,40 RPM w/1.5K Tq.Obtain SPR @ 6203'TVD 6203' with 9.8 ppg mud. 03:15 12:15 9.00 6,203 5,300 PROD1 EVALFN SRVY P Perform MAD pass as per Halliburton. POOH @ 120 FPH(2 data points/ft) pump @ 350 GPM= 1000 PSI, ROT 40 RPM. ECD= 10.4 ppg. Mad pass from 6203'to 5300'. 12:15 12:30 0.25 5,300 5,300 PROD1 EVALFN OWFF P Monitor well,static. Blow down top drive. 12:30 14:45 2.25 5,300 600 PROD1 EVALFN TRIP P POOH on elevators f/5300'to 600'. Actual displacement=68.71 bbls, Calculated displacement=60.96 bbls. 14:45 15:00 0.25 600 600 PROD1 EVALFN OWFF P Monitor well @ HWDP,static. 15:00 15:15 0.25 600 180 PROD1 EVALFN TRIP P Stand back HWDP in derrick. 15:15 16:00 0.75 180 90 PROD1 EVALFN PULD P PJSM, lay down flex collars. 16:00 16:30 0.50 90 90 PROD1 EVALFN PULD P PJSM, remove nuclear sources as per Halliburton rep. 16:30 18:15 1.75 90 90 PROD1 EVALFN PULD P Plug into MWD and read data as per Halliburton rep. 18:15 19:30 1.25 90 0 PROD1 EVALFN PULD P Cont to lay down BHA#9 as per Halliburton rep. 19:30 20:00 0.50 0 0 PROD1 EVALFN RURD P Clean and clear rig floor.Mobilize HES E-line tools to rig floor. 20:00 20:15 0.25 0 0 PROD1 EVALFNSFTY P Hold PJSM on rigging up HES E-line. 20:15 21:15 1.00 0 0 PROD1 EVALFN RURD P Rig up HES E-line as per Halliburton rep. 21:15 22:00 0.75 0 0 PROD1 EVALFN ELOG P Make up RDT logging tools on E-line. Test tools,tools did not test. 22:00 00:00 2.00 0 0 PROD1 EVALFN ELOG T Trouble shoot HES E-line tools. Change out tools, pick back up tools from pipe shed. 04/15/2013 C/O RDT tools. Log well with RDT tools on E-line 00:00 01:00 1.00 0 0 PROD1 EVALFN ELOG T Cont to trouble shoot E-line tools. C/O FPS tool on E-line tool string. 01:00 12:00 11.00 0 0 PROD1 EVALFN ELOG P Log with HES RDT tools.Work on MP2's and rig down Sperry MWD equipment. 12:00 00:00 12.00 0 0 PROD1 EVALFN ELOG P PJSM,cont to E-line log with RDT tools.Work on MP2's, inspect draw works chain and change oil. Inspect iron roughneck and change oil. Remove ice and snow from outside walkways. Remove heat exchanger in pits. Page 20 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/16/2013 24 hr Summary L/D Wireline RDT tools, M/U cleanout assy and completed cleanout run. P/U HRSCT and completed sidewall cores. P/U WAVE-XMRI-CSNG-GEM and begin logging. 00:00 01:15 1.25 0 0 PROD1 EVALFN PULD P PJSM and L/D Wireline RDT logging tools 01:15 01:45 0.50 0 376 PROD1 EVALFN PULD P PJSM and P/U Cleanout BHA t/376' 01:45 03:00 1.25 376 2,228 PROD1 EVALFN TRIP P RIH to 2228'MD,fill pipe and blow down T/D. 03:00 04:00 1.00 2,228 2,228 PROD1 RIGMNT SLPC P PJSM-Slip and cut 71'of drilling line. 04:00 06:00 2.00 2,228 6,119 PROD1 EVALFN TRIP P RIH t/6119', P/U=150k, 5/O=152k, Actual disp=53.4 bbl, Calc disp=53.9 bbl. 06:00 06:15 0.25 6,119 6,203 PROD1 EVALFN WASH P Wash and Ream t/6203'MD, 20 rpm, 420 gpm @ 925 psi-(No Fill) 06:15 07:30 1.25 6,203 6,203 PROD1 EVALFN CIRC P CBU X 3 @ 6203'MD, 550 gpm @ 1400 psi,60 rpm @ 1.5k TQ 07:30 07:45 0.25 6,203 6,203 PROD1 EVALFN OWFF P Observe well for flow-Static. 07:45 12:00 4.25 6,203 0 PROD1 EVALFN TRIP P PJSM and POOH to surface. P/U=150k,S/O=154k.Actual fill=57.5 bbl,Calc fill=53.9 bbl. Stopped at casing shoe and HWDP to OWFF-Static. 12:00 12:30 0.50 0 0 PROD1 EVALFN SFTY P PJSM-clean and clear rig floor. Prep tools in pipe shed for Wireline HRSCT run. 12:30 13:15 0.75 0 55 PROD1 EVALFN PULD P PJSM-P/U Wireline tools from pipe shed. 13:15 20:30 7.25 55 6,203 PROD1 EVALFN CORE P RIH with Wireline 1"HRSCT and cut 27 sidewall cores, POOH. 20:30 20:45 0.25 6,203 55 PROD1 EVALFN SFTY P PJSM on L/D and P/U Wireline tools and loading nukes. 20:45 21:15 0.50 55 0 PROD1 EVALFN PULD P Lay down rotary side wall coring tools. 21:15 22:15 1.00 0 95 PROD1 EVALFN PULD P Pick up WAVE-XMRI-CSNG-GEM tools. 22:15 00:00 1.75 95 6,203 PROD1 EVALFN ELOG P RIH and Wireline log. 04/17/2013 Completed HES logging program and R/D HES. Performed cleanout run w/BHA#11, no fill, POOH and L/D. R/U SLB Wireline, RIH w/Run#1-RT scan. 00:00 04:30 4.50 6,203 95 PROD1 EVALFN ELOG P PJSM and coninue running Wireline Run#3,WAVE-XMRI. Perform rig service,service skate,grease choke manifold. 04:30 04:45 0.25 95 0 PROD1 EVALFN SFTY P PJSM-L/D-P/U logging tools, removing sources. 04:45 06:15 1.50 0 0 PROD1 EVALFN PULD P L/D Run#3 logging tools, remove sources.Swap centralizers etc to Run#4 MRIL string. 06:15 07:00 0.75 0 55 PROD1 EVALFN PULD P PJSM and P/U Run#4 MRIL string. 07:00 12:00 5.00 55 6,203 PROD1 EVALFN ELOG P RIH with Run#4 MRIL/GEM/SGR 12:00 12:45 0.75 6,203 0 PROD1 EVALFN SFTY P PJSM-L/D Run#4 wireling tools and R/D HES. Page 21 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 16:15 3.50 0 6,119 PROD1 EVALFN FCO P PJSM-M/U BHA#11, PDC Bit 2RR5, Bit sub,float sub, HWDP to 376'. RIH t/6119'MD filling pipe every 20 std.Calc disp=55 bbl,Actual disp=47 bbl. 16:15 16:30 0.25 6,119 6,203 PROD1 EVALFN WASH P Wash and ream f/6119'MD t/6203' MD 16:30 17:30 1.00 6,203 6,203 PROD1 EVALFN CIRC P CBU X 3 @ 570 gpm-1400 psi, 50 rpm 1.5k TQ, P/U 150k,S/O 151K. 17:30 18:00 0.50 6,203 6,203 PROD1 EVALFN OWFF P Blow down Topdrive, Observe well for flow,static/slight drop. 18:00 19:30 1.50 6,203 2,292 PROD1 EVALFN TRIP P POOH f/6203'MD t/2292'MD. 19:30 19:45 0.25 2,292 2,292 PROD1 EVALFN OWFF P Observe well for flow at surface shoe, static/slight drop. 19:45 20:15 0.50 2,292 370 PROD1 EVALFN TRIP P POOH f/2292'MD V 370'MD. Observe well 10 minutes at 370' (HWDP)static/slight drop. 20:15 20:45 0.50 370 0 PROD1 EVALFN PULD P Rack back BHA#11,Calc fill=55.2 bbl,Actual fill=61.4 20:45 21:00 0.25 0 0 PROD1 EVALFNSVRG P Clean and clear rig floor. 21:00 21:15 0.25 0 0 PROD1 EVALFN SFTY P PJSM with SLB, (Rigging up wireline and P/U RT Scanner). 21:15 22:30 1.25 0 100 PROD1 EVALFN PULD P Rig up SLB wireline and pick up RT scanner. 22:30 00:00 1.50 100 6,203 PROD1 EVALFN ELOG P RIH with RT scanner and begin logging. 04/18/2013 Completed SLB RTscan with gamma, RIH with seismic imaging tools with gamma,spot CGG seismic equipment and perform VSP. R/D SLB and test BOPE per AOGCC, BLM regs and COP standards. P/U BHA #12 for final cleanout prior to running 7"casing and RIH.2 ea RA tags installed in casing. 00:00 01:15 1.25 6,203 100 PROD1 EVALFN ELOG P PJSM and continue running SLB wireline RT scan w/GR combo. 01:15 01:45 0.50 100 100 PROD1 EVALFN ELOG P PJSM-Laying down/Picking up wireline logging tools 01:45 03:00 1.25 100 352 PROD1 EVALFN PULD P Lay down RT scan combo and pick up VSP/GR combo tools 03:00 10:00 7.00 352 6,203 PROD1 EVALFN ELOG P RIH with VSP/GR combo and perform Vertical Seismic Profile, CGG seismic trucks operated on SE corner of pad. Shots taken at 30 depths. 1/ 10:00 11:00 1.00 6,203 0 PROD1 EVALFN PULD P PJSM and L/D VSP/GR tools, R/D wireline 11:00 12:00 1.00 0 0 PROD1 WHDBO RURD P Drain stack and pull wear bushing, R/U stack washer and flush stack, R/D stack washer. 12:00 12:30 0.50 0 0 PROD1 WHDBO RURD P R/U to test BOPE. 12:30 12:45 0.25 0 0 PROD1 WHDBO SFTY P PJSM on BOP testing. Page 22 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 17:15 4.50 0 0 PROD1 WHDBO BOPE P Test BOPE with 5"and 3.5"test joints.All tests with 5"test joint 5 minutes at 250/3500 psi.All tests with 3.5"test joint 10 minutes at 250/3500 psi per BLM regs. 5"test joint- #1-Upper Pipe rams, valve 1,12, 13, 14 and manual kill. #2-Upper IBOP, HCR kill,valves 9 and 11.#3 Lower IBOP,check valve, valves 5, 8 and 10.#4 Dart valve, valves 4, 6 and 7.#5 floor safety valve and valve 2.#6 HCR choke,4" Demco valve.#7 Manual choke valve, HCR kill.#8 Annular preventer,#9 lower pipe rams. 17:15 18:15 1.00 0 0 PROD1 WHDBO BOPE P Accumulator test-System pressure 2950 psi, pressure after closing all rams and annular 1800 psi.200 psi attained in 39 seconds,full pressure attained in 170 seconds, N2 bottle average 2075 psi. 18:15 21:15 3.00 0 0 PROD1 WHDBO BOPE P Install 3.5"test jt-Test Upper pipe rams, Lower Rams(BOP/Wellhead flange initial fail, lower ram door initial fail.Tighten and tested good 10 minutes 250/3500)and Annular preventer pass. Pulled test jt and tested blind rams 5 min good. Testing waved by AOGCC Bob Noble and BLM Justin Miller. 21:15 22:15 1.00 0 0 PROD1 WHDBO BOPE P Blow down choke manifold and rig down test equipment. 22:15 22:30 0.25 0 0 PROD1 CASING RURD P Clean and clear rig floor. 22:30 23:00 0.50 0 318 PROD1 CASING PULD P Pick up BHA#12, bit, bit sub,float sub, HWDP and Jars. 23:00 00:00 1.00 318 1,209 PROD1 CASING TRIP P RIH f/318'MD t/1209'MD. 04/19/2013 Completed cleanout run, L/D BHA#12.Change upper rams to 7"and test. Rig up and run casing to 4041' MD. Lost 80%returns while pumping. —� 00:00 02:15 2.25 1,209 6,119 PROD1 CASING TRIP P PJSM and continue RIH w/cleanout assy BHA#12 f/1209'MD t/6119' MD. Calc Disp=43.5 bbl,Actual Disp=43.4 bbl. 02:15 02:30 0.25 6,119 6,203 PROD1 CASING WASH P Fill pipe,wash and ream t/6203', 450 gpm @ 1050 psi,40 rpm @ 1k ft/lbs TQ. 02:30 03:30 1.00 6,203 6,203 PROD1 CASING CIRC P CBU x 3 reciprocating @ 6203'MD. 550 gpm @ 1400 psi,60 rpm @ 1k ft/lbs TQ. No fill, minimal cutting returns. 03:30 04:00 0.50 6,203 6,203 PROD1 CASING OWFF P Blow down top drive and observe well for flow-Static 04:00 08:00 4.00 6,203 370 PROD1 CASING TRIP P POOH, P/U off bottom 150k. Pull BHA from well, observing for flow at casing shoe and HWDP-Static. Calc Fill=55.1 bbl,Actual fill=59 bbl. Page 23 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 370 0 PROD1 CASING PULD P L/D BHA#12,clean and clear rig floor. 08:30 08:45 0.25 0 0 PROD1 CASING RURD P Pull wear bushing 08:45 10:30 1.75 0 0 PROD1 CASING RURD P PJSM and C/O top rams to 7". SIMOPS-C/O Drillers side tugger line. 10:30 12:00 1.50 0 0 PROD1 CASING BOPE P PJSM and R/U test equipment.Test 7"rams and annular preventer,250 psi/3500 psi 10 minutes. R/D test equipment. 12:00 14:45 2.75 0 0 PROD1 CASING RURD P PJSM and rig up 7"casing equipment. 14:45 15:15 0.50 0 0 PROD1 CASING SFTY P PJSM, running 7"casing. 15:15 20:00 4.75 0 2,320 PROD1 CASING RNCS P RIH with 7'casing per detail recording P/U and S/O every 10 jts. 20:00 20:30 0.50 2,320 2,320 PROD1 CASING CIRC P CBU at 2320'MD,2 bpm @ 375 psi-8%flow,3 bpm @ 425 psi-24% flow, 3.5 bpm @ 450 psi-36%flow. P/U 105k,S/O 75k. Reciprocate pipe 20'. 20:30 22:00 1.50 2,320 3,350 PROD1 CASING RNCS P RIH with casing per detail t/3350' MD, recording P/U and S/O every 10 jts. 22:00 23:00 1.00 3,350 3,350 PROD1 CASING CIRC T Attempt to CBU @ 3350'MD, 1 bpm @ 490 psi slight returns,2 bpm @ 480 psi 7%flow, 3 bpm @ 525 psi 24%flow,4 bpm @ 500 psi 43% flow. Observed 80%loss of return rate, reduced pump rate to 2 bpm with no improvement.Shut pump down and observe, no static loss. Attempted to resume circ @ 1 bpm, slight returns,2 bpm 340 psi with slight flow out. P/U 105k, SIO 75k. 23:00 00:00 1.00 3,350 4,041 PROD1 CASING RNCS P Contacted engineer, continue RIH with 7"casing to 4041'MD @ midnite. Reduced running speed from 40 fpm to 20 fpm due pushing mud away.Observing 50%pipe displacement while running in.Calc disp 34.6 bbl,Actual 26.23 bbl.Total lost to well including water added 15.87 bbl while running casing. 04/20/2013 Continue RIH w/7"casing to TD monitoring losses. Pump LCM pill,C&C for cement job. Pump cement job per program and displace with inhibited brine. Bumped plug,checked float and tested casing.Set packoff and test. R/U and UD 5"DP. 00:00 02:00 2.00 4,041 4,774 PROD1 CASING RNCS P PJSM and continue RIH w/7"csg t/ 4774'MD. 02:00 02:45 0.75 4,774 4,774 PROD1 CASING RNCS P Break circulation 1.5 bpm @ 500 psi, stage up U 2 bpm @ 525 psi, losses at 65 bph. Pumped 100 bbl, lost 58 bbl.Added 10 ppb Safe-Garb LCM to active while pumping. Page 24 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:30 0.75 4,774 4,774 PROD1 CASING OWFF P Observe well for flow.Well breathing slightly,gave back 6 bbl in 15 minute, 1.8 bbl the following 15 minutes, <1 bbl the final 15 minutes. 03:30 06:30 3.00 4,774 6,164 PROD1 CASING RNCS P Continue RIH w/7"casing t/6164' MD, P/U 195k,S/0 148k.Calc disp 21.6 bbl, actual displ-30.2 bbl. (51.8 bbl lost) 06:30 07:00 0.50 6,164 6,193 PROD1 CASING HOSO P M/U hanger and RIH t/6193'MD. 07:00 10:15 3.25 6,193 6,193 PROD1 CEMEN-CIRCP Circulate and condition @ 6180'MD @ 1 bpm,450 psi. Pumped 30 bbl xxxx ppb LCM pill,stage up to 4 bpm,600 psi. P/U 180k,S/O 150k. 10:15 12:00 1.75 6,193 6,193 PROD1 CEMEN-CMNT P PJSM and pump cement per program. Pump 5 bbl CW100,S/D and test lines to 3500 psi. Pump 35 t( bbl 8.4 ppg CW 100,40 bbl 12.0 ppg MudPush II,drop bottom plug. Pumped 50.4 bbl 15.8 ppg Class G Tail Slurry chased with 20 bbl 8.4 ppg water from SLB unit. 12:00 12:30 0.50 6,193 6,193 PROD1 CEMEN-DISP P Swap to rig pumps and displace cement with 180 bbl 10.0 ppg inhibited brine from truck and 29.9 bbl non-inhibited 10.0 ppg brine from pit 5. Displaced at 4.2 bpm to 1850 stks,3.1 bpm to 2000 stks and landed casing in hanger,then to 2 bpm. Bumped plug @ 2079 stks-600 psi. Bled off and checked floats,CIP @ 12:20. FC @ 6108.33', FS @ 6192.79'. 12:30 13:00 0.50 6,193 6,193 PROD1 CEMEN-PRTS P Test casing to 3500 psi for 30 minutes. (Charted) 13:00 14:15 1.25 0 0 PROD1 CEMEN-RURD P PJSM and rig down casing and cement equipment.Clear rig floor. 14:15 15:45 1.50 0 0 PROD1 CEMEN-PRTS P R/U and set 7"packoff,test to 5000 psi 10 minutes.SIMOPS-continue R/D csg equipment, L/D long baiils and P/U short bails and 5"elevators. R/U to lay down 5"Drill pipe. 15:45 22:15 6.50 0 0 PROD1 CEMEN"PULD P PJSM and L/D Jars and 5"DP. SIMOPS-attempted leak off test on OA with LRS.Annulus will not build pressure to lose. Pumped 100 bbl of 100 degree water to flush annulus, pressure @.5 bpm 225, 1 bpm @ 250, 1.5 bpm @ 275,2 bpm @ 300. No leak off. Initial SIP 225 psi,30 sec 210, 1 minute 200,3 minute 200.Waiting on LEPD from KUP for FP. 22:15 00:00 1.75 0 0 PROD1 CEMEN'RURD P PJSM(N/U Shooting flange)Clean and remove riser, install boot protector. Page 25 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/21/2013 24 hr Summary Rig up HES wireline and run guage ring/Junk basket,CST/CBL.C/O upper rams t/3.5"x6"and test.Test casing to 3500 psi. R/U and run 3.5"kill string t/2336'. Hang and RILDS, install TWC and test 2500 15 min. 00:00 02:00 2.00 0 0 PROD1 CEMEN"RURD P PJSM and continue R/D boot flange and N/U shooting flange. 02:00 04:30 2.50 0 0 PROD1 CEMEN-FRZP P PJSM, R/U and freeze protect OA with 65 bbl of LEPD from KUTP. ICP 275 psi @.5 bpm, unable to obtain LOT. FCP 500 psi @ 2 bpm,SIP 500 psi, no bleed down after 10 minutes. R/D Little Red Services. 04:30 08:00 3.50 0 0 PROD1 CEMEN"RURD P Spot wireline unit, R/U wireline, M/U tools-test lubricator to 2000 psi. 08:00 09:45 1.75 0 6,029 PROD1 CEMEN-ELNE P RIH with wireline run#1,6"guage ring and junk basket to 6029'MD, POOH. 09:45 10:45 1.00 0 0 PROD1 CEMEN-ELNE P L/D run#1 tools and pick up logging tools. 10:45 12:00 1.25 0 2,600 PROD1 CEMEN-ELOG P RIH with.wireline CAST/CBL holding 500 psi on casing. 12:00 15:00 3.00 2,600 6,029 PROD1 CEMEN"ELOG P Continute RIH with CAST/CBL tools holding 500 psi. POOH w/wireline holding 1500 psi on casing,TOC determined at 4606'MD. 15:00 16:30 1.50 0 0 PROD1 CEMEN-RURD P PJSM and R/D wireline. 16:30 18:00 1.50 0 0 PROD1 CEMEN"RURD P PJSM and N/D shooting flange and N/U riser. 18:00 20:00 2.00 0 0 PROD1 WHDBO BOPE P PJSM and C/O upper rams from 7" to 3.5"x 6"VBR. R/U and test to 250 psi/3500 psi 5 minutes each. 20:00 20:30 0.50 0 0 PROD1 WHDBO RURD P R/D testing equipment, retighten riser adapter on annular preventer. 20:30 22:30 2.00 0 0 PROD1 WHDBO PRTS P Rig up and perform casing test to 3500 psi, 30 minutes charted- flatline. SIMOPS rigging up to run 3.5"kill string. 22:30 00:00 1.50 0 936 PROD1 RPCOM RCST P PJSM and run 3.5"kill string per detail t/936'MD 04/22/2013 Run 3.5 tubing, land w/WLEG @ 2335.63'. Set TWC and test. N/D-N/U tree,test hanger seals,test tree. Freeze protect tubing and IA to 1500'with 52 bbl diesel. Rig is still on Cassin#6,waiting for trucks to move in field. Performing cleanup and maintenance. 00:00 01:45 1.75 0 0 COMPZ RPCOM RCST P PJSM and continue RIH w/3.5"kill string t/2307'MD. P/U 47k, S/O 50K. 01:45 02:15 0.50 0 0 COMPZ RPCOM THGR P M/U tubing hanger, land hanger and RILDS.WLEG @ 2336.55'MD/TVD. 02:15 02:45 0.50 0 0 COMPZ RPCOM PRTS P Set 2 way check,test t/2500 psi from below for 15 minutes. (Charted) 02:45 03:30 0.75 0 0 COMPZ RPCOM RURD P Monitor well and R/D surface lines. 03:30 05:30 2.00 0 0 COMPZ RPCOM NUND P PJSM and N/D BOPE, N/U tree. 05:30 06:30 1.00 0 0 COMPZ WHDBO PRTS P Fill void with hydraulic fluid,test upper and lower seals t/5000 psi for 10 minutes,witnessed by COP Drilling Supervisor. Page 26 of 28 1 Time Logs Date- From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:30 1.00 0 0 COMPZ WHDBO PRTS P Test tree to 5000 psi for 10 minutes. (Charted) 07:30 07:45 0.25 0 0 COMPZ WHDBO PRTS P Pull 2 way check. 07:45 08:00 0.25 0 0 COMPZ WHDBO RURD P PJSM and R/U circ lines, R/U Little Red Services. 08:00 09:00 1.00 0 0 COMPZ WHDBO FRZP P PT line t/2500 psi,open well and pump 52 bbl diesel down IA. ICP @ 1.5 bpm 200 psi, FCP 400 psi. 09:00 10:00 1.00 0 COMPZ WHDBO FRZP P Allow IA and tubing to U-Tube to 0 pressure differential.Set BPV. 10:00 11:00 1.00 0 COMPZ WHDBO PRTS P R/U Little Red to test BPV. PT line U 1500 psi.Test BPV f/below U500 psi (Charted). R/D Little Red. 11:00 12:00 1.00 0 COMPZ MOVE RURD P Blow down and R/D circ lines, secure well. 12:00 00:00 12.00 COMPZ MOVE DMOB P Prepare rig for move from Cassin#6 to Kuparuk 3C-09. Perform rig maintenance, clean cellar, rig floor, drop pan, cellar box,wellhead. Repair possum belly cracks. Perform MP2 on top drive, rig floor,top drive electrical. Replace 1502 wing halfs on rig floor. Prep jacking units for move. Blow down water,change out bucket rubbers. Haul small items as trucks are availiable to 3C-09. Release trucks. 04/23/2013 Rig is still on Cassin#6,waiting for trucks to move in field. Performing cleanup and maintenance. 00:00 12:00 12.00 COMPZ MOVE DMOB P PJSM-Change out saver sub to 4" for RWO.Work on rig move checklist,work on mud pumps, MP2's perform derrick inspection, complete welding projects on shakers. Freeze protect all pumps, test run all cold start generators, clean out vac unit. Empty all SAA's, oil and glycol prior to move, manifested and picked up by environmental. 12:00 00:00 12.00 COMPZ MOVE DMOB P PJSM-Continue working on rig move checklist. C/O Coomey bladder. Change roller bearing on R/W drag chain,generate and update procedures. Smooth out hammer unions on mudline, re-install kill line. 04/24/2013 Rig down camp,trucks delayed due to weather.Camp left Cassin#6 @ 23:30. 00:00 12:00 12.00 COMPZ MOVE DMOB P Prepare rig and camp for move. Waiting on trucks due to weather. 12:00 00:00 12.00 COMPZ MOVE DMOB P Prepare rig and camp for move. Trucks arrived and camp departed Cassin#6 @ 23:30 HRS. 04/25/2013 Camp arrived at 3C, modules en route on re-supply road. 00:00 12:00 12.00 COMPZ MOVE TRNS P Move rig camp to 3C pad. Lay containment and rig mats for rig. Page 27 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 COMPZ MOVE TRNS P Set up camp and send trucks back for rig modules.Arrange for tiger tank,wellhead service hand and kill weight fluid.. 04/26/2013 4 rig mods moved to 2M pad 00:00 12:00 12.00 COMPZ MOVE TRNS P Move pits, motors,pipe shed and rock washer to 2M pad. Lay rig mats around well 3C-09. Page,28 of 28 I` I 1 d ConocoPhillips (Alaska) Inc. NAD 27 jI1 North Alaska ASP5 Cassin API: 50103206660000 - PTD:212-196 ' Li 0 , 3 Sperry Drilling Services Definitive Survey Report 24 April, 2013 0 F IN -MK 1111111 HALLIBURTC Sperry Drilling Services .l Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD 27 Local Co-ordinate Reference: Well Cassin#6 Project: North Alaska ASPS TVD Reference: Cassin#6 @ 93.00ft(D141(65.6+27.4)) Site: Cassin MD Reference: Cassin#6 @ 93.00ft(D141(65.6+27.4)) Well: Cassin#6 North Reference: True Wellbore: Cassin#6 Survey Calculation Method: Minimum Curvature Design: Cassin#6 Database: EDM 2003.16 Single User Db Project North Alaska ASP5,Alaska 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 Cassin#6 Well Position +N/-S 0.00 ft Northing: 5,989,227.89 ft Latitude: 70°22'19.10 N +El-W 0.00 ft Easting: 732,051.49 ft Longitude: 148°6'49.57 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 65.60 ft Wellbore Cassin#6 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 3/30/2013 20.76 81.14 57,649 Design Cassin#6 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.40 Vertical Section: Depth From(TVD) +N/-5 +EJ-W Direction (ft) (ft) (ft) r) 27.40 0.00 0.00 146.15 Survey Program Date 4/24/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 224.37 6,132.92 MWD(Cassin#6) MWD MWD-Standard 03/29/2013 2,313.87 6,132.92 MWD(Cassin#6) MWD MWD-Standard 03/29/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 27.40 0.00 0.00 27.40 -65.60 0.00 0.00 5,989,227.89 732,051.49 0.00 0.00 UNDEFINED 224.37 0.87 123.86 224.36 131.36 -0.83 1.24 5,989,227.09 732,052.75 0.44 1.38 MWD(1) 312.96 1.42 130.97 312.93 219.93 -1.93 2.63 5,989,226.04 732,054.17 0.64 3.07 MWD(1) 407.60 1.44 132.83 407.54 314.54 -3.50 4.39 5,989,224.52 732,055.98 0.05 5.35 MWD(1) 499.72 1.42 128.60 499.64 406.64 -5.00 6.13 5,989,223.07 732,057.77 0.12 7.57 MWD(1) 589.84 1.36 131.10 589.73 496.73 -6.40 7.81 5,989,221.73 732,059.49 0.09 9.67 MWD(1) 685.12 1.37 134.44 684.98 591.98 -7.94 9.47 5,989,220.24 732,061.20 0.08 11.87 MWD(1) 775.25 1.26 134.04 775.09 682.09 -9.39 10.95 5,989,218.84 732,062.72 0.12 13.90 MWD(1) 870.75 1.36 133.90 870.56 777.56 -10.90 12.52 5,989,217.38 732,064.34 0.10 16.03 MWD(1) 963.17 1.24 134.35 962.96 869.96 -12.36 14.03 5,989,215.96 732,065.89 0.13 18.08 MWD(1) 1,056.19 1.19 133.24 1,055.96 962.96 -13.73 15.45 5,989,214.64 732,067.36 0.06 20.01 MWD(1) 1,148.92 1.15 133.21 1,148.67 1,055.67 -15.02 16.83 5,989,213.39 732,068.78 0.04 21.85 MWD(1) 1,242.10 1.15 133.92 1,241.83 1,148.83 -16.31 18.19 5,989,212.14 732,070.17 0.02 23.68 MWD(1) 4/24/2013 12:47:54PM Page 2 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD 27 Local Co-ordinate Reference: Well Cassin#6 Project: North Alaska ASP5 TVD Reference: Cassin#6 @ 93.00ft(D141(65.6+27.4)) Site: Cassin MD Reference: Cassin#6 @ 93.00ft(D141(65.6+27.4)) Well: Cassin#6 North Reference: True Wellbore: Cassin#6 Survey Calculation Method: Minimum Curvature Design: Cassin#6 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (C) (°) (°) (ft) (ft) (C) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,334.54 1.17 131.35 1,334.25 1,241.25 -17.58 19.56 5,989,210.92 732,071 59 0.06 25.50 MWD(1) 1,425.77 1.14 133.67 1,425.46 1,332.46 -18.82 20.92 5,989,209.72 732,072.98 0.06 27.29 MWD(1) 1,519.71 1.18 136.41 1,519.38 1,426.38 -20.17 22.26 5,989,208.42 732,074.36 0.07 29.15 MWD(1) 1,612.17 1.37 138.47 1,611.82 1,518.82 -21.69 23.65 5,989,206.94 732,075.80 0.21 31.19 MWD(1) 1,704.78 1.37 140.08 1,704.41 1,611.41 -23.36 25.10 5,989,205.31 732,077.29 0.04 33.38 MWD(1) 1,796.18 1.33 144.01 1,795.78 1,702.78 -25.06 26.42 5,989,203.66 732,078.67 0.11 35.53 MIND(1) 1,885.07 1.37 137.04 1,884.65 1,791.65 -26.67 27.75 5,989,202.09 732,080.05 0.19 37.61 MWD(1) 1,982.21 1.07 132.32 1,981.76 1,888.76 -28.13 29.21 5,989,200.67 732,081.56 0.33 39.64 MWD(1) 2,072.65 1.08 133.62 2,072.19 1,979.19 -29.29 30.46 5,989,199.56 732,082.83 0.03 41.29 MWD(1) 2,167.69 1.02 134.00 2,167.21 2,074.21 -30.49 31.71 5,989,198.39 732,084.13 0.06 42.99 MWD(1) 2,251.51 0.95 130.34 2,251.02 2,158.02 -31.46 32.78 5,989,197.46 732,085.22 0.11 44.39 MWD(1) 2,380.61 0.97 132.96 2,380.10 2,287.10 -32.90 34.39 5,989,196.07 732,086.88 0.04 46.48 MWD(2) 2,473.16 0.97 127.90 2,472.64 2,379.64 -33.92 35.59 5,989,195.09 732,088.10 0.09 47.99 MWD(2) 2,564.76 1.00 131.63 2,564.22 2,471.22 -34.92 36.79 5,989,194.12 732,089.34 0.08 49.50 MWD(2) 2,657.31 1.01 131.56 2,656.76 2,563.76 -36.00 38.01 5,989,193.08 732,090.59 0.01 51.07 MWD(2) 2,749.91 1.08 128.63 2,749.34 2,656.34 -37.09 39.30 5,989,192.04 732,091.92 0.10 52.69 MWD(2) 2,842.73 1.02 120.42 2,842.15 2,749.15 -38.05 40.70 5,989,191.12 732,093.34 0.17 54.27 MIND(2) 2,935.52 1.15 121.20 2,934.92 2,841.92 -38.95 42.21 5,989,190.26 732,094.88 0.14 55.86 MWD(2) 3,027.32 1.06 126.10 3,026.70 2,933.70 -39.93 43.68 5,989,189.33 732,096.38 0.14 57.49 MWD(2) 3,119.92 0.97 125.28 3,119.29 3,026.29 -40.89 45.01 5,989,188.42 732,097.74 0.10 59.03 MWD(2) 3,212.57 0.98 127.17 3,211.93 3,118.93 -41.82 46.28 5,989,187.52 732,099.04 0.04 60.51 MWD(2) 3,305.22 1.01 123.97 3,304.56 3,211.56 -42.75 47.59 5,989,186.63 732,100.38 0.07 62.02 MWD(2) 3,398.74 1.03 129.34 3,398.07 3,305.07 -43.75 48.93 5,989,185.68 732,101.74 0.10 63.58 MWD(2) 3,491.66 1.05 131.81 3,490.97 3,397.97 -44.84 50.21 5,989,184.62 732,103.06 0.05 65.21 MWD(2) 3,585.39 1.15 129.29 3,584.69 3,491.69 -46.01 51.57 5,989,183.50 732,104.46 0.12 66.94 MWD(2) 3,676.17 1.02 133.25 3,675.45 3,582.45 -47.14 52.87 5,989,182.41 732,105.79 0.17 68.60 MWD(2) 3,770.90 0.94 126.02 3,770.17 3,677.17 -48.18 54.11 5,989,181.41 732,107.06 0.16 70.15 MWD(2) 3,863.31 0.86 124.91 3,862.56 3,769.56 -49.02 55.29 5,989,180.61 732,108.27 0.09 71.51 MWD(2) 3,956.03 0.87 134.78 3,955.27 3,862.27 -49.91 56.36 5,989,179.75 732,109.37 0.16 72.85 MWD(2) 4,046.44 0.84 140.25 4,045.67 3,952.67 -50.91 57.27 5,989,178.78 732,110.31 0.10 74.18 MWD(2) 4,137.95 0.83 145.73 4,137.17 4,044.17 -51.97 58.07 5,989,177.74 732,111.14 0.09 75.51 MWD(2) 4,230.97 0.98 149.85 4,230.18 4,137.18 -53.21 58.85 5,989,176.52 732,111.96 0.18 76.98 MWD(2) 4,322.62 0.94 149.36 4,321.82 4,228.82 -54.54 59.63 5,989,175.22 732,112.78 0.04 78.51 MIND(2) 4,414.69 0.93 157.41 4,413.88 4,320.88 -55.88 60.30 5,989,173.91 732,113.49 0.14 80.00 MIND(2) 4,510.24 0.70 167.61 4,509.42 4,416.42 -57.16 60.73 5,989,172.63 732,113.95 0.28 81.30 MIND(2) 4,603.91 0.91 179.24 4,603.08 4,510.08 -58.47 60.86 5,989,171.34 732,114.13 0.28 82.46 MWD(2) 4,694.15 0.91 186.26 4,693.31 4,600.31 -59.90 60.79 5,989,169.91 732,114.10 0.12 83.61 MWD(2) 4,788.79 0.85 186.39 4,787.94 4,694.94 -61.34 60.63 5,989,168.46 732,113.99 0.06 84.72 MWD(2) 4,881.62 0.66 195.23 4,880.76 4,787.76 -62.54 60.41 5,989,167.25 732,113.81 0.24 85.59 MWD(2) 4,974.26 0.65 203.86 4,973.39 4,880.39 -63.54 60.06 5,989,166.24 732,113.48 0.11 86.22 MWD(2) 4/24/2013 12:47:54PM Page 3 COMPASS 2003.16 Build 73 • Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD 27 Local Co-ordinate Reference: Well Cassin#6 Project: North Alaska ASP5 TVD Reference: Cassin#6 @ 93.00ft(D141(65.6+27.4)) Site: Cassin MD Reference: Cassin#6 @ 93.00ft(D141(65.6+27.4)) Well: Cassin#6 North Reference: True Wellbore: Cassin#6 Survey Calculation Method: Minimum Curvature Design: Cassin#6 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD ' Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,067.04 0.78 223.19 5,066.16 4,973.16 -64.48 59.41 5,989,165.28 732,112.87 0.29 86.64 MWD(2) 5,145.13 0.80 231.83 5,144.25 5,051.25 -65.20 58.62 5,989,164.53 732,112.10 0.15 86.81 MWD(2) 5,250.94 0.65 228.63 5,250.05 5,157.05 -66.06 57.59 5,989,163.65 732,111.10 0.15 86.94 MWD(2) 5,292.12 0.63 230.85 5,291.23 5,198.23 -66.35 57.24 5,989,163.34 732,110.75 0.08 86.99 MWD(2) 5,345.25 0.54 233.58 5,344.35 5,251.35 -66.69 56.81 5,989,163.00 732,110.34 0.18 87.03 MWD(2) 5,437.06 0.66 227.16 5,436.16 5,343.16 -67.30 56.08 5,989,162.36 732,109.62 0.15 87.13 MWD(2) 5,530.47 0.67 232.03 5,529.56 5,436.56 -68.00 55.25 5,989,161.63 732,108.82 0.06 87.25 MWD(2) 5,622.99 0.67 233.79 5,622.08 5,529.08 -68.66 54.39 5,989,160.95 732,107.98 0.02 87.32 MWD(2) 5,717.60 0.60 238.14 5,716.68 5,623.68 -69.24 53.52 5,989,160.34 732,107.13 0.09 87.32 MWD(2) 5,807.07 0.62 245.15 5,806.14 5,713.14 -69.70 52.68 5,989,159.86 732,106.30 0.09 87.23 MWD(2) 5,901.19 0.68 285.43 5,900.26 5,807,26 -69.76 51.68 5,989,159.76 732,105.31 0.48 86.73 MWD(2) 5,992.37 0.94 271.74 5,991.43 5,898.43 -69.59 50.41 5,989,159.89 732,104.03 0.35 85.88 MWD(2) 6,085.04 0.85 232.99 6,084.09 5,991.09 -69.98 49.11 5,989,159.46 732,102.74 0.65 85.48 MWD(2) 6,132.92 0.91 220.73 6,131.96 6,038.96 -70.49 48.57 5,989,158.94 732,102.22 0.41 85.60 MWD(2) 6,203.00 0.91 220.73 6,202.04 6,109.04 -71.33 47.85 5,989,158.08 732,101.52 0.00 85.89 PROJECTED to TD 4/24/2013 12:47:54PM Page 4 COMPASS 2003.16 Build 73 w w*�OF �. THE STATE Alaska Oil and Gas __ conservation Commission wh GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0 5 1• Anchorage, Alaska 99501-3572 ALAMain: 907.279.1433 Fax: 907.276.7542 David Lee Senior Drilling Manager Conoco Phillips Alaska, Inc. l — qb P.O. Box 100360c;,), Anchorage, AK 99510 Re: Wildcat Field, Wildcat Pool, Cassin 6 Sundry Number: 313-194 Dear Mr. Lee: 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, D.. el T. Seamount, Jr. Commissioner DATED this 2fday of April, 2013. Encl. • STATE OF ALASKA RECEIVED A CA OIL AND GAS CONSERVATION COM >ION APR 2 2 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 0 1.Type of Request: Abandon E Shu for Redrill Perforate New Pool d �ra yp q � �v g (" I-" Repair w ell ('-"" Change Approve Program Suspend 't• Plug Perforations E Perforate f` Pull Tubing f- Time Extension F- Operational Shutdown E Re-enter Susp.Well fW Stimulate (" After casing (- Other:lnstall Kill String Cv 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development l Exploratory W. - 212-196 • 3.Address: 6.API Number: Stratigraphic I— Service F- P. O. Box 100360,Anchorage,Alaska 99510 _ 50-103-20666-00 • _ 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes 1" No Cassin 6• 9.Property Designation(Lease Number): 10 Field/Pool(s): AA 081833 • Wildcat • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured). Junk(measured): 6203 • 6203 6203' 6203' none none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2286' 9.625" 2314' 2314' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none none none none Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal fri. 13. Well Class after proposed work: Detailed Operations Program I"" BOP Sketch F- Exploratory f . Stratigraphic ( Development I— Service f-" 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/20/2013 Oil 1— Gas I- WDSPL E Suspended f� • 16.Verbal Approval: Date:4/19/2013 WINJ Imm GINJ r WAG I" Abandoned I-" Commission Representative: Guy Schwartz GSTOR I- SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Lee @ 263-3741 Email: David.L.Lee@conocoohillios.com Printed Name David Lee 3Title: Senior Drilling Engineer ,, , Signature ' i(`` ,.�` Phone:263-3741 Date ,_.S, I -< 2\,_ ,)�'j Commission Use Only Sundry Number: 3( 3_04 Conditions of approval:alNotify Commission so that a representative may witness Plug Integrity ✓ BOP Test E Mechanical Integrity Test IW Location Clearance r Other. RSOMS APR 2 5 2010 Spacing Exception Required? Yes ❑ No [✓( Subsequent Form Required: /b •,•y0 Z Cplvlfvl APPROVED BY �Z�/`� Approved by- proved a{ icat-ie�a is va TOrr1.99 nths from thTc� RM1301 val. Date: / orrRie1sM/, 2L � e �� ; Y1�/3 Submit Form and Attachments in Duplicate g1k,h1I�� yX / G2 1 `tel ConochiIIips ConocoPhillips Alaska Inc. NPRA Exploration Program Cassin #6 Supplement Completion Program (Kill String Only) Version 1.0 04/17/2013 Program Prepared by: Reviewed by: Dadang Kurnia David Lee Staff Completion Engineer Senior Drilling Engineer Reviewed by: Review by: Tom Brassfield Kerry Freedman Staff Drilling Engineer Principal Completion Engineer APPROVED BY: CONCURRED BY: CONCURRED BY: Liz Jolley Bowen Roberts Chip Alvord Supervising Drilling Engineer Completions Manager Drilling Manager Cassin#6—NPRA Exploration Page 1 of 8 Supplement Completion Program v1.0 Aki ,�; ConochiIIips 1. Scope of Change This supplement completion program is intended to document a revision and scope of changes have been made to the approved Cassin#6 Drilling and Completion program dated 02/22/2013. The primary reason for these changes is mainly due to the remaining time before the end of the ice road season would not sufficient to complete the well as per original plan. Therefore a kill string will be run and the well will be suspended. The following are scopes of change: • '-10ppg inhibited kill weight brine will be used to displace top cement plug. • No well clean out will be performed. • The well will not be perforated and completed as originally planned and a 2200 ft of 3-1/2"tubing kill string will be hang off on the tubing hanger. Summary of Proposed Changes NOTE: At the end of the cement job, lOppg inhibited kill weight brine will be pumped as displacement. Continue as per original program to pressure test casing to 3500psi for 30 monites. 1. RU Eline.Run 6"Gauge Ring and Junk Basket prior to running CBL log. 2. Perform CAST/CBL log. 3. RD Eline. 4. Run Kill String and Land Tubing Hanger 5. Install a 2-way check valve 6. Nipple down the BOP stack and Nipple Up X-tree.Pressure test X-Tree. 7. Retrieve 2-way check ---te - r k ,ti Ce.sT wl1�SF4 ,., , .,--�/ `''"`I -- 8. Freeze protect well and install a back pressure valve 9. Rig down and move rig to Kuparuk Cassin#6—NPRA Exploration Page 2 of 8 Supplement Completion Program v1.0 ConocoPhillips 2. New Proposed Wellbore Schematic Cassin #6 ConocoPhillips Proposed Kill String Configuration Alaska Conductor(Driven): 16"Condador 108' � i Kill String: 1)3-%'Tubing Hanger 2)3-%z"9.3#EUE Tubing(--22OOft) 2 Production Tubira: 3'/:,9.3#L-80,EUE 8RDR2 i f SurfaceCasino: ALP 9-58",40#,L-80,BTC Set @2,314"MD/2,314"T O TOC+1-XXXX'IuU 1XXXX'TVD 500'above the top Zone — — Cassin Sand(Un-perforated) @ 5,314"—X,XXX'(XX') Blackburn Sand(U n-neferated) @ 5,765"—X,XXX'(XX') Sanford Sand(Un-0eforated) @ 5,910"—X,XXX'(XX') production Casino 7",26#,L-80,BTC-Mod Set @ 4,698"MD 14,698"TVD 7",29#,P110,BIC Set @ 6,198"MD 16,198"TVD Cassin#6—NPRA Exploration Page 3 of 8 Supplement Completion Program v1.0 ConocoPhillips wouiw aoa O► lA1.ON�ANS� VLO►MaNl 3.1. Run Cement Evaluation Log (Phase: COMPZN) Well Status: • The 8-1/2"Production hole has been drilled to TD at 6,203 ftMD and cased with 7"29ppf P110 BTC casing(6198'-5000')and 7"26ppf L-80 BTC casing(5000'to surface). • RA pip Tag at- 4,050' MD and 5,050' MD. • Casing pressure was tested to 3500psi for 30 minutes • Wellbore is filled with l0ppg inhibited 6%KC1/NaC1 KW brine. • Wear Bushing is installed. Objectives: • HS&E—No accidents, incidents, or spills • Run 6" Gauge Ring and Junk Basket to tag bottom • Run combo CAST-M/CBL cased hole log to evaluate the cement bond/quality in the 7" production casing. Safety: • Hold a safety meeting with the rig crews E-line crew and all contractors. Write and review a JSA to ensure that everyone involved understands the logging operation and the risks involved. • When dealing with high pressure during pressure testing, make sure personnel avoid high exposure areas. • Make sure everyone is aware of his or her responsibilities. Interval Notes: • The cement bond log will be run under pressure 1500 psi. • Rig up the a-line pressure control equipment and pressure tested to 2000 psi to facilitate a logging pass under 1,500 psi. The grease injector head will be used. Interval Procedures: 1. R/D the bell nipple and flow line on top of the annular preventer and replace them with a 5K 4 1/16" R-39 shooting flange. 2. P/U 7"Riser with Otis Connection and make it up to the shooting flange. NOTE: This should place the top of the lubricator+/-3.5' above the rig floor. 3. R/U the Halliburton E-line unit and PCE as per Halliburton(or refer to Attachment 20 in the Original Procedure) Note: Grease injector head will be used as part of PCE. 4. Strip the E-line through the PCE and test the line for continuity. 5. MU 6" Gauge Ring/Junk Basket with GR/CCL. 6. Stab back the Otis Connection on Riser. 7. Using the rig pumps,pressure test the PCE against casing to 2,000 psi for 10 minutes before RIH. Cassin#6—NPRA Exploration Page 4 of 8 Supplement Completion Program v1.0 ConochiUips 8. RIH with the Gauge Ring until tag PBTD. Note: Notice and record the PBTD tagged or if tag any fills. Note: Notice and record if recovery on Junk Basket. 9. Pull out of hole and lay down gauge ring/junk basket tool. 10. M/U the CAST-M/CBL-M logging tool and lower the assembly into the well. 11. Stab back the Otis Connection on Riser. 12. Using the rig pumps, pressure test the PCE against casing to 2,000 psi for 10 minutes before RIH. 13. RIH with the logging tool to the landing collar. 14. Pressure up casing to 1500 psi and perform log up to 1,000' above the calculated top of cement at the required speed to obtain quality data. (Maximum running speed 45'/min.) NOTE: check with Schlumberger lab for UCA to ensure the cement has reached a minimum of 500 psi compressive strength. 15. Pull out of hole and lay down CAST-M/CBL-M tool. 16. E-mail a PDF version of the field prints to the Drilling & Completion Engineers as soon as they are available. 17. Forward hard copies and electronic versions of the processed logs to the Drilling& Completion Engineers in Anchorage as soon as they are available. 3.2. Run Kill String (Phase: COMPZN) Well Status: • The well filled up with l Oppg inhibited kill weight brine. • Casing has been pressure tested to 3500psi for 30 minutes • The well has not been perforated. • Wear Bushing is installed. Objectives: • HS&E—No accidents, incidents, or spills • Run Kill String • N/D the BOPs and N/U Tree • Pump Freeze Protect • Install BPV • Suspend the well • Move the rig off location Safety: • Hold a safety meeting with the rig crews and all contractors to ensure the driller and workers understand the work objective. Cassin#6—NPRA Exploration Page 5 of 8 Supplement Completion Program v1.0 ConocoPhiflips NOlTN lLOM Or�RAT10NR ANY Y�V�LO/MINT Interval Notes: • Drift the 3-1/2", 9.3#, EUE tubing with a 2.867" OD rabbit. • Ensure to retrieve wear bushing before landed tubing hanger assembly. Drain BOP and Clean as necessary. • Use Jet Lube"Run-N-Seal" connection dope for EUE Connection. Interval Procedures: 1. Hold a safety meeting with the rig crews and all contractors to ensure that the driller and workers understand the order of the work. 2. Change Top Pipe Rams for running tubing. Test pipe rams to 250 psi Lo and 3500 psi Hi. 3. Pull wear bushing. Make up wash tool. Jet wash to clean around the tubing hanger area to ensure no debris. 4. MU 3-1/2"Tubing Hanger(FMC)to the TH Running tool and Landing Join. LD same. Note: Drift all the 3-1/2"Tubing with 2.867"Teflon drift. Discuss the importance of drifting all tubing and history or effects of not drifting. 5. Run—2200ft of 3-1/2"9.3ppg Tubing./ 6. Make up the tubing hanger assembly to the last joint of tubing and orient the completion so the hanger matches up with the centering guide in the tubing bowl. 7. Land tubing hanger and Run in Lock Down Screws. Pull and lay down landing joint A. Install 2-way check into tubing hanger. Install landing joint B. 8. Pressure test upper hanger seals (250 psi for 5 minutes, 5000 psi for 10 minutes). Chart tests. 9. Pressure test 2-way check and tubing hanger from below(directional of flow)through the casing valve to 2500psi for 15 minutes. Chart tests. (Note: the well is treated as well category 3; located in a"sensitive area" and/or capable to flow greater than 3 MMscfd). 10. Bleed off pressures. 11. Pull and lay down landing joint B. 12. Flush stack to clean up if needed. 13. Observe well for 30 minutes to confirm that the well is static. 14. The Company Man will verify the following barriers are present before ND BOP stack: 1)Kill weight fluid in tubing, 2)Kill weight fluid in inner annulus, 3)Two way check in tubing hanger,pressure tested from below, and 4)Tubing hanger pressure tested from below. 15.ND BOPE.NU tree and adapter. Note: Carefully lower the tree with tubing bonnet not to damage the tubing hanger neck. Cassin#6—NPRA Exploration Page 6 of 8 Supplement Completion Program v1.0 g =� ConocoPhillips ..oar..sonE o...wsora�wtio svuo�wMt 16. Pressure test the flange connection through the test port located on the tubing bonnet flange to 5,000 psi for 10 minutes. This will test the upper hanger seals from below and the lower hanger seals from above. 17. Rig up lubricator and pull two way check valve. 18. Rig up manifold&hard lines to tubing& annulus. 19. Freeze protect well by pumping annulus (53 bbl) of diesel (± 1500 ft TVD). Put tubing and annulus into communication across choke manifold and allow diesel to percolate on the annulus. • 3-1/2"tubing capacity = 0.0087 bbl/ft • 3-1/2"tubing x 7" casing annulus capacity=0.0264 bbl/ft • Total volume= 1,500' MD x(0.0087+0.0264)bbl/ft= 53 bbls 20. Shut in well &Rig down lines. 21. Rig up Lubricator& set BPV. 22. Secure well. 23. Lay down drill pipe&prepare rig for moving. 24. Turn well over to operations via handover form. NOTE: Handover Form must be filled out, signed by all involved parties(Drilling, Wells, & Production), scanned, &posted. Following through on this critical detail will ensure a reliable resource for the Production Engineer to reference during the planning&execution of post rig work. Cassin#6—NPRA Exploration Page 7 of 8 Supplement Completion Program v1.0 • ConocoPhillips MORIN SLOP.Or..ATIOMa AMC,Y.V.IOrY.MT Attachments 1 (Proposed Well Schematic Suspended) Cassin #6 ConocoPhillips Proposed Kill String Configuration Alaska BPV Conductor(Drivel): 16"Condictor108' Kill String: 1)3-Yi Tubing Hanger Freeze Protect ,4 2)3-'/i 9.3#EUE Tubing(-2200ft) o to 1500' 2 Production Tubing: r 3'r',9.3#L-80,EUE 8RD R2 r i 4 i 4 S urface Casino 4 9-50,40#,L-80,BTC Set@ 2,314"MD 12,314"TVD 10ppg Kill Weight Brine TOC+/-XXXX'IIi 1XXXX'TVD 15 500'above the top Zone — Primary Barriers: 1)Production Casing(un-perforated) 2)Tubing Hanger Seals 3)IA AnnulusVatve Secondary Barriers: Cassin Sand(Un-perforated) 1)BPV @ 5,314"—X,XXX'(XX') 2)Kill weight Brine Blackburn Sand(Un-perorated) @ 5,765"—X,XXX'(XX') .' C Sanford Sand{Unireforated) 1 @ 5,910"—X,XXX'(XX') ; " Production Casino 7",26f,L-80,BTC-Mod Set @ 4,698"MD 14,698"TVD 7",29#,P110,BTC Set @ 6,198"MD 16,198"TW Cassin#6—NPRA Exploration Page 8 of 8 Supplement Completion Program v1.0 • j-)7 ZIz - l 'IC, Cassin #6 ConocoPhillips Proposed Kill String Configuration Alaska Color(Drwelr ;6-�:!x.-tmx 1011? 1 Kill StnnQ r 1)3-W Tubing Hanger Freeze Protect ! ( 2)3-W 9 3#EUE Tubing(-2200ft) I WoAretbn i1W0IN s ; 3':_93IL80,EUEERC;F.: r. r fISOO' 9 +g�i / .:,1 l i g A s Si laceGm r f. 9•Sl8",4011,L.80,BTC 1 Set lre 2,314"M0'f 2,314"T 1 r 1 ... r l Oppg III 1 V-tA)� Weight Brine MC•t•xxixhgvxxxx•Tw ' 500'above theta[.:_•._ i Prmary 8arners .,...... 1)Production Castog On-perforated) 2)Turing Hanger Seats W Annulus Vallee i Secondary Barriers C»dr154rld Nn mileti ed, 1)B PV �$•3t4'—v.,x::.r, I' : 2)Kli weight Brine Wtaaientn Sind N!lDdaroleQ s 02 5,765"—%)XXX'(XX') A $ardadc4 dfttnorinr..1rd1 Alp 5,310'-x XxY.'(-r.x �' ,i Prudurticn Covina "i`�"a". ': €s,L-80.BTC-Moo S et a 4,6918"MD i 4,198"TVD 7",29s,P1 10,BTC seek6,193"PAD r6,19B•TW From: Schwartz, Guy L(DOA) [ i:guy.schwartz@alaska.gov] Sent: Friday, April 19, 2013 1:28 PM To: Lee, David L Cc: Bettis, Patricia K (DOA); Regg, James B (DOA) Subject: [EXTERNAL]RE: Cassin #6 - 212196 Completion Strategy David, Ok... please send a revised well schematic showing how the well will be left. 2 ' Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Lee, David L [mdiito:Davtc,i. Lee_<<conocophilips.con-l] Sent: Friday, April 19, 2013 1:27 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA); Regg,James B(DOA) Subject: RE: Cassin #6 - 212196 Completion Strategy Yes we are planning on running a CBL prior to running the kill string. Thanks DL From: Schwartz, Guy L(DOA) [mailto:0u✓.schv✓artz aalaska.gpv] Sent: Friday, April 19, 2013 11:29 AM To: Lee, David L Cc: Bettis, Patricia K(DOA); Regg, James B (DOA) Subject: [EXTERNAL]RE: Cassin #6 - 212196 Completion Strategy David, Thanks for update... we discussed this earlier. You have approval to suspend Cassin #6 as proposed with Kill String with the understanding that no perforations will be added to the casing 7" production casing and filled with KWF. Are you planning on running CBL this year? Notify inspector to witness the 7" casing pressure test- 3000 psi ( chart/30min ) as per step 17 in the approved PTD. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Lee, David L[mailto:David.L.Le aconoc.ophillips.com] Sent: Friday, April 19, 2013 10:54 AM To: Schwartz, Guy L(DOA) Subject: Cassin #6 - 212196 Completion Strategy Guy,as mentioned on the phone,due to ice road timing Cassin 6 is now just going to be completed with a 3 3.4"kill string down to 2200'. We will displace our cement plug with 10.0ppg inhibited kill weight brine so kill weight fluid will be left inside the casing and no perforations will be put in the casing. If you have any questions or concerns please let me know. Thanks David 3 06-55(ii Regg, James B (DOA) From: Doyon 141 Company Man [n1334@conocophillips.com] Sent: Monday, April 22, 2013 9:03 AM To: Regg, James B (DOA) Fels 4k�/( Cc: Lee, David L Subject: FW: Attachments: Cassin#6 7 inch casing test chart.pdf Jim, Attached is a scanned copy of the test chart for the pressure test of the 7" production casing on Cassin#6 that was performed on April 21, 2013. Please inform us if any other information is required. Guy Whitlock/ Rob Reinhardt Drilling Supervisors Doyon 141 670-4963 office 670-4976 Rig floor 141 Company Man ,April 22,2013 8:59 AM F1 Company Man 1 C'a55-14-6, ANN. Nim Tr • soi°� ��` '411111 Wyk ;01 1001.11 .--== ."-_ 1"11%11111741L4 -1111pb IN. pi,„wrotar ,„,,, ,,,,,,...„ sitSw,,,„,asTw&v,,,w,„„,..,,,„iii . ••11110,50„„, .., Onsizzate #4 1b kW %iv,AV %\ ‘,ckva°°0%MLA drelett �.ao7F,� y ' mMNd1141111 )J: i1lJ! ii1iJ"lIlIIIIJJJJJii441. 4/1, bri,40 ,o. 0lit v.N � 4\10 �� V\ X MtswLsYu#4I'4,t4'/*g 110 pt • NO 4% 4eP4': 1 le,.....-so '-• / *SOS , ,/ 111/#1/0 YY y ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT00340 TO: Patricia Bettis, Petroleum Geologist ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Cassin 6 Permit: 213-196-0 DATE: 04/15/2013 Transmitted: North Slope, Alaska Cassin 6 (501032066600) CD /digital data RECEI V 4. I P ---- Cassin 6, LWD MAD logging pass data; Halliburton. AOGCC ,. 2390 1 The RDT tool for the Cassin#6 Well is currently being run, so CPAI does not as yet have the data bottom hole formation pressure for the well. CPAI anticipates the pressure will be similar to the reservoir pressure measured in the Cassin#1 Well,being 2503 psi at 5711 ft. MD/ 5705 ft. TVD. This is equivalent to an 8.5 ppg mud weight. CPAI will provide an update once actual pressure for the Cassin #6 well is available. *The information provided hereunder by ConocoPhillips Alaska, Inc., as Operator of the Bear Tooth Unit ("ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 2.0 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Cassin 6-e- nsmittal well folder t. c7 . /3 Receipt: 4‘...S/ 'y—e_–E_.--e---------- Date: ~ IIIIIAK/IT-Technical Data Management I ConocoPhillios I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.Lemk&.Conocophillips com . l2, , Ccv, 312'' 1460 RECE1VL2 APR (; 20'; ConocPAOGCC hillips o Alaska,Inc. P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 I i Jeanie M.Shifflett - Emergency Planning Coordinator,ATO 1990 (. ^I\/F Telephone 907-265-6488 -- ,- E-mail Jeanie.M.Shifflett@conocophiilips.com April 9, 2013 1%J4 - f Y'i i ro i r,:'f`:' t:°? i�t Ofi HAND DELIVERED tivfror�►r mill Corrervatioil Mr. Graham Wood Section Manager Alaska Department of Environmental Conservation Division of Spill Prevention & Response Industry Preparedness Program Exploration, Production and Refineries 555 Cordova Street Anchorage, AK 99501 RE: Request for Temporary Amendment of Seasonal Drilling Restriction Cassin #6 Well North Slope Exploration Oil Discharge Prevention and Contingency Plan ("Plan") ADEC Plan Number 12-CP-5096 Extended Operations for Cassin Drilling in NPR-A North Slope, Alaska CPAI Contract No. CO 206223 Dear Mr. Wood: CPAI seeks a temporary amendment to the seasonal drilling restriction as set out in the July 20, 2012, letter from the Alaska Department of Environmental Conservation ("ADEC") to CPAI, approving CPAI's Plan. ADEC's letter included Condition of Approval #7 ("Condition 7") that reduced the drilling season by requiring isolating the hydrocarbon zones with cemented casing by April 21 or April 24, depending on type of access to the well location (i.e., access without or with ice road). Previous Plan approval required that drilling into a hydrocarbon formation had to cease by those dates, but did not specify timing for cementing of the casing. In a letter dated August 7, 2012 ("CPAI Letter"), CPAI notified ADEC of concerns regarding the new restriction in Condition 7. Still, CPAI expected to be able to comply with the condition, and we have sought to do so. CPAI is currently conducting drilling operations for the Cassin #6 Well ("Well") located within the Bear Tooth Unit and in NPR-A ("Operations"). Last week, CPAI met with ADEC representatives to discuss the impact of Condition 7 on the Operations. Many factors contributing to the current situation were discussed at the meeting, including delayed ice road access, weather delays, and pians for coring programs needed to evaluate the formation, in support of the temporary amendment to Condition 7. As stated at the meeting, CPAI will cease drilling into the hydrocarbon formation of the Well by April 24th as ConocoPhIllips Alaska,Inc.Is a Subsidiary of the ConocoPhillips Company April 9, 2013 Page 2 prescribed by Condition 7; however CPAI requests a temporary amendment to the seasonal drilling restriction for the Well to allow CPAI to perform other non-drilling operations through May 1, 2013. Non-drilling operations primarily will include formation evaluation (wireline logging), well clean out, and running liner prior to cementing at the hydrocarbon zone(s). In support of the CPAI's request, CPAI hereby submits the confidential slides attached hereto covering the Well, Operations, and spill mitigation measures. CPAI requests the information provided to ADEC hereunder by CPAI be held confidential. CPAI also requests the information be held confidential by the Alaska Oil and Gas Conservation Commission ("AOGCC") if it is provided to AOGCC because it contains information or data that is exempted from disclosure under 20 ACC 25.537 (b). Accordingly, CPAI as Operator, on behalf of itself and the other working interest owners in the Bear Tooth Unit, hereby requests that Condition 7 be temporarily amended to allow CPAI to complete the cementing of the casing for the Cassin #6 Well by May 1, 2013. unless earlier required to comply with tundra travel restrictions. CPAI understands any temporary amendment to Condition 7 will only extend the timing for conducting non-drilling operations of the Well in 2013. 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CD UC 0 o O N E' i5 O U vv) N Cl.) cts ° ON = a) E v � � � cu U a� ( > v > L QitQ C Oa--+ — – O sis 4- wimmJ C • > Ci a) V) L- 0- •- N •– V) ca U c• E O O � 75 N Q c6 Q — N N a, COcc C x iniumi rt3 _C -0 • Nom. _C2 _ c ••(T.) — — a) r...1 CC lD -0 CU C C1 O •O- m N J "0kk ��., cin iJ O �, c -a O ate-+ CO .0 U N - (6 p p 0 p vI N •v) (0 C a) N •v) t13 _a �r < Q) Q Q (0 CO N 0- Imo— Q +_' a 0_ • �a: V O I I I CL CI U 1 1 1 I L a 6 d O UO (,,r) • • O g O ConocoPhillips Alaska, Inc. P. O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Dora I.Soria Land Department,ATO 1480 Telephone 907-265-6297 Facsimile 907-263-4966 E-mail dora.i.soria@conocophillips.com April 12, 2013 HAND DELIVERED Ms. Patricia Bettis, Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 RE: Request for Additional Data for the Cassin #1 and Cassin #6 Wells Temporary Amendment of Seasonal Drilling Restriction for the Cassin #6 Well Extended Operations for Cassin Drilling in NPR-A CPAI Contract No.CO 206223 Dear Ms. Bettis: Your e-mail message dated April 9, 2013, requested ConocoPhillips Alaska, Inc. ("CPAI") provide the Alaska Oil and Gas Conservation Commission ("AOGCC") additional information by noon on April 12, 2013, in order to support the Alaska Department of Environmental Conservation ("ADEC") in their evaluation of CPAI's request to extend the seasonal drilling for the Cassin #6 Well. In response to your request, CPAI as Operator, on behalf of itself and the other working interest owner in the Bear Tooth Unit, hereby submits the data identified on Exhibit A attached hereto (collectively "Data") and requests the information be held confidential by AOGCC because it contains information or data that is exempted from disclosure under 20 ACC 25.537(b). Please let me know if you have any questions regarding the Data. CPAI appreciates AOGCC's attention to this matter. Sincerely, .e. Dora I. Soria Staff Landman DATA WAS RECEIVED BY AOGCC BY: A A AAA NAME: Gran lf/t I1Jheif TITLE: C-Ye /j gECEIVED S � I'iO i «. .a 2013 DATE: TIME: AOGCC ConocoPhillips Alaska,Inc.is a Subsidiary of the ConocoPhillips Company EXHIBIT A DATA Disc containing the following digital files: PDF of Mudlogs - Cassin 1 Surface to TD - Formation Log Cassin #6 5300-5825 - Cassin #6 MUD LOG 108 TO 5329 FT LAS files - Cassin 1_FE_Rec_LWD_LAS.las - Cassin_1_R400_Prelim_Sonic.las - Cassin_6_FE_Merged_100_5330.1as - Cassin_6_R300_Preliminary_Processed_XBAT.las Paper files: Core Descriptions - Cassin #1 Well, Rotary Core Descriptions; Cores 1-60 - Cassin #6 Well, Core Descriptions; Core No. 1 (2 copies) - Drilling Operation Summaries dated 4/04/2013-4/11/2013 The information provided hereunder by ConocoPhillips Alaska, Inc., as Operator of the Bear Unit ("ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). ConocoPhillips Alaska,Inc.is a Subsidiary of the ConocoPhillips Company -Pi , aP -11-(9cvs So l ,K'«S The information provided hereunder by ConocoPhillips Alaska, Inc., as Operator of the Bear Tooth Unit(Conoco"), is confidential Hyden, Brittney B and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). From: Lee, David L ,(J. f-- c.," fro(•.Nk,ii Sent: Thursday, April 11, 2013 6:33 AM To: (sblair@miswaco.slb.com); Alldredge, Paul (Halliburton); Alvord, Chip; Bearden, Daniel '' D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin;Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel, Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston, Jenna K (Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B; Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);John Yocum;Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Holta; Myers, Monty M; NSK Expl Env; NSK Fld Drlg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R. Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I; Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge, Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com);waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/11/2013 Summary of Operations 4/10/2013 -Finished coring on our second coring run at 5683' MD. 180' of core cut on second run. -POOH with core and lay down core at surface. 100% recovery. -Ship core back to Anchorage -Make up 180' of new core barrel and RIH to 5683' -Core from 5683'to 5739' MD Current Operations 006:00 -Finished cutting core at a depth of 5863' (143' of core cut) and now pulling out of hole at 4600' following trip schedule. 24 Hour Forecast - POOH with 3rd set of core -Ship core to Anchorage -Test BOP -Make up drilling BHA and drill down to top of brown sand NOTE: -488' of core cut so far Give me a shout with any questions or concerns Thanks David 1 CONFIDEPAI The informs' -ovided hereunder by ConocoPhillips Alaska. Inc., as Operator ;Bear Tooth Unit(ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from Hyden Brittney B disclosure under 21,A, AC 25 537(b). AUo4- From: Lee, David L Sent: Wednesday, April 10, 2013 6:47 AM To: (sblair@miswaco.slb.com);Alldredge, Paul (Halliburton); Alvord, Chip; Bearden, Daniel D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin; Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel, Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston, Jenna K (Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B;Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);John Yocum;Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Holta; Myers, Monty M; NSK Expl Env; NSK Fld Drlg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R. Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I; Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge, Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com); waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/10/2013 Summary of Operations 4/9/2013 -Finish tripping out of hole following our coring program -Lay down core and prep core for transport -Core transported to Alpine via heated van, core then flew from Alpine to Anchorage by chartered flight. Core then moved from airport to Weatherford lab. -Pick up 180' of coring assembly and RIH -Core from 5503'to 5657' Current Operations @06:00 -Finished cutting core at a depth of 5683' (180' of core cut) and now pulling out of hole at 2360' following trip schedule. 24 Hour Forecast - Finish POOH and lay down core and core barrels -Make up 180' coring BHA -RIH and core rest of shale in-between Blackburn and Sanford as well as the Sanford sand NOTE: Next BOP test is due tomorrow by midnight, and the plan is to do the test after the next coring run is completed. Give me a shout with any questions or concerns Thanks David 1 CONRDENflAL The informal vided hereunder by ConocoPhillips Alaska, Inc., as Operator L Bear Tooth Unit(ConocoPhillips"). is confidential and proprietary to ConocoPhillips-andis not subject to disclosure because it contains inforpation or datatbat-is exempted from disclosure under 20AAC 25.537(b)- Hyden, Brittney B From: Lee, David L Me) Sent: Tuesday, April 09, 2013 7:23 AM To: (sblair@miswaco.slb.com);Alldredge, Paul (Halliburton);Alvord, Chip; Bearden, Daniel D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin;Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel, Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston,Jenna K (Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B;Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);John Yocum;Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Holta; Myers, Monty M; NSK Expl Env; NSK Fld Drlg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R.Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I; Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge, Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com); waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/9/2013 Summary of Operations 4/8/2013 -Continue making up coring BHA -RIH to 5316 and displace well to 9.8ppg coring fluid -Circulate and condition coring fluid -Core Cassin sand from 5330' to 5498'. 168' of core was cut -Circulate bottoms up and trip out of hole as per coring program Current Operations @06:00 -Laying down core and core barrels 24 Hour Forecast - Finish laying down core and core barrels -Make up 180' coring BHA -RIH and core rest of shale in-between Cassin and Blackburn as well as the Blackburn sand Give me a shout with any questions or concerns Thanks David 1 C6NR5!N '1AL The information vided hereunder by Conoco@#tittips Alaska, Inc., as Operator o, Sear Tooth Unit(ConocoPhillips"),is confidential and proprietary to ConocoPhillips"and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Hyden, Brittney B From: Lee, David Ltt y Sent: Monday, April 08, 2013 6:54 AM To: (sblair@miswaco.slb.com);Alldredge, Paul (Halliburton); Alvord, Chip; Bearden, Daniel D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin;Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel,Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston,Jenna K(Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B;Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Holta; Myers, Monty M; NSK Expl Env; NSK Fld Drlg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R.Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I; Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge,Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com);waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/8/2013 Summary of Operations 4/7/2013 -Change out BHA to get gamma closer to the bit to help with finding core point -RIH and drill from 5214 to 5330' -Core point was called at 5330', circulate bottoms up and POOH -L/D drilling BHA and make up coring BHA Current Operations @06:00 -Displacing to coring fluid 24 Hour Forecast -Cut 180' of core through the Cassin sand -Circulate bottoms up and POOH using set running speeds -Lay out core and coring BHA, make up drilling BHA to drill shale in-between Cassin sand and Blackburn sand Give me a shout with any questions or concerns Thanks David CONFIDENTIAL The information r ed hereunder by ConocoPhillips Alaska, Inc., as Operator of tn. r Tooth Unit(ConocoPhillips"),is confidential and proprietary to ConocoPhillip and is not subject to disclosure because it contains-intimation or data that is exempted from Hyden, Brittney B disclosure)pet-6r 20 AAC 25.537(b). N°Y y JZ From: Lee, David L C.,,,^ Sent: Sunday, April 07, 2013 8:18 AM To: (sblair@miswaco.slb.com);Alldredge, Paul (Halliburton); Alvord, Chip; Bearden, Daniel D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin; Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel, Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston, Jenna K (Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B;Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Holta; Myers, Monty M; NSK Expl Env; NSK Fld DrIg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R. Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I; Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge, Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com);waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/7/2013 Summary of Operations 4/6/2013 -Drill from 4090' to 5214' -Circulate 3 bottom up and start to pull out of hole -Pull out of hole with pumps on due to swabbing -Read MWD tools and remove sources Current Operations 006:00 -Running in hole at 525' 24 Hour Forecast - Run in hole to 5214', drill to core point and pull out of hole to pick up coring tools Give me a shout with any questions or concerns Thanks David 1 CONFIDENTIAL The informatior ded hereunder by ConocoPhillips Alaska, as Operator oft. gar Tooth Unit(ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from Hyden, Brittney B disclosure under QAC 25.537(b). From: Lee, David L Nok co-/4(6w44J Sent: Saturday, April 06, 2013 5:30 AM CT To: (sblair@miswaco.slb.com);Alldredge, Paul (Halliburton); Alvord, Chip; Bearden, Daniel D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin;Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel, Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston, Jenna K (Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B;Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Holta; Myers, Monty M; NSK Expl Env; NSK Fld Drlg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R. Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I;Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge, Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com);waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/6/2013 Summary of Operations 4/5/2013 -Drill from 2344' to 2542' -Trouble shoot mud pump 2, pull to casing shoe to do so. 2 Hours of trouble time -RIH to 2542' and drill to 4090' Current Operations @06:00 -Drilling ahead at 4622' MD 24 Hour Forecast - Drill production section to core point, estimated at 5314' Give me a shout with any questions or concerns Thanks David 1 ONHDEN?1AE, The information led hereunder by ConocoPhillips Alaska, Inc., as Operator of th,_ ,ar Tooth Unit jconocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contain ormation or data that is exempted from Hyden, Brittney B disclosureun r 20 AAC 25.537(b). From: Lee, David L ikAt3 Sent: Friday, April 05, 2013 6:49 AM To: (sblair@miswaco.slb.com);Alldredge, Paul (Halliburton); Alvord, Chip; Bearden, Daniel D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin; Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel,Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston, Jenna K (Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B;Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Holta; Myers, Monty M; NSK Expl Env; NSK Fld Drlg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R.Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I; Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge, Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com);waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/5/2013 Summary of Operations 4/4/2013 -Finish BOP test -Pick up 5" DP and stand in derrick -Make up BHA and RIH -Test casing to 3000 psi for 30 minutes -Drill out shoe track and 20' of new hole and perform LOT, 13.5ppg achieved on LOT -Displace well to 9.8ppg Kla shield mud system Current Operations 006:00 -Drilling ahead at 2551' MD 24 Hour Forecast - Drill production section towards core point Give me a shout with any questions or concerns Thanks David 1 ('ONFIDENAL The information I ed hereunder by ConocoPhittip laska, Inc as Operator of th, .:r Tooth Unit(ConocoPhillips"), is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it cocOins information or data that is exempted from Hyden, Brittney B disclosure rider 20 AAC 25.537(b). iv From: Lee, David L Sent: Thursday, April 04, 2013 6:48 AM To: (sblair@miswaco.slb.com);Alldredge, Paul (Halliburton); Alvord, Chip; Bearden, Daniel D; Bostick, Charles D (Baker Oil Tools); Boyle, Mick F; Brassfield, Tom J; Burkhead, David W.; Chris Cochran (Chris.Cochran@HALLIBURTON.com); Clark, Bryn E; Davasher, Mick J; Doug Griffin;Wilson, Doug (Anadarko); Doyon 141 Company Man; Doyon 141 Wellsite Geologist; Engel, Joe P; Goff, Bart (Halliburton Sperry); Guo, Haibin; Herbert, Frederick 0; Houston, Jenna K (Dowell Schlumberger); Hunter, Lindsey L; Hyden, Brittney B;Jenna Houston (Dowell Schlumberger) (jhouston2@slb.com);Jolley, Liz C; Keith, Greg D; Kurnia, Dadang; Matthew Hotta; Myers, Monty M; NSK Expl Env; NSK Fld Drlg Supv; Oglesby, Edward S (Swift Technical (Europe) Limited); Quinn, Q M; Roberts, Bowen E; Senden, R. Tyler; Smith, Kent W; Snyder, Frank C; Soria, Dora I;Taylor, Cary L(Halliburton); Fleming, Tim (External); Urish, Max W; Partridge, Wally (Anadarko); Wayne Campaign (wcampaign@waterspetro.com); waynecampaign@yahoo.com; Wheatall, Michael Subject: Cassin 6 - Doyon 141 Operations Summary 4/4/2013 Summary of Operations 4/3/2013 -Condition mud for cement job -Cement surface casing, pumped 55 bbl mud push, 295 bbl of lead and 72 bbl of tail, 160 bbl of cement returns to surface. -Nipple down diverter and nipple up wellhead and BOP -Begin testing BOP, 250psi/ 3500psi for ten minutes, BLM rep Justin Miller witnessed the test Current Operations @06:00 -Picking up the 5" DP required to reach TD of production interval 24 Hour Forecast - Pick up 5" DP and stand back -Pick up BHA and test casing to 3000psi -Drill out shoe track and preform FIT to 16ppg -Swap over to Kla shield mud system and drill ahead NOTE: Finished the BOP test this morning, so our next BOP test will be due on April 11 at midnight. Give me a shout with any questions or concerns Thanks David 1 CONFIDENTIAL Following described voluntarily submitted CONFIDENTIAL data pertaining to the Cassin 6 (212-196-0) Exploration well stored in Conoco Phillips Alaska, INC Producer Folder: Shifflett(Conoco Phillips) to Silfven (AKDEC)August 7, 2012 RE: North Slope Exploration Oil Discharge Prevention.... Shifflett(Conoco Phillips) to Wood (AKDEC)April 9, 2013 RE: Request for Temporary Amendment of Seasonal .... These documents are not to be released without the permission of Conoco Phillips. 4 Bettis, Patricia K (DOA) From: Soria, Dora I [Dora.I.Soria@conocophillips.com] Sent: Tuesday, April 09, 2013 4:11 PM To: Dewandel, Shannon S (DEC); Bettis, Patricia K(DOA) Cc: Schwartz, Guy L (DOA); Davies, Stephen F (DOA); Shifflett, Jeanie M Subject: RE: Cassin 6 Extension Request Shannon, Please forward to AOGCC what we've shared with you. I will fill in the gaps of data as appropriate. Please call me if you have any questions Regards, -dora From: Dewandel, Shannon S (DEC) [mailto:shannon.dewandel©alaska.gov] Sent: Tuesday, April 09, 2013 11:56 AM To: Bettis, Patricia K (DOA); Soria, Dora I Cc: Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: [EXTERNAL]RE: Cassin 6 Extension Request Good morning everyone, I just wanted to let you all know I have briefly spoken with Steve Davies at AOGCC regarding this issue. I send him the bit of information we had regarding this subject last Friday, and mentioned to him that I would have additional information for him to look at the early part of this week. Just wanted everyone to have all of the information. I did receive a packet of information from CPAI 30 minutes ago from Jeanie Shifflett of CPAI. Is this information included in what was spelled out below? Dora, were you going to share the information I've received already with AOGCC, or is it the same information referred to below? Please excuse my lack of thorough understanding of details regarding down hole information. Please advise if I will need to scan and forward the information packet I received to AOGCC or if they will receive the same information. Thank you, Shannon Shannon DeWandel (907) 269-7541 Dept. Environmental Conservation 555 Cordova Street Anchorage,AK 99501 From: Bettis, Patricia K (DOA) Sent: Tuesday, April 09, 2013 11:49 AM To: Dora.I.Soria@ conocophillips.com Cc: Dewandel, Shannon S (DEC); Schwartz, Guy L (DOA) Subject: Cassin 6 Extension Request Good morning Dora: 1 i 1D' In order to support DEC in its evaluation of CPAI's request to extend seasonal drilling restrictions for the Cassin#6 exploratory well,the AOGCC must be provided by Noon on April 12, 2013-with the following information from the Cassin#1 and Cassin#6 exploratory wells that has been recorded up through Noon on April 11, 2013: Information Format 1. Mud log(2"=100'vertical scale) PDF—electronic image 2. Well logs-Openhole & LWD including, but not limited to: LAS—digital data o GR o Formation resistivity (shallow, medium and deep) o Neutron porosity o Bulk density o DRHO o Sonic 3. Wellsite geologist's descriptions of any conventional or sidewall cores Printed copy or PDF— electronic image 4. Summary of drilling operations for the past week for Cassin 6 Printed copy or PDF— electronic image This information may be hand-delivered to AOGCC's Anchorage office or provided by email, whichever is preferred by CPAI. Since CPAI is voluntarily submitting this information to the AOGCC, any items that CPAI wishes to remain confidential should be clearly marked as such. If you have any questions, please contact Guy Schwartz at (907) 793-1226 or Patricia Bettis at(907) 793-1238. Best Regards, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 2 Bettis, Patricia K (DOA) Subject: FW: SDR extension request-questions and comments From: Davies, Stephen F (DOA) Sent: Tuesday, April 09, 2013 9:15 AM To: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: FW: SDR extension request- questions and comments Guy, Patricia: In order to accurately evaluate Cassin#6 for a possible recommendation regarding extension of seasonal drilling restrictions, I suggest a reply email to CPAI with a cc to Shannon Dewandel of DEC should be framed something like this: Dora: In order to support DEC in its evaluation of CPAI's request to extend seasonal drilling restrictions for the Cassin #6 exploratory well, the AOGCC must be provided–by Noon on April 12, 2013—with the following information from the Cassin #1 and Cassin#6 exploratory wells that has been recorded up through Noon on April 11, 2013 : Information Format 1. Mud log (2"=100' vertical scale) PDF–electronic image 2. Well logs-Openhole & LWD including, but not limited to: LAS–digital data o GR o Formation resistivity(shallow, medium and deep) o Neutron porosity o Bulk density o DRHO o Sonic 3. Wellsite geologist's descriptions of any conventional or sidewall cores Printed copy or PDF– electronic image 4. Summary of drilling operations for the past week for Cassin 6 Printed copy or PDF– electronic image This information may be hand-delivered to AOGCC's Anchorage office or provided by email, whichever is preferred by CPAI. Since CPAI is voluntarily submitting this information to the AOGCC, any items that CPAI wishes to remain confidential should be clearly marked as such. If you have any questions, please contact Guy Schwartz or Patricia Bettis. Best Regards, From: Dewandel, Shannon S (DEC) Sent: Friday, April 05, 2013 2:34 PM To: Davies, Stephen F (DOA) Subject: FW: SDR extension request - questions and comments First of 3 emails 1 Shannon DeWandel (907) 269-7541 Dept. Environmental Conservation 555 Cordova Street Anchorage, AK 99501 From: Soria, Dora I [mailto:Dora.I.Soria@conocophillips.com] Sent: Friday, April 05, 2013 2:27 PM To: Dewandel, Shannon S (DEC) Cc: Wood, Graham M (DEC); Shifflett, Jeanie M Subject: RE: SDR extension request - questions and comments Shannon, Thank you for visiting with me again and providing me some more guidance. As to the questions below, the Cassin team informs me cased hole logging and testing is not how CPAI/industry conducts such operations because the tools do not work well in a cased hole. There are issues with reliability and accuracy of the information gathered under such conditions. Please let me know if someone at AOGCC wants to visit with someone at CPAI regarding this matter. The team is working on the additional information required to process the request. Have a good weekend and I will be in touch on Monday. Regards, -dora 907-265-6297 From: Dewandel, Shannon S (DEC) [mailto:shannon.dewandel@alaska.gov] Sent: Friday, April 05, 2013 11:17 AM To: Soria, Dora I Cc: Wood, Graham M (DEC); Shifflett, Jeanie M Subject: [EXTERNAL]SDR extension request - questions and comments Hi Dora, I have taken a look at your draft letter requesting an extension to the seasonal drilling restriction and have some comments as well as some questions. First a comment; please submit the request as a Temporary Amendment of Seasonal Drilling Restriction for the Cassin#6 well. This decision will not change or amend the COA#7 as it will be for a short lived approval (if we approve). It will only extend operations at the drill site longer at that location, and only for a limited amount of time, and we may impose blowout prevention conditions as well. Questions 1. Has CPAI considered cased-hole logging and pressure testing? 2. What are the reasons cased-hole logging and testing won't work for CPAI? Additional information required to process the request 1. Please list all measures CPAI would propose to provide protection against a blow out if we approve the request (for example, pressures expected/mud weights used, well control specialist on site, etc) in lieu of using the April 24th date. If necessary, please mark "confidential" on information used to support your request,with the probability that AOGCC will need to see these documents also. 2. Provide a clear timeline that shows the absolute minimum amount of time needed to conduct the drilling and completion activities (taking into account the definitions found in 20 AAC 25.990(14, 15, and 23). 2 3. Describe why Cassin#6 is different (for example, include why CPAI feels that formation evaluation is different than flow testing, and why it is not as prone to possible blow outs). Please take into account that once a well is cased and properly cemented, the risk of blowout drops dramatically and the chief risk becomes spillage via fluid handling. Securing the well in such a manner before DEC's deadline dates will allow cased-hole logging and cased-hole testing operations (both lower-risk operations)to be conducted after the deadline and up to closure of tundra travel. I believe I have covered most of my outstanding questions on this issue, however, you may receive additional requests up to the date of our decision on this issue. Please respond to my remarks via email so the conversation remains in one chain. If supporting information is confidential, please reference those documents but send them in a different file. Thank you, Shannon Shannon DeWandel (907) 269-7541 Dept. Environmental Conservation 555 Cordova Street Anchorage,AK 99501 3 Bettis, Patricia K (DOA) From: Dewandel, Shannon S (DEC) Sent: Friday, April 05, 2013 2:34 PM To: Davies, Stephen F (DOA) Subject: FW: Sent of Behalf of Jeanie Shifflett-Comments on Proposed Exploration C-Plan Stipulation 2 of 3 emails Shannon DeWandel (907) 269-7541 Dept. Environmental Conservation 555 Cordova Street Anchorage,AK 99501 From: Silfven, Laurie A (DEC) Sent: Wednesday, April 03, 2013 8:18 AM To: Case, Clynda A (DEC); Dewandel, Shannon S (DEC); Evans, Gary P (DEC); McDermott, Karen I (DEC); Munson, Dianne R (DEC); Silfven, Laurie A (DEC); Wood, Graham M (DEC) Subject: FW: Sent of Behalf of Jeanie Shifflett - Comments on Proposed Exploration C-Plan Stipulation Graham and Shannon—this e-mail from last summer is relevant for your meeting tomorrow. It pertains to the newest exploration plan condition of approval for an end-of-season drilling restriction. The e-mail is save in our EPR Letter Templates folder. Clynda, Gary, Dianne, and Karen—I'll cc you,just to keep you refreshed as an FYI. Laurie From: Davies, Stephen F (DOA) Sent: Thursday, July 19, 2012 9:12 AM To: Swartz, Jeanne M (DEC) Cc: Silfven, Laurie A (DEC); Schwartz, Guy L (DOA); Roby, David S (DOA); Ballantine, Tab A (LAW) Subject: RE: Sent of Behalf of Jeanie Shifflett - Comments on Proposed Exploration C-Plan Stipulation Jeanne, DEC has requested input from the AOGCC concerning ConocoPhillips' (CPAI) proposed revision to DEC's seasonal drilling restriction clause. CPAI's proposed revision is: "To reduce the risk of an oil discharge and to ensure the effectiveness of planned spill response methods prior to periods when the planned response methods are rendered ineffective by environmental limitations, drilling into hydrocarbon bearing formations for the CPA1 onshore exploration wells within 130 miles of infrastructure with ice road access must be completed by April 24th;for exploration wells within 130 miles of infrastructure without ice road access, drilling must be completed by April 21st of each drilling season that the plan approval is in effect." The language proposed allows CPAI to lengthen the operating season to engage in open-hole logging operations, open- hole testing, and then running and cementing casing after DEC's deadline dates. These are higher-risk operations for any new well (exploratory, development or service). Once a well is cased and properly cemented, the risk of blowout drops dramatically and the chief risk becomes spillage via fluid handling. The AOGCC suggests that when writing the 1 • seasonal drilling restriction clause,the DEC consider mitigating blowout risk by requiring isolation of all potential hydrocarbon formations prior to DEC's deadline dates using either: 1. cemented, un-perforated casing, or 2. cemented, slotted or perforated casing combined with downhole plug(s) or tubing with packer(s). Securing the well in such a manner before DEC's deadline dates will allow cased-hole logging and cased-hole testing operations (both lower-risk operations)to be conducted after the deadline and up to closure of tundra travel. Regards, Steve Davies AOGCC From: Swartz, Jeanne M (DEC) Sent: Wednesday, July 18, 2012 11:11 AM To: Davies, Stephen F (DOA) Subject: RE: Sent of Behalf of Jeanie Shifflett - Comments on Proposed Exploration C-Plan Stipulation Steve, Thanks very much for working on this. We greatly appreciate your input-Jeanne From: Davies, Stephen F (DOA) Sent: Wednesday, July 18, 2012 10:49 AM To: Swartz, Jeanne M (DEC) Cc: Silfven, Laurie A (DEC) Subject: RE: Sent of Behalf of Jeanie Shifflett - Comments on Proposed Exploration C-Plan Stipulation Jeanne and Laurie, The senior staff here has worked up a recommended clause for you. It's at legal for review. I'll forward it when our attorney is through with his edits. Thanks, Steve D. From: Swartz, Jeanne M (DEC) Sent: Tuesday, July 10, 2012 3:46 PM To: Davies, Stephen F (DOA) Cc: Silfven, Laurie A (DEC) Subject: FW: Sent of Behalf of Jeanie Shifflett - Comments on Proposed Exploration C-Plan Stipulation Hi Steve, Laurie and I left you a voicemail message that was quite long. The email string below gives you a more complete picture of the reason for our call. Basically, we would like your guidance in the question of what constitutes well operations. Last fall you met with Laurie and some other people from our section when the Escopeta (now Furie) drilling operation was going to be extended past the seasonal limit due to certain well testing procedures they had planned. This is the first exploration plan with seasonal drilling restrictions we have considered since Escopeta. We would like to take a consistent approach with our interpretation of seasonal drilling operations for this and future exploration plans. CPAI wants us to allow formation testing as they have stated in their email at the bottom of the string. Do you agree with their interpretation? Your help would be greatly appreciated—please contact me or Laurie if you have questions or need more information. Thanks—Jeanne 2 Jeanne Swartz Alaska Department of Environmental C ., Environmental Protection Specialist III (907) 269-7604 Work Jeanne.Swartz@alaska.gov From: Swartz, Jeanne M (DEC) Sent: Tuesday, July 10, 2012 12:06 PM To: Schorr, Betty 3 (DEC) Cc: Silfven, Laurie A (DEC) Subject: FW: Sent of Behalf of Jeanie Shifflett - Comments on Proposed Exploration C-Plan Stipulation Betty, CPAI had the comments below on our seasonal drilling condition of approval: 7. Seasonal Drilling Restrictions. To reduce the risk of an oil discharge and to ensure the effectiveness of planned spill response methods prior to periods when the planned response methods are rendered ineffective by environmental limitations, all drilling operations for the CPAI onshore exploration wells within 130 miles of infrastructure with ice road access must be completed by April 24th; for exploration wells within 130 miles of infrastructure without ice road access, all drilling operations must be completed by April 2151 of each drilling season that the plan approval is in effect. Drilling operations, as defined in 20 AAC 25.990(23),includes active drilling, setting and cementing casing, and other activities ancillary to formation testing. As part of this seasonal drilling restriction, formation testing must also be completed by the specified dates. This condition is reasonable and necessary to reduce the risk of an oil discharge by using specific temporary measures during periods when planned spill response methods are rendered ineffective by environmental limitations, in accordance with 18 AAC 75.445(t). The plan accounts for a 21-day response time for drill sites with ice road access and 24 days for drill sites without, which includes both source control and cleanup. The drilling end date is based on the expected tundra closure date ofMay 15. I wanted to make you aware of this before our meeting this afternoon. Thanks-Jeanne From: Charton, Jason T. [mailto:Jason.T.Charton@conocophillips.com] Sent: Tuesday, July 10, 2012 11:11 AM To: Swartz, Jeanne M (DEC) Cc: Shifflett, Jeanie M; Brassfield, Tom J; Alvord, Chip Subject: Sent of Behalf of Jeanie Shifflett- Comments on Proposed Exploration C-Plan Stipulation Jeanie is on jury duty today. She's asked that I forward her comments on the proposed Exploration C-Plan stipulation Dear Jeanne, Thanks for letting us review the wording for the condition of approval below. Although the wording is like a similar condition issued in the 2007 renewal approval letter, this new version has some changes that may unintentionally impact our exploration program. • In 2007, we worked with ADEC to establish a condition of approval for Seasonal Drilling Restrictions that required cessation of drilling operations into hydrocarbon formations by April 21st (without ice road access) or April 24'h 3 • (with ice road access). The intention of the 2007 condition was to mitigate the risk of a blowout and its subsequent response occurring beyond May 15th (expected date of tundra travel closure), and that actual drilling of the well should cease by those dates; additional operations required to gather data and complete the well could continue (i.e. logging for"formation evaluation", running casing, and cementing). There was no reference to the definition of "drilling operations" in 20 AAC 25.990(23). • We'd like to note that the definition of"drilling operations" in 20 AAC 25.990(23)that is provided in the new condition is not the full definition and is slightly misinterpreted. The full definition is: "drilling operations"means the penetration of ground below the setting depth of structural or conductor casing, using a drilling rig capable of performing the permitted well work, and for purposes other than setting structural or conductor casing; "drilling operations"includes the running of casing, cementing, and other downhole work performed ancillary to formation evaluation, and operations necessary to complete and equip the well so that formation fluids can be safely brought to the surface. The definition mentions "other downhole work performed ancillary to formation evaluation". This is intended to refer to downhole logging of the formation to gather geologic and reservoir data (e.g. rock coring and gathering permeability, porosity, temperature, and pressure data), not formation flow testing. Formation flow testing is performed once the well is completed ("complete" is also defined in 20 AAC 25.990); upon completion, the well is cased and cemented and the wellhead is secured with a Christmas tree (holds valves, spools, pressure gauges, chokes, and fittings to direct and control the flow of formation fluids). In some cases, the well may be plugged and abandoned, as a final step. • Specifying a definition for"drilling operations" that includes work to gather downhole data, complete the well and formation testing, reducing the exploration season by a potential additional 21 days, is problematic since the referenced activities would have to occur by the April dates; this was not the intention of the 2007 condition and does not provide additional spill risk mitigation, as the risk (and applicable Response Planning Standard) is associated with the act of drilling. • Formation testing is only conducted once the well is cased and the wellhead secured, such as the definition of "drilling operations" states, "so that formation fluids can be safely brought to the surface" Risk of a blowout is mitigated; instead the spill risk is from transfer hoses or oil storage tanks and the volume would be low relative to a blowout, since the source can be stopped using valves on the secured wellhead. Placing a seasonal drilling restriction on data gathering, well completion, and formation testing adds little value to mitigating spill risk from a blowout and only further constrains the exploration season, which may render potential exploration projects unsuccessful if attempted, or simply unachievable and thus not attempted. It also makes it difficult for us to take into account, weather and mechanical delays, which complicates well planning and restricts timing even further. CPAI has proven experience with exploration on the North Slope. We have manpower, equipment, and infrastructure readily available for spill response. Our exploration projects are driven both by the April dates (as a deadline to cease drilling) and the tundra travel closure date (expected at around May 151. We incorporate those parameters into planning and execution of our exploration projects and have had great success. Further restricting the exploration season potentially would have a negative impact on the program. Please consider the following language for the Seasonal Drilling Restriction: "To reduce the risk of an oil discharge and to ensure the effectiveness of planned spill response methods prior to periods when the planned response methods are rendered ineffective by environmental limitations, drilling into hydrocarbon bearing formations for the CPAI onshore exploration wells within 130 miles of infrastructure with ice road access must be completed by April 24th; for exploration wells within 130 miles of infrastructure without ice road access, drilling must be completed by April 21St of each drilling season that the plan approval is in effect. This condition is reasonable and necessary to reduce the risk of an oil discharge by using specific temporary measures during periods when planned spill response methods are rendered ineffective by environmental limitations, in accordance with 18 AAC 75.445(1). The plan accounts for a 21-day response time for drill sites with ice road access and 24 days for drill sites without, which includes both source control and cleanup. The drilling end date is based on the expected tundra travel closure date of May 15." Thanks, Jeanie Shifflett Emergency Planning Coordinator HSE - Emergency Management ConocoPhillips Alaska, Inc. 4 Office: 907-265-6488 Cell: 907-301-2368 Fax: 907-265-6216 Email: Jeanie.M.Shifflettaconocophillips.com 5 41# Schwartz, Guy L (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Monday, March 25, 2013 3:43 PM To: Louis Niglio (louis.niglio@bsee.gov); Schwartz, Guy L (DOA) Cc: Hyden, Brittney Bo Subject: Cassin #6 Prognosed Tops - 212196 Lou and Guy, here are the new predicted formation depths for Cassin 6. If you have any questions please let us know. Thanks Davit From: Hyden, Brittney B Sent: Monday, March 25, 2013 3:38 PM To: Lee, David L; Brassfield, Tom J Cc: Keith, Greg D; Smith, Kent W; Clark, Bryn E; Urish, Max W Subject: Cassin #6 Prognosed Tops Please distribute, as necessary. Cassin 6 (Prognosed) Formation MD SSTVD 116 -22 Base Permafrost 1,094 -1,000 K-5 Marker 1,704 -1,610 2,342 -2,248 Nanushuk/K3 2,657 -2,563 Torok 3,980 -3,886 Cassin 5,314 -5,220 Wickersham 5,514 -5,420 Blackburn 5,569 -5,475 Sanford 5,699 -5,605 Brown 6,064 -5,970 Total Depth 6,394 -6,300 KB 94 Brittney Blake Hyden ConocoPhillips Alaska, Inc. Geologist, Prospect Maturation Office: (907) 263-4824 brittney.b.hyden@conocophillips.com w w\��I/j�,• THE STATE Alaska Oil and Gas ofA LASKA Conservation Commission __ , � GOVERNOR SEAN PARNELL 333 West Seventh Avenue � +mtmZ- E� Anchorage, Alaska 99501-3572 ALAS' Main: 907.279.1433 Fax: 907.276.7542 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Wildcat Field, Wildcat Pool, Cassin#6 ConocoPhillips Alaska, Inc. Permit No: 212-196 Surface Location: 5091' FSL, 1996' FWL, SEC. 27,T12N, R1 W,UM Bottomhole Location: 5091' FSL, 1996' FWL, SEC. 27, T12N, R1W, 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. 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, /04„,,ve_ Cathy P. oerster Chair DATED this day of February, 2013. STATE OF ALASKA A CA OIL AND GAS CONSERVATION COMA ON PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1 c.Specify if well is proposed for: Drill El• Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑� • Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑., • Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number. ConocoPhillips Bond No. S-9 S Q i RO ?1)Rlx0 57625--r' Cassin#6 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 700 G Street ATO15-1552 MD: 6400' ' ND: 6400'• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Wildcat• Surface: Sec.27,T12N-R1 W,5091'FSL,1996'FWL uj^;ct AA 081833 Top of Productive Horizon: 11a3 8.Land Use Permit' 13.Approximate Spud Date: Sec.27,T12N-R1W,5091'FSL,1996'FWL IM 932568 3/15/2013 ' Total Depth: 9.Acres in Property: 14.Distance to Nearest Propert : Sec.27,T12N-R1W,5091'FSL,1996'FWL 5756 acres of olza5 -- 3 —1-4-miles viii)2.04 4b.Location of Well(State Base Plane Coordinates-NAD 27)' ££ 10.KB Elevation above MSL:118- J/(e' feet 15.Distance to Nearest Well Open Surface' x-239,9G51r' y-5480467,52 Zone- GL Elevation above MSL: 88• feet to Same Pool: None ?-3210s). S989et1.g Pp.il it 9110t1 16.Deviated wells:N/A kickoff depth: feet ‘ 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: degrees I Downhole: 2612 psi• Surface: 1603 psi _ 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole I Casing Weight Grade CouplingLength MD TVD MD TVD (including stage data) _ 24" 16" 63# H40 Welded 108' Surf Surf 108' 108' Pre-Installed 12 1/4" 9 5/8" 40# L80 BTCM 2570' Surf Surf 2570' 2570' 778 sks of IiteCrete and 351 sks of class'G' 8 1/2" 7" 26# L80 BTCM 6400' Surf Surf 6400' 6400' 224 sks of Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural - Surface RECEIVE_ Intermediate ProductionDEC 14 � �� Liner Perforation Depth MD(ft): Perforation Depth ND(ft). AOGCC 20. Attachments: Property Plat Q• BOP Sketch ❑ Drilling Program ❑� Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program M 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. David Lee 263-3741 Contact David 1 Iee@conocophillips corn Email Printed Name /nChip Alvord Title Drilling Manager Signature V alft Phone 265-6120 Date /Zff 4(20I2— .1 Commission Use Only Permit to Drill A APl Number: Permit Approval �nh See cover letter for other Number: J/•/CI 50-103-.0647-00-00 Date: 2•I�j 14 i J requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: ,(- 550 c) ios L of - .s-f Samples req'd: Yes Q No❑ Mud log req'd:Yes Q No❑ �� J e St �J ,1 H2S measures: Yes Q No❑ Directional svy req'd:Yes❑ No Q /� � Spacing exception req'd: Yes ❑ No E Inclination-only svy req'd:Yes[A No❑ ''F �-e e �.e�e r fS I .I 0 C7 C-C / Sz-(.H-4r7 ArpcaUt—n /`W1. FS�yht. 4.C. •.ai44'or1. / IIIJJJ APPROVED BY Approved b . COMMISSIONER THE COMMISSION Date: Z-?�--f 3 /// "`-" A- I t , Submit Form and Form 10-401(Revised 10/2012) This permit is valid f A4{months frpm the date Of approval(20 AAC 25.005(9)) Attachments in Duplicate R1)e ConocoPhillips Post Office Box 100360 Anchorage,Alaska 99510-0360 December 14, 2012 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Cassin #6 Dear Commissioners: ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore exploratory well Cassin#6. This vertical delineation well will be drilled off an ice road/pad originating from 2L Pad using Doyon Rig 141. The objective of this well is to confirm the presence of the Cassin, Blackburn and Sanford sands, penetrate them, 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 12-1/4" surface hole to approx. 2570' MD/TVD, followed by an 8-1/2" production hole section to approx. 6400' MD/ TVD which will penetrate all the potential sands. The evaluation program in the production hole section of Cassin#6 will consist of coring the entire sand section, obtaining RDT fluid samples in the targeted sands, followed by a wireline logging program. The well will then be cased, completed and each of the sands will be perforated to set the well up to perform DFIT analysis. After the DFIT analysis has been completed the well will be suspended in accordance to the regulations. Drr (ov- , The planned spud date for Cassin#6 is March 15, 2013. pti5 1t-.A R----44-c-- sf- Please find attached for the review of the Commission forms 10-401 and the intormat on required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact myself at(907)263-3741. Sincerely, David Lee Senior Drilling Engineer AF 'on for Permit to Drill,Well Cassin#6 • Saved. 14-Dec-12 Permit It— Cassin #6 r9.6 lk Application for Permit to Drill Document MaxWell P1ix. imiz6 Well Vcilue Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(fl 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 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 4 Requirements of 20 AAC 25.005(c)(5) 4 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) 4 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 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 Cassin#6 APD Prepared by:David Lee Page 1 of 7 Q Pc � Printed: 14-Dec-12 a ,G : 4 $ du Al `ion for Permit to Drill,Well Cassin#6 Saved: 14-Dec-12 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 Plan 7 Attachment 3:Drilling Hazards Summary 7 Attachment 4: Cement Summary 7 Attachment 5:Shallow Hazard and Pore Pressure Conclusions 7 Attachment 5:Seismic Analysis 7 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 conmussion 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 Cassin#6. 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 a 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 5091' FSL, 1996' FWL, Sec 27,Twn 12 N,Rg 1 W NAD 27 RKB Elevation 118'AMSL Northings: 5,990,167.52 Eastings: 239,965.6 Pad Elevation 88' AMSL - Location at Top of Productive Interval 5091' FSL, 1996'FWL, Sec 27,Twn 12 N,Rg 1 W #1 (Cassin) NAD 27 Measured Depth, RKB: 5,520' Northings: 5,990,167.52 Eastings: 239,965.6 Total Vertical Depth, RKB: 5,520' Total Vertical Depth, SS: 5,432' Location at Top of Productive Interval 5091' FSL, 1996' FWL, Sec 27,Twn 12 N,Rg 1 W #2(Blackburn) NAD 27 Measured Depth, RKB: 5,765' Northings: 5,990,167.52 Eastings: 239,965.6 Total Vertical Depth, RKB: 5,765' Total Vertical Depth, SS: 5,677' Location at Top of Productive Interval 5091' FSL, 1996'FWL, Sec 27,Twn 12 N,Rg 1 W #3(Sanford) NAD 27 Measured Depth, RKB: 5,910' Northings: 5,990,167.52 Eastings: 239,965.6 Total Vertical Depth, RKB: 5,910' Total Vertical Depth, SS: 5,822' Location at Total Depth 5091' FSL, 1996' FWL, Sec 27,Twn 12 N,Rg 1 W Cassin#6 APD Prepared by:David Lee Page 2 of 7 Printed: 14-Dec-12 `fllr, 1t. 14' I 11 c.. Ary m for Permit to Drill,Well Cassin#6 Saved: 14-Dec-12 NAD 27 Measured Depth, RKB: 6,400'• Northings: 5,990,167.52 Eastings: 239,965.6 Total Vertical Depth, RKB: 6,400' 4 Total Vertical Depth, SS: 6,312' 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) 1fa well is to be intentionally deviated,the application for a Permit to Drill(Form/0-401)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 potion of the proposed well, 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 irells within 200 feet of the proposed wellbore (4)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 follow ing items,except for an item already on file with the conimusion and identified un the application (3)a diagram and description of the blowout prevention equipment(ROPE)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 Hurst 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 ha=ards,including (4)the maximum:downhole pressure that may be encountered criteria used to determine it,and maximum potential surface pressure based on a methane gradient, Expect light overpressure(1454 psi)starting at top of Nanushuk section at 2625' TVD. • Equivalent Mud Weight @ Nanushuk= 1454 psi/(2625'*.052)= 10.65 ppg Equivalent Mud Weight @ Cassin Sand =2609 psi/(5520'*.052)=9.09 ppg Equivalent Mud Weight @ Blackburn Sand =2548 psi/(5765'*.052)=8.5 ppg Equivalent Mud Weight @ Sanford Sand =2612 psi/(5910'*.052)=8.5 ppg The maximum potential surface pressure(MPSP)while drilling Cassin#1 is calculated using the predicted 2,612 psi reservoir pressure,a 0.11 psi/ft gas gradient and Sanford sand top TVD of 5910' ft. MPSP =FPP—(0.11 x TVD) MPSP = 2612—(0.11 x 5910) I = 1962 psi •� bv_ (B)data on potential gas=ones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of Bole problems such as abnormally geo-pressured strata. lost circulation=ones,and=ones that have a propensity for differential sticti ing. Cassin#6 APD Prepared by:David Lee Page 3 of 7 �� r-N I �, i Q Printed: 14-Dec-12 Ap Dn for Permit to Drill,Well Cassin#6 Saved: 14-Dec-12 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. 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; Casin. and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) _ (lb/ft) Grade Conn. (� _ (ft) (ft) Cement Program Pre-installed 16 24 62.5 H-40 Welded 108 Surf 108/108 Cemented to Surface with 9 5/8 12 1/4 40 L-80 BTCM 2570 Surf 2570/2570 780 sks Arctic LiteCRETE Lead 11.09 ppg, 355 sks Tail Slurry'G'15.8 ppg Cement Top planned @ 5020'MD/5020' 7 8 1/2 26 L-80 BTCM 6400 Surf 6400/6400 TVD. Cemented w/ 225 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) pplication(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 nuist 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 drilluig fluid system,as required by 20 AAC 25 033; Drilling will be done using water based mud systems having the following properties: Surface 108'—2570' Mud Type M-I Gel Density(ppg) 10.0 Funnel Viscosity(seconds) 300 Yield Point(cP) 40-80 API Fluid Loss(ml/30min) NC—< 10 Chlorides(mg/l) <1000 pH 8.5—9.5 Cassin#6 APD Prepared by:David Lee Page 4 of 7 a ! S Printed: 14-Dec-12 Al 'on for Permit to Drill,Well Cassin#6 Saved: 14-Dec-12 Production 2570'—6400' Mud Type KLA Shield Density(ppg) 11.0 Low Shear Rate Yield Point(LSYP) 7-9 awl 00 ft^2) API Fluid Loss(m1.30min) <6 pH 9.5-10.0 Drill Solids(% V/V) <7 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 follow mg items,except for an item already on file with the commission and identified in the application (9)for an eiplor atony or sfratigrap/uc test well,a tabulation setting out the depths ofpredicted abnormally geo-pressured strata as required by 20 AAC 25.033(/); 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 Ili the application: (10)for an exploratory or siratigrap/uc 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 A.4C 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 Peril 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 Cassin#6 is listed below. 1. MIRU Doyon 141 on Cassin#6 conductor. /1 Nof: •lnsr gel"' frioir 2. NU and function test diverter system and prepare spud feud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. Cassin#6 APD Prepared by:David Lee Page 5 of 7 ,. Printed: 14-Dec-12 � t _ 4 • Ap )n for Permit to Drill,Well Cassin#6 Saved: 14-Dec-12 4. Spud and drill vertical 12-1/4"hole to the 9 5/8"surface casing point(2570' MD/2570' 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 9 5/8"40#L-80 BTCM 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. N a 4-: N 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE,install 3-1/2"x 6"VBR's, 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 8 '/2"hole to core point(-5520'),Run MWD/LWD logging tools in drill string as required for directional monitoring and formation gathering. POOH and pick up coring BHA. Core from 5520' to 6110' in 4 runs then POOH to pick up directional BHA. RIH and log and survey cored section of the well prior to getting back on bottom. 10. Once back on bottom Drill vertical 8 1/2"hole to 6400'MD/6400' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 11. POOH with DP and stand back. R/U and run wireline logs. 12. Perform wiper trips as hole conditions dictate between logging runs. 1r=0u4 ''' py V/ ' j-tosr 13. POOH and R/D wireline. Close blind RAMS,change 3-1/2"x 6"VBR's to 7"RAMS,test to 250/3500 psi. RU and run 7"26#L-80 BTCM casing to 6400' MD/6400' TVD and cement. 14. Change upper pipe RAMS f/7"to 3-1/2"x 6"VBR's,freeze protect well. 15. 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. 16. LD 5"DP and PU 4"DP with casing scrapping BHA. 17. Shut in BOP's and pressure test casing to 3,000 psi per AOGCC regulations. Record results. S`v ( 18. Perform casing scrapper run and displace casing to filtered brine. cl (�/�4-C 19. POOH with DP and stand back,L/D BHA, R'S \. 20. R/U and perform CBL,L/D CBL tools err �l � Q n A 1' 21. R/U and perform Eline perforating,R/D Eline perforating 411 {�1" 22. R/U Deburring BHA and perform deburring run on DP,rack back DP and L/D deburring BHA 23. R/U lower completion and RIH on DP,drop balls to set packers. 24. Test top packer,release setting tool and POOH and lay out DP. 25. RIH with upper completion and land tubing hanger and pressure test tubing hanger to 5000psi and two way check valve to 3500psi. 26. N/D BOP and rig down and move out rig. 7. After Rig is off location,well DFIT analysis will commence. 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 music be accompanied E r each of the following items,except for an item already on file u'th 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 authorr_ation under 20 AAC 25 080 for an annular disposal operation in the well; Cassin#6 APD Prepared by:David Lee Page 6 of 7 ,}, I r t Printed:14-Dec-12 M ! 1 v 1 . . J..- A :ion for Permit to Drill,Well Cassin#6 Saved: 14-Dec-12 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. 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. 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 Cassin#6 APD Prepared by:David Lee Page 7 of 7 Printed: 14-Dec-12 r'tkI r" le 1 R N CASSIN #6 LOCATED WITHIN PROTRACTED SECTION 27, T. 12 N., R. 1 W. HARRISON BAY UMIAT MERIDIAN, ALASKA 189' FNL 1996' FWL A.7-4"`'�_"`r PROJECT NAD83 Datum NAD27 Datum AREA { d`; N 70°22'17.8' N 70°22'19.1" �° - �� i. f#�>_- W 152007'01.0" W 152°06'49.6" ASPC ZN5 ASPC ZN5 -i -}-' si ; (Y) 5,988,944 (Y) 5,989,228 , 41% i (X) 1,872,072 (X) 732,052 7 , .. ' I"' `ma 1QSUT1 + 1T ■l I VICINITY MAP N 0 4 .a to o SEC. 22, T 12 N., R 1 W. o / N SEC. 27, T 12 N., R 1 W. O o -O- 1-j Q 169' / U Z pi 0. z _CASSIN #6\ H 1996' 1p 00 i� 2p0 33 \ G ?„,...-10 o o re w z z �/ N N C F— F 1,1 — 3 -0 O N N �O w W W � 5pp 0 N 0 N V N N O0• (n N 1 °0 I °00 1°O 1 " \CE x w a Q a �� w I w c.) I 7 in 0 0 200 oI IIIA —• N SCALE IN FEET G11 z z REVISION 2 z_ 3 KUU K P I K 2012-2013 NPR-A EXPLORATION CASSIN#6 rz t=11. i LcmFPROPOSED ICE PAD CONFIGURATION P ALPINE, ALASKA (..) LC a 139E.51s1.Ave..Anchorage,Alaska 99503•(907)273- DATE: 01/09/2013 DRAWN BY: AD SHEET: 2 OF 2 Alpine Office (907)8764739 I— Alpine Survey Office SCALE: 1"=200' CHECKED BY: DB W.O. No: 12-08-05-1 isS kcl& �' 01291 3 I I CASSIN #6 i HARRISON BAY A. LOCATED WITHIN PROTRACTED M► SECTION 27, T. 12 N., R. 1 W. UMIAT MERIDIAN, ALASKA Aria i �. PROJE• 189' FNL 1996' FWL v AR {r��)'r• . NAD83 Datum _ 1•� . ',LP ' j N 70°22'17.8" i�, G' W 152°07'01.0" ��"'/" �el�,�;� , � �Y}�, ASPC ZN4 7 �� i` 'i Y 5,989,890 (X) 1,379,998 iFT: Nuy s,, .,..., „asp VICINITY MAP ° -- SEC. 22, T 12 N., R 1 W. SEC. 27, T 12 N., R 1 W. 2� V.- ,/ '$ r ty y a" � 189' /` o No, S. 1996' id 1° / CA, SIN #6\ o° 2p0d'' 3 3 0 OM\ 15., o 0 o v RSG Z Z \i N N -p I— a N / N N N U 44 N N b°(21 ) °°0 N R°PO — E A 0 200 ■■■■■ SCALE IN FEET P' s' / I at K U U K P I K 2012-2013 PR-A EX LORATION CASSIN PROPOSED ICE PAD CONFIGURATION 1 LC 11/1 ALPINE, ALASKA 139E.51st.Ave•Anchorage,Alaska 99503•(907)2731833000 DATE: 11/8/12 DRAWN BY: AG SHEET: 2 OF 2 Alpine OIi (907)670 4739 Alpine Survey Office SCALE: 1" = 200' CHECKED BY: DB W.O. No: 12-08-05-1 Lii\ lui !v,. ;, tt... . �o�"'��1-„�� Ti Q" r. 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HARRISON DAY UMIAT MERIDIAN, ALASKA 0N-__ 189' FNL 1996' FWL -y, -� PROJECT NAD83 Datum NAD27 Datum AREA ri<• N 70°22'17.8" N 70°22'19.1" _4____ r - - ---t t----- W -W 152°07'01.0" W 152°06'49.6" � �� AS PC ZN5 AS PC ZN5 -1_ %Ii _ __, '�N- (Y) 5,988,944 (Y) 5,989,228 I; 1_ (X) 1,872,072 (X) 732,052 -4 - — ' - 1IQ_ UTA.--_, I I J PREVAILING VICINITY MAP WIND 0-3 ? Ln M in 0 SEC. 22, T 12 N., R 1 W. o SEC. 27, T 12 N., R 1 W. iw \ Q 189' / Y Z A o o 0. F 1996' - :!�,. �� o 200 'fly 0\ RIG \/ o tr �R\G/Pj,i0 Z CASSIN #6 0 NN w 1- vA O N 0NJ N w w 500• > N0 N rx 100000 E in I 0 N ROP _m \GE = 35 X Lu AP,- 0_ Lu U_ I I Ln 0 0 200 0 1■•III N SCALE IN FEET w m a z REVISION 3 z_ 3 KU U KP I K 2012-2013 NPR-A EXPLORATION a CASSIN#6 ce A PROPOSED ICE PAD CONFIGURATION a0-. _ ALPINE, ALASKA w 0 ��/ 139E.51stAve..Alchorage,Alaska99503•(907)273DATE: 01/15/2013 DRAWN BY: AG SHEET: 2 OF 2 f--- Alpine Office l907)670-4739 D Alpine Survey Office SCALE: 1"=200' CHECKED BY: DB W.O. No: 12-08-05-1 a Crb p t ° Wellbore Cleanout and Displacement to Filtered Brine 1. Change the upper pipe rams from 7"to 3-1/2" x 6"VBR and lower pipe ram to 2-7/8" x 5" VBR. 2. Remove and dispose of all the KLA-SHIELD drilling mud from the pits. 3. As the mud pits are emptied use high pressure washers and / or steam cleaners to perform the clean up. 4. Pump fresh water through all pumps, pits, lines, hoses and manifolds that may be exposed to completion fluid. Particular attention should be paid to the choke and kill manifolds, cement unit,gas buster or any other seldom used lines that may be contaminated with mud or mud solids. 5. Clean the shaker area thoroughly, especially the ditch lines from the sand traps to the pit room. Large amounts of water should be pumped through all centrifugal pumps at the shaker area including the centrifuge, and degasser. 6. P/U a BOP jetting tool and lower it in the hole to thoroughly jet the stack with sea water. Pick up above the stack and function all rams closed then open and then run back in to jet the stack again. 7. After initial cleaning of pits and equipment has been completed, pump 100 bbls of water treated with 3 PPB Caustic Soda, 1 drum SAFE-SURF W, and 1 vis. Cup of DF-9065 through all pits, tanks, lines, hoses, centrifugal pumps, manifolds, and any other equipment that will be exposed to completion brine. The Company Man will verify the pits are clean. 8. Fill pits with adequate volume of filtered 9.0 ppgKCl/NaCl (^'600 bbls). 9. Pickup the WBCT 10. RIH with 4" 14#XT-39 DP, breaking circulation every 2,000 ft with filtered fresh water. 11. Perform clean up at perforating and packer setting areas by reciprocating string 3 times. • Packer Setting Depths: (TBD)xxxxftRKB,xxxxftRKB, xxxxftRKB • Perforating Interval Depths: (TBD) xxxxftRKB to xxxxftRKB xxxxftRKB to xxxxftRKB xxxxftRKB to xxxxftRKB 12. Wash down the last couple stands when getting close to the expected top of cement landing collar to avoid plugging the mill with any fill or green cement. Tag top of cement landing collar. Mill any cement stringers as necessary. 13. Perform a short trip to the 9-5/8" casing shoe (-3500 ft) and trip back to bottom. 14. Pump down the DP 20 Bbl FLO-VIS pill (2 ppb)followed by 10 Bbls of SAFE-SOLV OM at 1.0 BPM. 15. Displace the SAFE-SOLV OMto the bit with ^'69Bbls of fresh water at± 1 BPM and shut down. 16. Close the annular preventer and reverse circulate the SAFE-SOLV OM out of the well with the rig pumps to a dedicated dirty tank/pit with^300Bbls("'2X annulus volume) of filtered fresh water at-7.5 BPM. 17. Pump down the DP with the rig pumps and displace the well with the following pill train: • 40 bbl. High-Vis Spacer with 3 PPB Flowzan mixed in fresh water • 100 bbl. Caustic Wash with 3 PPB Caustic Soda mixed in fresh water • 100 bbl. Cleaning Spacer with 3%by vol. SAFE-SURF W mixed in fresh water • 40 bbl. High-Vis Spacer with 3 PPB Flowzan mixed in fresh water • 100 bbl. Flocculating Spacer with 1 drum of FILTER-FLOC mixed in fresh water 18. Follow the space train with filtered 9.0ppg 6%KCI/NaCl. Pump the pill train at maximum rate 400-500 GPM while monitoring pressures. Rotatethe DP 80-100 RPM. Start reciprocating at 60'/min, after the caustic enters the annulus. Divert the spacer pill train and 220 Bbls of brine to a dedicated dirty returns tank/pit for later disposal after being neutralized. 19. Close in the pipe rams and pressure test the casing to 4,000 psi for 30 min. 20. Record and plot casing test pressure vs.volume on the LOT form. 21. Open the pipe rams, POOH and stand back the 4" drill pipe. 22. Rabbit the DP with a 2.313"teflon drift while TOH 23. L/D the WBCT BHA.Weigh and record all debris recovered,take photos of the BHA assemblies and post them on the S:Drive. Run Cement Evaluation Log 1. R/D the bell nipple and flow line on top of the annular preventer and replace them with a 5K 4 1/16" R-39 shooting flange. 2. P/U 7" Riser with Otis Connection and make it up to the shooting flange. 3. R/U the Halliburton E-line unit and PCE 4. Strip the E-line through the PCE and test the line for continuity. 5. M/U the CAST logging tool and lower the assembly into the well. 6. Stab back the Otis Connection on Riser. 7. Using the rig pumps, pressure test the PCE against casing to 2,000 psi for 10 minutes before RIH. 8. RIH with the logging tool to the landing collar. 9. Pressure up casing to 1500 psi and perform log up to 1,000' above the calculated top of cement at the required speed to obtain quality data. (Maximum running speed 45'/min.) 10. Pull out of hole and lay down CAST tool. 11. E-mail a PDF version of the field prints to the Drilling&Completion Engineers as soon as they are available. 12. Forward hard copies and electronic versions of the processed logs to the Drilling& Completion Engineers in Anchorage as soon as they are available. Perforating Using Casing Gun 1. PU 4.89" ID riser to lubricate the longest perforating gun. PU and MU with Quick Test Sub and Wireline valve. 2. PU and MU perforating gun assembly#1 with GR/CCL tool. 3. Stab the tool inside lubricator. Pressure test lubricator against blind ram to 2500 psi for 10 minutes. 4. RIH the casing gun past the proposed perforating depth. 5. Correlate the gun using the previous correlation logs. Log up and tie-in the GR/CCL to RA markers. 6. RIH back and pick up to position the gun to the first perforation depth. Have Company Man verify the gun is on depth. PROPOSED PERFORATION INTERVAL CASSIN#1 First Interval (-15 ft):X,XXX—X,XXX ftMDRKB (TBD) Second Interval (^'15 ft):X,XXX—X,XXX ftMDRKB (TBD) Third Interval ("'15 ft):X,XXX—X,XXX ftMDRKB(TBD) 7. Ensure the wellbore is full. Prepare trip tank to monitor for losses/gain all time. 8. Detonate and fire the gun.Observe cable movement to verify gun detonation. 9. POOH with perforating gun.Top fill wellbore through trip tank with kill weight filtered brine while POOH with perforating guns by pumping through the BOP kill line. Record and report the loss rate. 10. Confirm 0 psi pressure and unscrew the HES quick connection sub(QTS). LD spent guns. Note the shots fired when guns at surface. 11. Repeat perforating next intervals. 12. Continue to fill the wellbore with filtered kill weight brine through trip tank. Record the loss rate and reported in daily report. 13. RD E-Line unit. 14. Email all the PDF copy of correlation logs to Completion Engineer as soon as they are available. Run Perforating De-Burring 1. Pickup De-Burring assemblies 2. TIH with the De-Burring BHA on 4" DP to+/- 50' above the top perforation interval. 3. Monitor losses while RIH. Once on bottom and before entering the perforations, record pick-up and slack-off weights and rotary torques prior to washing operations. Record the fluid loss rate prior to De-burring the perforations. 4. Establish a circulation rate of 2 BPM and record the stable pump pressure. NOTE: Have 100 bbls of HEC lost circulation pill prepared at MI Swaco Mud Plant in Alpine and loaded on a certified clean truck. NOTE:The HEC lost circulation pill will be prepared by the following procedure: • 100 bbls. filtered 9.0 PPG 6% by weight KCI/ NaCI Brine • %2 vis. cup DF-9065 • Lower pH to^'4 using Citric Acid • Slowly add 3.5 PPB HEC-10 • Allow to circulate through high shear hopper for 10—15 minutes, or as long as necessary until no fish eyes can be observed • Increase pH to 8.5 with Caustic Soda and shear for an additional 30 minutes. • Filter HEC lost circulation pill through 10 micronnominal followed by 10 micron absolute mesh filter cartridge to remove any fish eyes while transferring to certified clean vac-truck for transport to rig. 5. Rotate 60-80 rpm to the right while reciprocating perforated intervals. Ream each stand approximately 6—8 minutes slip to slip while monitoring drag. If excessive drag is seen while de-burring the perforations,slow down the reaming speed. Adjust flow rate as needed to accommodate for losses. 6. TIH while rotating and reciprocating at+/-60'/min until the top of the lower of MAGNOSTART assembly is 50' below the lower most perforation. 7. POOH to 50' above the top perforation and circulate at 5-6 BPM and monitor returns. If good returns are established, circulate 2 BU with filtered brine while diverting returns to a dedicated tank for later disposal. 8. Rabbit the DP with a 2"teflon drift while TOH. 9. L/D BHA and stand back the DP 10. Weight and record all debris recovered from the BHA and magnet,take photos of the BHA assemblies and post them on the S:Drive. Run Lower Completion 1. Strap and record the dimensions(ID, OD, and Length)of each piece of equipment prior to RIH. 2. Rabbit all 3-1/2" tubing with 2.867" teflon drift. 3. Pick up lower completion as specified in the Lower Completion Running 4. After the first packer is picked up, do not exceed 90 seconds per stand to prevent surging. 5. Record P/U and S/O weight of lower completion after making up the liner setting sleeve. 6. TIH with the lower completion on 4" DP to position the upper most Premier packer(depth TBD). 7. R/U the Halliburton E-line unit and PCE 8. Strip the E-line through the PCE and test the line for continuity. 9. M/U the Gamma Ray logging tool and pull the string into the lubricator. 10. M/U the PCE to the TIW. 11. Close the TIW and pressure test the PCE to 2,500 psi for 10 minutes. 12. Bleed of the test pressure and open the TIW. 13. RIH, and locate the RA tag in the DP. Log while pulling out of hole and correlate the perforation depths using the Gamma Ray signature,the RA tags in the 7" casing and the Tie-in-Log for reference. 14. Correlate the correct depth for the production packer. 15. POOH and R/D the E-line equipment. 16. Adjust the lower completion assembly depth as per the correlation requirements. 17. When the CPAI representative and Baker Hughes Supervisor are in agreement that the packers are on depth, set the slips. 18. R/U circulating sub and pressure test all lines to the rig floor to 5,000 psi. 19. With the lower completion assembly in place and the DP full, break circulation 2-3 BPM to ensure there is no restriction. Note: Do not exceed 1000 psi.The packer start to set at^ 1500 psi. 20. Break the line at the TIW valve and drop a 1" steel setting-ball. Allow sufficient time for the ball to gravitate to seat. 21. When ball reaches the seat, perform a low-pressure tubing test of 500 psi. If pressure cannot be maintained, reverse circulation low rate may be required to clear ball seat of debris. If pressure still cannot be maintained, consult with the BHI Supervisor and the Completion Engineer for the appropriate action. 22. With the ball on seat, pressure up on the tubing slowly to 2,700 psi. Hold pressure at 2,700 psi for 5 minutes and then pressure up to 4,000 psi in 500 psi increments holding the pressure for 5 minutes at each increment. 23. Bleed the tubing pressure to zero and perform a 20,000 lbs pull test on the production packer to ensure the packer slips have engaged the casing. 24. Pressure test the IA to 1,500 psi and hold for 5 minutes to test the top packer. 25. Bleed the IA pressure to zero. 26. Slack off 20,000 lbs and pressure up the tubing to 2,700 psi to hydraulically release the setting tool. 27. P/U to insure the setting tool has released from the setting sleeve. NOTE: If the setting tool does not release hydraulically, slack off and initiate the mechanical release by rotating 1/4 turns to the left at the tool. 28. After confirming the setting tool has released,flow test the well for 30 minutes prior to TOH with the DP and setting tool and L/D same. Run Upper Completion 1. Hold a safety meeting with the rig crews and all contractors to ensure that the driller and workers in the pipe shed understand the order of installation and how to communicate clearly if there are problems. 2. Change Top Pipe Rams for running tubing completion.Test pipe rams to 250 psi Lo and 4000 psi Hi. 3. Pull wear bushing. Make up wash tool.Jet wash to clean around the tubing hanger area to ensure no debris. 4. MU 3-1/2"Tubing Hanger(FMC)to the TH Running tool and Landing Join. LD same. Note: Drift all the 3-1/2"Tubing with 2.867"Teflon drift. Discuss the importance of drifting all tubing and history or effects of not drifting. 5. Run the completion 6. Make up Schlumberger Solid Gauge Mandrel as per Schlumberger procedure. NOTE: Make up single way plug to TEC-wire as to SLB procedure. Connect to Espionage® gauge and pressure test connection (5 min @ 5000 PSI). 7. Lower upper completion string until an indication is seen on surface that indicates that the seals are entering the seal bore,then pick-up 10 ft. 8. Make up string into Top Drive and prepare to displace the well to filtered 9.0ppg KCI/NaClweight brine. 9. Circulate well to inhibited and un-inhibited packer fluid as follows: • Pump"145bbls of inhibited kill weight brine (w/2%CRW-13).This will place inhibited brine in the annulus. . • Pump"45bbls of uninhibited kill weight brine. 10. Monitor the well for 30 minutes to confirm the well is static. 11. After displacement is complete sting into Seal Bore Extension (SBE) as follows: • Slowly sting into Seal Bore Extension with pumps circulating down the drill pipe at"'1 BPM, looking for pressure increase as seals enter SBE. Record surface pressure.Shut down pumps and open bleeder. Do not exceed 10 bbls of pump down to keep the area between packer and second mandrel filled with the inhibited brine. • Slack off to completely insert seal assembly to fully located position. • Mark pipe for calculating space out. 12. Space out with tubing pups to leave locator 5 feet above fully located position. Make up the tubing hanger assembly to the last joint of tubing and orient the completion so the hanger matches up with the centering guide in the tubing bowl. Make up feed through downhole gauge TEC wire as per Schlumberger procedure. Pressure test swagelok fitting on tubing hanger TEC-wire ports to 5000 psi. Chart pressure records. 13. Sting back into SBE (without pumping), land tubing hanger with landing joint A, and Run in Lock Down Screws. Leave landing joint A in place. 14. Pressure test annulus to 1000 psi (do not exceed 2500 psi to avoid shearing DCR-1)to confirm SBE seals are stabbed in. Bleed down annulus. Leave landing joint A in place. 15. Observe well for 30 minutes to confirm that the well is static. 16. Pressure test the tubing to 4000 psi for 15 minutes against the ball & ball seat. Chart test. 0 Bleed tubing pressure to 2,000 psi. Pressure test the 3-1/2" x 7" annulus to 3500 psi for 15 minutes. Chart test. Record pressure tests on MIT forms. Leave landing joint A in place. 17. While keeping pressure on the annulus, bleed down tubing as fast as possible to shear the DCR-1 valve (DCR-1 is set to shear at 2500 psi casing to tubing differential). Bleed tubing and annulus down to 0 psi. 18. Pull and lay down landing joint A. Install 2-way check into tubing hanger. Install landing joint B. 19. Pressure test upper hanger seals(250 psi for 5 minutes, 5000 psi for 10 minutes). Chart tests. 20. Pressure up inner annulus to 2500 psi to test two way check from below(direction of flow) and tubing hanger from below(direction of flow). Chart tests.These pressure tests are required to consider the two-way check and lower hanger seals as mechanical barriers tested in the direction of flow per the COP Well Control Manual. 21. Bleed off pressure on annulus. 22. Pull and lay down landing joint B. 23. Flush stack to clean up if needed. 24. Observe well for 30 minutes to confirm that the well is static. 25. The Company Man will verify the following barriers are present before ND BOP stack: 1) Kill weight fluid in tubing, 2) Kill weight fluid in inner annulus, It- '4 ✓ 3)Two way check in tubing hanger, pressure tested from below, and 4)Tubing hanger pressure tested from below. 26. ND BOPE.NU tree and adapter. 27. Pressure test the flange connection through the test port located on the tubing bonnet flange to 5,000 psi for 10 minutes.This will test the upper hanger seals from below and the lower hanger seals from above. 28. Rig up lubricator and pull two way check valve. 29. Rig up manifold & hard lines to tubing &annulus. 30. Freeze protect well by pumping annulus (70 bbl) of diesel (±2000 ft TVD). Put tubing and annulus into communication across choke manifold and allow diesel to percolate on the annulus. • 3-1/2" tubing capacity=0.0087bb1/ft • 3-1/2" tubing x 7" casing annulus capacity=0.0264bb1/ft • Total volume = 2,000' MD x(0.0087+0.0264) bbl/ft= 70bbls 31. Shut in well & Rig down lines. 32. Rig up Lubricator&set BPV. 33. Secure well. 34. Lay down drill pipe& prepare rig for rig. 35. Turn well over to operations via handover form. NOTE: Handover Form must be filled out, signed by all involved parties(Drilling, Wells, & Production), scanned, & posted. Following through on this critical detail will ensure a reliable resource for the Production Engineer to reference during the planning&execution of post rig work. k PA I Aa a Pi el' 7,1 eii m ConocoPhillips (Alaska) Inc. -Expl 6 '` North Alaska ASP5 i Cassin a I Plan: Cassin #6 Cassin #6 I. i Plan: Cassin #6 (wp01) 4 iii t 1 ,a Standard Proposal Report i il!1 id pE Ed in 28 November, 2012 g 1 111 ` 11, I it _ LI y pial gt tillf lIGf 11 ilP i" e .—....:... . HAtt-L!P T " ! Sperry Drilling Services 6 . ? !"' Irl ; , kai i i 0 HALLIBURTON rroject: North Alaska ASP5 WELL DETAILS: P, ..-.assin#6 North American Datum 1983 Alaska Zone 5• Site: Cassin Ground Level: 88.00• Sperry Drilling Services Well: Plan:Cassin#6 +NI-S +E/-W Northing Fasting Latittude Longitude Slot Wellbore: Cassin#6 0.00 0.00 5989900.00 1380000.00 70°22'17.898 N 156°7 0.953 W Plan: Cassin#6(wp01) REFERENCE INFORMATION Co-ordinate(WE)Reference:Well Plan:Cassin 88,True North 0- Vertical(TVD)Reference:Plan D141 @ 116.008(0141(88+28))- _ Measured Depth Reference:Plan D141 @ 116.008(0141(88+28)) Calculation Method:Minimum Curvature 400- FORMATION TOP DETAILS - TVDPathTVDssPath MDPath Formation 1116.00 1000.00 1116.00 Base Perm 1738.00 1622.00 1738.00 K-5 Marker 800- 2653.00 2537.00 2653.00 Nanushuk/K3 4028.00 3912.00 4028.00 Torok 5548.00 5432.00 5548.00 Cassin Sand 1000 5793.00 5677.00 5793.00 Blackburn Sand 5938.00 5822.00 5938.00 Sandford Sand 1200- Base Perm • 6428.00 6312.00 6428.00 TD 1600- K-5 Marker 2000- 2000 2400- - 9 5/8"x13 1/2" --- Start 3032.00 hold at 2516.00 MD 2800-- Nanushuk/K3 CASING DETAILS c 3000 MD TVD TVDSS Name Size Hole Size 2570.00 2570.00 2454.009 5/8"x13 1/2" 9-5/8 13-1/2 O - 6428.00 6428.00 6312.00 7"x8 1/2" 7 8-1/2 03200- 0_ L - a al - Q3600- To - Q) di4000- _...---- _-- _-- _- __ 4000 f-• - Torok 4400- _ 4800- 5000 5200- Start 880.00 hold at 5548.00 MD 5600-- - _ 600- _ Cassin Sand Cassin#6(wp01) - _Blackburn Sand 6000- 6000 Sandford Sand 6400- '•'28 TO 7"x8 1/2" TD at 6428.00' 6800- Cassin#6(wp01) I I I I r t I I l I l I r f I I l I I I I I I I I I 7 I I t I I t l I I I I I I I t l I I l I I l I I t t t I I I -1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 Vertical Section at 0.00° (800 ft/in) ConocoPhillips H s - Q_8 Q _ = - = _ V I in N O a3 m,--.N - O GO q 4 1i .,..,GG C sF Zam aRmt, 7r IL .,-, h d VI �pCcm G CS' 5 .a y O Z t°� F — u r..ce o 5000 a Z,. M. -n .. 2 m aQE a -)1 - - f••• 0 c00C 4 N - z Sas fvvi� ° _0 0 moo '� W u dO (m OO _ Q r CO U big �� - Q F Z c h 0 Clio W y yg FN,40 - - �3j Wp W KKKa 00 O M W O O F O R 8 q n N - m U N b - t E Q:1 988 O OZP >i > N,o —0 N G Vl O _ O O b N _ L o —O O O O - �-. h N - O - ru .0 O LO « 1 _CL (n ^ O NN - a Q '. m Z I - O x C 3 to N ti V m as 4*cn CO CD*k —O .+.. Q CU C C �I - L.N 'y'rn 1 I 1 _ C cn O OJ l0 (0 CONi � - ZUa00 - -, - U s, ;� _0 3 'per>.Da g - a 0 N a —oo - o _ o ro 76=I"...-,- 0. .-ta(10 =am.-,O0 0 O0 Zn LL'OmONN — m,- 0c caZO - Hr Cr om(7 o Z Q n C o m - U .. til, d N L .- 01.-0-0 E m E0 o —v ¢� m a ° I- - r Dm - 6 p CHt I I I I I I I I I I I I I I I I I I 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 I I I I I I 1 I 1 1 1 1 I 1 I 1 1 I 1 1 I I I 1 1 1 1 I 1 1 1 1 0 Oo 8 0 0 O 0 O O o 0 O 0 J T MO N N .N.. 0 h v1 O - N N en 0 a a (u!/8 00I)(+)l1uoN/(-)gnoS I 6 Halliburton -Sperry HALLI B Li RTO J PJ Standard Proposal Report Database: Alaska EDM Prod v16 Local Co-ordinate Reference: Well Plan:Cassin#6 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan D141 @ 116.00ft(D141(88+28)) Project: North Alaska ASP5 MD Reference: Plan D141 @ 116.00ft(D141(88+28)) Site: Cassin North Reference: True Well: Plan:Cassin#6 Survey Calculation Method: Minimum Curvature Wellbore: Cassin#6 Design: Cassin#6(wp01) Project North Alaska ASP5,Alaska Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 5- Using geodetic scale factor Site Cassin Site Position: Northing: 5,986,110.00ft Latitude: 70°21'38.602 N From: Map Easting: 1,374,096.85ft Longitude: 156°9'49.609 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: -2.04 ° Well Plan:Cassin#6 Well Position +NI-S 0.00 ft Northing: 5,989,900.00 ft Latitude: 70°22'17.898 N +EI-W 0.00 ft Easting: 1,380,000.00 ft Longitude: 156°7'0.953 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: • 88.00 ft Wellbore Cassin#6 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I (°) (nT) BGGM2011 9/10/2012 17.50 80.37 57,478 Design Cassin#6(wp01) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N1-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 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) (0) (0) (ft) ft (ft) (ft) (°I100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 -88.00 0.00 0.00 0.00 0.00 0.00 0.00 2,516.00 0.00 0.00 2,516.00 2,400.00 0.00 0.00 0.00 0.00 0.00 0.00 5,548.00 0.00 0.00 5,548.00 5,432.00 0.00 0.00 0.00 0.00 0.00 0.00 6,428.00 0.00 0.00 6,428.00 6,312.00 0.00 0.00 0.00 0.00 0.00 0.00 11/28/2012 4:31:39PM Page 2 COMPASS 2003.16 Build 69 1 1 H H 4 I ta F ( Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: Alaska EDM Prod v16 Local Co-ordinate Reference: Well Plan:Cassin#6 � ° �� Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan D141 @ 116.00ft(D141(88+28)) Project: North Alaska ASP5 MD Reference: Plan D141 @ 116.00ft(D141(88+28)) If Site: Cassin North Reference: True Well: Plan:Cassin#6 Survey Calculation Method: Minimum Curvature Wellbore: Cassin#6 Design: Cassin#6(wp01) 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) (ft) (ft) -88.00 28.00 0.00 0.00 28.00 -88.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 1,116.00 0.00 0.00 1,116.00 1,000.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 Base Penn 1,738.00 0.00 0.00 1,738.00 1,622.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 K-5 Marker 2,516.00 0.00 0.00 2,516.00 2,400.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 2,570.00 0.00 0.00 2,570.00 2,454.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 9 5/8'x13 1/2" 2,653.00 0.00 0.00 2,653.00 2,537.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 Nanushuk/K3 4,028.00 0.00 0.00 4,028.00 3,912.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 Torok 5,548.00 0.00 0.00 5,548.00 5,432.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 Cassin Sand-Cassin#6(wp01) 5,793.00 0.00 0.00 5,793.00 5,677.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 Blackburn Sand 5,938.00 0.00 0.00 5,938.00 5,822.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 Sandford Sand 6,428.00 0.00 0.00 6,428.00 6,312.00 0.00 0.00 5,989,900.00 1,380,000.00 0.00 0.00 TD-7'x81/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Cassin#6(wp01) 0.00 0.00 5,548.00 0.00 0.00 5,989,900.00 1,380,000.00 -plan hits target center -Circle(radius 300.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,570.00 2,570.00 95/8'x131/2" 9-5/8 13-1/2 6,428.00 6,428.00 7"x8 1/2" 7 8-1/2 11/28/2012 4:31:39PM Page 3 COMPASS 2003.16 Build 69 ORI G1t'-! tL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: Alaska EDM Prod v16 Local Co-ordinate Reference: Well Plan:Cassin#6 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan D141 @ 116.00ft(D141(88+28)) Project: North Alaska ASPS MD Reference: Plan D141 @ 116.00ft(D141(88+28)) Site: Cassin North Reference: True Well: Plan:Cassin#6 Survey Calculation Method: Minimum Curvature Wellbore: Cassin#6 Design: Cassin#6(wp01) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (1 (°) 5,548.00 5,548.00 Cassin Sand 0.00 1,738.00 1,738.00 K-5 Marker 0.00 5,938.00 5,938.00 Sandford Sand 0.00 6,428.00 6,428.00 TD 0.00 5,793.00 5,793.00 Blackburn Sand 0.00 4,028.00 4,028.00 Torok 0.00 1,116.00 1,116.00 Base Perm 0.00 2,653.00 2,653.00 Nanushuk/K3 0.00 11/28/2012 4:31:39PM Page 4 COMPASS 2003.16 Build 69 Cassin #6 Drilling Hazards Summary 12 1/4" Hole/9 5/8" 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 Low Shallow hazard study has noted that there are no significant shallow hazards. Follow best practices and increase mud weight if 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 8 1/2" Hole/7" 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. Abnormal pressure in Torok and Moderate Use PWD to monitor hole. Follow mud weight schedule zone of interest as needed. Per shallow hazard study and offset well data, anticipate slight abnormal pressure. Practice stripping drills,shut-in drills and increase mud weight as needed. Ensure adequate kick tolerance. Lost Circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. Differential sticking with core Low Follow mud weight schedule. Keep drill string moving barrel Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. i Attachment 3-Drilling Hazards Summary Rev1.doc Prepared by David Lee 0kPagt E e 1 of 1 ic,iftt Cassin 6 Schlumberger CemCADE Preliminary Job Design 9 5/8" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client:COP Revision Date: November 2,2012 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 250%excess in the permafrost and 50% excess below the Location:Anchorage,AK Phone:(907)263-4207 permafrost. The top of the tail slurry is designed to be at-1770' MD. Mobile:(907)223-8916 email:jhouston2©slb.com Lead Slurry Minimum pump time: -212 min. (pump time plus 120 min.) Arctic LiteCRETE +Adds- 1.90ft3/sk 0.7632 ft3/ft x(108')x 1 (0% excess)=I 83 ft3 0.3132 ft3/ft x(1088'-108')x 3.5(250% excess)= 1075 ft3 0.3132 ft3/ft x(1770'-1088')x 1.5(50%excess)= 321 ft3 83 ft3+ 1075 ft3+321 ft3= 1479 ft3 1479 ft3/1.90 ft3/sk= 778 sks(780) Previous Csg. Tail Slurry Minimum pump time: -170 min. (pump time plus 120 min.) < 16",65#casing 15.8 ppg Class G +adds- 1.17ft3/sk at 108'MD 0.3132 ft3/ft x(2570'-1770')x 1.5(50% excess)= 376 ft3 0.4256 ft3/ft x 80' (Shoe Joint)= 34 ft3 376 ft3+ 34 ft3= 410 ft3 410 ft3/ 1.17 ft3/sk= 351 sks(360) BHST= 74°F, Estimated BHCT=77°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 6.0 50.0 8.3 8,3 ALC Surface Lead 6.0 263.1 43.8 52.1 Surface Tail 5.0 73.0 14.6 66.7 < Top of Tail Cement at Pause 0.0 0.0 3.0 69.7 -1770 MD Fresh Water 5.0 5.0 1.0 70.7 Pause 0.0 0.0 5.0 75.7 Mud 8.0 173.8 21.7 97.4 Mud 3.0 10.0 3.3 100.7 < 9 5/8",40#casing in 12-1/4"OH MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv< 14, Ty<25. TD at 2570'MD (2570'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv=22-28, Ty=30-38 Centralizers: As per COP program *Mark of Schlumberger ORtGINAL Cassin 6 Schlumberger CemCADE Preliminary Job Design 7" Intermediate Casing (V1) Preliminary Job Design based an limited input data.For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client:COP Revision Date: November 2,2012 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 40%excess. The top of the tail slurry is designed to be at-5020' Location:Anchorage,AK Phone:(907)263-4207 MD. Mobile:(907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -185 min. (pump time plus 120 min.) 15.8 ppg Class G +adds- 1.17ft3/sk [ 0.12681 ft3/ft x(6400'-5020')x 1.4(40% excess)= 245 ft3 0.2148 ft3/ft x 80' (Shoe Joint)= 17 ft3 245 ft3+ 17 ft3= 262 ft3 262 ft3/1.17 ft3/sk= 224 sks (230) Previous Csg. BHST= 156°F, Estimated BHCT= 100°F. < 9 5/8",40#casing (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) at 2570'MD PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 6.0 40.0 6.7 8.7 Intermediate Tail Slurry 5.0 46.7 9.3 16.0 Pause 0.0 0.0 3.0 19.0 Fresh Water 5.0 5.0 1.0 20.0 Pause 0.0 0.0 5.0 25.0 Mud 6.0 226.8 37.8 62.8 Mud 3.0 10.0 3.3 66.1 MUD REMOVAL < Top of Cement at Expected Mud Properties: 11.0 ppg, Pv< 14, T„<25. -5020'MD Spacer Properties: 12.0 ppg MudPUSH* II, Pv=22-28, TY=30-38 Centralizers: As per COP program • < 7",26#casing in 8-1/2"OH TD at 6400'MD (6400'TVD) * Mark of Schlumberger nir i .i f #1 S t Cassin #6 Shallow Hazard and Pore Pressure Conclusions December 12, 2012 Executive Summary ConocoPhillips Alaska Inc. (COP) intends to drill exploration well Cassin #6 in March 2013 should its predecessor, Cassin#1, be deemed as successful. As part of the well planning process, COP contracted with Fusion Petroleum Technologies Inc. (Fusion) of Houston, Texas to perform geopressure prediction on 42 mit of 3D seismic data from the NPRA Merge 3D seismic survey and evaluate the down-hole pore pressure regime at the Cassin#6 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. Several zones of possible low saturation gas and a deeper, higher pressure zone have been identified and should be drilled with care. Cassin Proposed Drilling Locations Proposed Cassin Well Locations(5;16.12) as of May 16,2012 Location AY.SP 4 FEET X Y Lat. Len. 13743'-..: ..2 2C:.CC 70.36869612_3 -150.15224 5 =-.:^' 7:.3:'6,5:4:1, .152182654:62 136? .._ .4..e67-CC sw _ 1377352.22 5624C2:.CC 72.33573233175 -152.115n6555 F.- -1 1555 22 SIM':CC 70.374552073 -152.034333:,55 1353 .%752-i4 CC 2 332103560 2 0532 5535 ms's �_.�� _ 13359 9ALGl20 CC 70.371535265 .152.11"3313 5 7 137.2.544 `.4532'CC 70 355;.72071 .152 26.4 35 i 13523:3.2. !WV:CC 72.31531P23i -152.1276 2445 Eaoaenst ? 3751.0 3 ear_C:.Cc 73.4,1572255: 145:414::* 10 555 ss4715•:.CC 70.321±3.1532 .52.053126653 1.202114 Hazard Survey Arse s i 42 sq miles 4' E t ; Bap tirI 16"!1 1 Alaska Bear Tooth Unit `1236"* wputcriYt 1 Wells-Surface Hot*Location + laza4ant i :u45e 2:131\'11: t laverasF p�FliMtlt►t :4562 o¢ccsea:ba_ran:n:•.'a..- i .fE• 7asar ::3Aay.Ves"•'a'•'E t 1 I I_exp Va•:C II i 1 - I I:c1:1±re k/'i±--:6643 nFla1c.•la6U a K W Fe xiOoseseatet r.. LOLY.f1Jl: FTJC417r -arew ie PH'C31Cr M/FltOlei 11'`1*y Miff asIts,153 4'23358€7 Tenth Unit fa5e`I rano CCcm "L,,�� J. •". Cl1 r lr ITY 15._CCC.] '-�,) \-✓ 1, ?LI 7 .,Ca €alp C 5493[ Latlhtle y 1 a ttetu= r y UOE "C ix U �,��-`� ,lrp�lpp'•Np 1_r, r rte• RI N7C1 M.errar 13V5.' �+ CVCJ3;fi_tip1��rfGir7 i; -"• _ IJ,es 152=15W 152`/ 151`45Y. Figure 1: Location map of Cassin area and area of interest for hazard study. Note Cassin #6 is NE of first well Cassin #1. 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 data at every CDP location were generated, and used to calibrate for pressure using the control well location. Pressures were then predicted in 3D across the entire prospective area using the GEOPRESSTNI 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 Cassin #6 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. The control well for this project was the West Fish Creek#1 well (WFC) drilled by Husky in 1977. Figure 2 shows the area of interest Att05_Cassin#6 Shallow Hazard.doc y Prepared by Kent Smith, Brittney Hyden&David L. Lee with the WFC and proposed wells and line of section for seismic panels reported by Fusion. Fusion generated fluid and fracture pressure models for Cassin locations 1, 3, and 8 as well as for#6. • ^. I---'',.,,,.„,‘,,. COSMO POLO / / Cassie_PM. ,U / -,,,, /CtoSSM *L.7 / - ''7C''-''4--. V1 Cassn 6&L / �. /6* !/ _ .. 4,. / canna /ff f! /f / ej / J / / assin,_PDL 5 f L5 1 . / i CaSi// ,- *A / 7 ''''--,,,, / r, M 1 MN h a•Rm'a...aer. . /41? ''''P / AV "• cm r'' / / I j i m Figure 2: Seismic base map showing outline of 3D study area, West Fish Creek Well and proposed drilling locations. Conclusions The fluid and fracture pressure models derived from the control well was applied to the interval velocity volume and used to generate fluid and fracture pressure models for the Cassin #6 proposed location. Also, 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 Cassin #6 well. Att05_Cassin#6 Shallow Hazard.doc Prepared by Kent Smith, Brittney Hyden&David L. Lee OR ! GINA Pressure Gradient Data(ppg} °.:20 10.23 12.00 14.00 "t;00 1E00 20.00 pFPC: O✓BG Top Nanushuk -2537 SS J . • m rr ; ''- Top Cassin -5432 SS 1 TD - MW 8000 Figure 3: Predicted down-hole pressures in Cassin #6. Green line is suggested mud weight; red, pore pressure; orange, fracture gradient; black, overburden gradient. The shallow hazards analysis of the study area reveals that in the Cassin #6 location the predicted pore pressures are essentially hydrostatic except for one zone where the pressures may slightly elevated between 3,200 to 5,500 feet SSTVD. In this zone, the predicted pressure rises to approximately 10.5 ppg. The mud program will take into account the possible impact of this pressure prognosis. Contractor Fusion does remark that this anomaly could be caused by artifacts in the seismic data so care should be taken while drilling in this zone. The final well prognosis for the Cassin #6 is shown on the ThinMANTM pseudo-impedance sections for arbitrary line A-A' (Figure 4). Figure 4 displays the depths to each of the mapped shallow zones noted with depths relative to sea level as determined from the REVELTM time- depth conversion. Inspection of Figure 4 shows the base of permafrost will be encountered at about 580 feet SSTVD (based on seismic velocities) and the base of possible hydrates at approximately 1,011 feet below sea level. Zone 1 through 4 gas hazards will be encountered from just below the base of hydrate to a maximum depth of 1770 feet. These zones are most likely coarser, silty sediments containing low saturation gas. Att05_Cassin#6 Shallow Hazard.doc Prepared by Kent Smith, Brittney Hyden&David L. Lee • c:«P.ae c,ra�+<�cu (x..a.LE Cx..P)0 fxMaL. O mast tr " 19 91 Sa masa mzeu N 186.36.0 1Ci�0 1{gT1p 1N31.0 W�:.0 1 ',.'119'411,‘ 5S0 t .1sL1 QJ Mpg a . 5.ani "1 , 1288ft(M L) r1. t 9 !r a.. 1, Figure 4: ThinMANTM impedance section for arbitrary line A-A'through the Cassin #6 well showing hazard horizons mapped in feet below sea level. Summary Fusion has identified several zones in the shallow section of the Cassin #6 well which should be monitored for gas influx while drilling. These four zones are at 1,288-feet, 1,559-feet 1,627-feet and 1,770-feet SSTVD. Fusion states that Cassin #6 has the highest risk of the four studied locations and therefore Cassin #6 should be carefully monitored while drilling. It should be noted that these zones are most likely coarser, silty zones containing at most low saturation gas. Pore pressure and fracture gradient along the well bore was also calculated and the results suggest a benign pressure gradient near hydrostatic with an increase to pressures requiring 10.5 ppg from approximately -4,000 to- 5,400' SSTVD. Again, care should be taken to monitor the well to account for this possible increase in pressure. In summary, the Fusion evaluation shows the Cassin #6 location contains no significant drilling hazards which would prompt moving the location: however, Fusion states that the shallow hazards are most significant at the #6 location so this well should be carefully monitored for increases in pressure and gas influx. Att05_Cassin#6 Shallow Hazard.doc Prepared by Kent Smith, Brittney Hyden&David L. Lee R„ f' i w I- 0 0 U d J U b a r_ N r O a b ! L N b a O N L N OO LT0 a O N. D O 8o o a s i O'n w 0 O o O O co 000Eo rn -oo > dE P. co.c _ d CE N co 2 C• -O .H y N N a' cE c J 8 �� 49 .c0o? a Ey aU dE d N O V E D U C-o t o O OC O N 2 co 'yCUa -' o_r� x cFU nn L ° m rl M0 my E ?IT co a i V ae C 0 ..- • Kii4:44 04 V"!I•4 4;4' ON • . X ; X o XX XX t + 0) •s ` '8 v 'C t to y y % N n N • N N c = a U o 2 a o a a 0C 8^c N o o •=Q x n . a U co a cn FS a O o o a -2,P O— v ,. a o H 2 0_ m b a o . 0 o a o O N m y _m • . . • Oto AO �Op 4 v . o . . J cii'' x W to Lc, c . o o (V 4 . , . • C063 in co O 0 o r I',;.' in O L C LL N {o C co co Y Nco O 0 o d ' coC Y 0 cco co to m 0 co 0 m Z U m co 1- 0 P, I I I\,1 t L:.r Page 1 of 1 Schwartz, Guy L (DOA) From: Lee, David L [David.L.Lee@conocophillips.comj Sent: Wednesday, February 20, 2013 4:43 PM To: Schwartz, Guy L (DOA) Cc: Brassfield, Tom J Subject: RE: Cassin#6 (PTD 212-196) Attachments: FMC Schematic- 16X9.875X7X3.5.plf.pdf; 12-08-05-1_Ice Pad Exhibits_002 Rev3.pdf; Cassin 6 Completion Procedures.docx Guy, please find the FMC wellhead schematic, completion procedures and pad layout with diverter line attached. Cement Yields are as follows: Surface Lead cement(ALC litcrete)—1.90 ft3/sk Surface tail cement (G)—1.16ft3/sk Production cement (G)—1.16ft3/sk If you need anything else just let me know. Thanks David Lee From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, February 20, 2013 2:39 PM To: Lee, David L Subject: [EXTERNAL]Cassin #6 (PTD 212-196) David, Please provide wellhead diagram and as built location map with diverter line shown. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/21/2013 Bettis, Patricia K (DOA) From: Lee, David L [David.L.Lee@conocophillips.com] Sent: Wednesday, January 09, 2013 2:19 PM To: Bettis, Patricia K(DOA) Subject: Coordinates for Cassin 1 and Cassin 6 Attachments: 12-08-05-1_Ice Pad Exhibits_002 Rev2.pdf; 12-08-05-1_Ice Pad Exhibits_001 Rev2.pdf Hey Patricia, please find the attached updated ice pad maps for Cassin 1 and Cassin 6 to reference the correct zone. Thanks for catching this and please let me know if you need anything else. Thanks David Lee 1 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. TRANSMITTAL LETTER CHECKLIST WELL NAME LOSS)n PTD# a a i c/ Development Service /Exploratory Stratigraphic Test Non-Conventional Well FIELD: POOL: 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(f), 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. Rev:9/09/2011 • E w N aa) a a 2 Cn vi o. D 2 b a) o u t com m a c hi a) Q a o O a) vc' co a) O E N. 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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. FINAL WELL REPORT MUDLOGGING DATA Cassin #6 Provided by: Approved by: Brittney Hyden Compiled by: Joshua Dubowski Kent Smith Harry Bleys Distribution: 8/20/2013 T.D. Date: 4/13/2013 Cassin #6 1 1 MUDLOGGING EQUIPMENT & CREW................................................................................................2 1.1 Equipment Summary......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS.....................................................................................................................................3 2.1 Well Summary................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Additional Comments......................................................................................................................3 2.4 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................6 3.1 Lithostratigraphy .............................................................................................................................6 3.2 Mudlog Summary............................................................................................................................7 3.2.1 Colville Group..........................................................................................................................7 3.2.2 Nanushuk ................................................................................................................................8 3.2.3 Torok .......................................................................................................................................9 3.3 Connection Gases ........................................................................................................................14 3.4 Trip (Wiper) Gases.......................................................................................................................14 3.5 Sampling Program / Sample Dispatch..........................................................................................15 4 PORE PRESSURE EVALUATION ......................................................................................................16 4.1 Quantitative Methods....................................................................................................................17 5 DRILLING DATA..................................................................................................................................18 5.1 Survey Data ..................................................................................................................................18 5.2 Bit Record.....................................................................................................................................20 5.3 Mud Record ..................................................................................................................................21 6 DAILY REPORTS ................................................................................................................................23 7 SHOW REPORTS ...............................................................................................................................24 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ LWD Combo Log (MD/TVD) 2”/100’ Gas Ratio Log (MD) 2”/100’ Drilling Dynamics Log (MD/TVD) Final Well Data on CD/ROM Cassin #6 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 Effective Circulating Density (ECD) From Sperry-Sun 2731’ to TD 0 Hook Load / Weight on bit Totco WITS Feed 0 Mud Flow In Derived from Strokes/Minute and Pump Output 0 Mud Flow Out Totco WITS Feed 0 Mudlogging unit computer system HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 Mudlogging unit DAC box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss Totco WITS Feed 0 Pump Pressure Totco WITS Feed 0 Pump stroke counters Totco WITS Feed 0 Totco Well Monitoring Components Totco computer networked in Mudlogging Unit 0 Rate of penetration Totco WITS Feed 0 RPM Totco WITS Feed 0 Torque Totco WITS Feed 0 1.2 Crew Unit Type : Steel Arctic Unit Number : ML056 Mudloggers Years *1 Days *2 Sample Catcher Years Days Joshua Dubowski 5 23 Joe Coon 1 16 Harry Bleys 13 23 John Vargo 6 16 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well Cassin #6 3 2 WELL DETAILS 2.1 Well Summary Well: Cassin 6 API Index #: 50-103-20666-00-00 Field: NPR-A Surface Coordinates: 5091 FSL AND 1996 FWL, SEC 27, T12N, R1W, UM Borough: North Slope Primary Target Depth: 5,315’ MD/ 5,221’ SSTVD State: Alaska TD Depth: 6,203’ MD/ 6,009’ SSTVD Rig Name / Type: Doyon 141, Arctic Triple Suspension Date: N/A Primary Target: Cassin, Blackburn and Sanford Sands License: Spud Date: March 31, 2013 Ground Elevation: 66’ AMSL Completion Date: N/A RT Elevation: 94’ AMSL Completion Status: Secondary Target: Depth: N/A Classification: Exploration TD Date: April 13, 2013 TD Formation: Lower Torok Days Testing: N/A Days Drilling: 13 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Coring Casing/ Liner MD (ft) TVD (ft) LOT (ppg) 12.25” 2,324’ -2,230’ Collville 10.0 0.95 - 9.625” 2314’ 2314’ 13.5 8.5” 6,203’ -6,109’ Lower Torok 9.8 0.91 yes N/A 2.3 Additional Comments Cassin #6 is the second of two wells drilled by ConocoPhillips in the Bear Tooth Unit during the 2013 drilling season. Cassin #6 is located ~1.33 miles northeast of Cassin #1 and 3.4 northwest of West Fish Creek 1. It is expected to penetrate the Cassin, Blackburn and Sanford sands. Cassin #6 is expected to intersect all three sands in weakly confined and laterally extensive lobe systems. The Cassin sand will be penetrated in the proximal portion of the lobe system, whereas the Blackburn and Sanford sands will be penetrated in a more distal setting. The main objectives of the well will be to: Determine reservoir presence, quality and quantity in the Brookian section down-dip position to Cassin #1; Determine hydrocarbon phase and identify possible fluid contacts; Obtain pressure and fluid samples for oil characterization; Obtain conventional core from the target sands. Cassin #6 4 2.4 Daily Activity Summary March 30, 2013 Continue working on rig acceptant checklist. Load spud mud into pits and N/U diverter system. Load pipe shed with MWD tools and 96 joints of 5” drill pipe. Test diverter (good). P/U drill pipe and HWDP and rack back. P/U BHA at report time. March 31, 2013 Fill hole and test lines to 3500 psi (good). Circulate and Condition mud. Drill to 309’ and CBU. POOH and L/D BHA. P/U BHA #2 and RIH. Drilling ahead at report time. April 1, 2013 Drill ahead to TD at 2324’ MD. CBU and waiting on geologist. April 2, 2013 POOH to 2235’ and monitor well (static). POOH to 664’ and circulate hole clean. RIH to 2235’, circulate and condition mud. Monitor well (static). POOH and L/D BHA. R/U casing equipment and run casing to 2313’. Condition mud and circulate, R/D casing equipment and R/U cementing equipment. Circulate and condition mud. April 3, 2013 Circulate and finish R/U cementing equipment. Pump cement and R/D cementing equipment. N/D diverter and M/U conduit to find TOC, tagged up at 7’ and wait on cement. M/U torque speed head and casing spool, L/D conduit, P/U mouse hole, strap 5” pipe. Decision made to N/U BOP. N/U BOP and testing equipment. Testing BOP at report time. April 4, 2013 Finish testing BOP’s and R/D test equipment. P/U 17 stands of 5” DP and M/U 8.5” BHA. Single into hole with 45 joints of 5” DP. Test casing and RIH to TOC @ 2204’. Drill out cement and casing shoe and 20’ of new hole. Circulate and condition mud. Perform FIT to 13.5 EMW. Displace well to 9.8 ppg Kla-Shield mud. April 5, 2013 Drilled ahead to 2542’ and CBU. Pull to shoe and troubleshoot mud pump #2. RIH and drill ahead to 4129’ at report time. April 6, 2013 Drilled to 5214’ and monitor well (static). POOH to 4950’, improper hole fill, trip back to bottom. CBU and pump out 10 stands. attempt to pull out on elevators, hole still swabbing, continue to pump out of hole to 2267’. Attempt to POOH on elevators but still getting improper hole fill. Monitor well. L/D BHA at report time. April 7, 2013 Finish L/D BHA and P/U new BHA. RIH to 2236 and slip and cut drill line. RIH to 5108. Wash and ream to 5160 and MAD pass. Drill ahead to 5330’ and CBU. Pump out of hole 10 stands then POOH on elevators to surface. L/D BHA and P/U coring BHA April 8, 2013 P/U coring BHA and RIH to 5195’ and displace well to coring fluid. Drop ball and RIH to 5330. Core to 5498’ and monitor well (static). Pump out first 3 stands then begin POOH following coring procedure. Cassin #6 5 April 9, 2013 Finish POOH with core barrel as per procedure. R/U and gamma ray core barrels. L/D core barrels and remove core. M/U core barrels. RIH and begin coring. Core to 5683’ and circulate. April 10, 2013 Finish circulating and POOH with core barrel as per coring procedure. L/D and gamma ray core. P/U coring barrels and RIH and begin coring run #3. Coring at report time. April 11, 2013 Core to 5826’. Observe wt. not drilling off and pump pressure increase. Decision made to POOH and break off core. CBU and POOH as per procedure. L/D and gamma ray core. Rig up testing equipment and test BOP’s. April 12, 2013 Core to 5826’. Observe wt. not drilling off and pump pressure increase. Decision made to POOH and break off core. CBU and POOH as per procedure. L/D and gamma ray core. Rig up testing equipment and test BOP’s. April 13, 2013 Finish POOH and L/D BHA. P/U new BHA and RIH with drilling assembly. Displace to KlaShield mud. Drill to TD at 6203’ and CBU 3x. POOH on elevators at report time. April 14, 2013 RIH to bottom and CBU. MAD pass from 6203’ to 5340’. Monitor well (static) and POOH to surface. L/D BHA and R/U to run wireline. April 15, 2013 Troubleshoot and C/O wireline tools. RIH with wireline. April 16, 2013 Finish wireline run #1 and R/D wireline. M/U cleanout BHA and RIH to 2228’ and slip and cut drill line. RIH to bottom and CBU 3x. Monitor well (static). POOH and L/D BHA. R/U wireline tools and RIH with RSWC. L/D tool and P/U sonic/XRMI tools and RIH. April 17, 2013 Finish sonic/XRMI wireline run and L/D tools. P/U and run MRIL/GEM/SGR tools. Finish running MRIL/GEM/SGR and L/D tools and all wireline equipment. M/U cleanout BHA and RIH. CBU 3x and monitor well (static). POOH to 2292’ and monitor well (static). POOH and rack back BHA. R/U wireline and run RT scanner. April 18, 2013 Finish running RT scanner and L/D tool. M/U VSP tool and RIH. Finish and L/D tool and wireline equipment. R/U and test BOP. R/D BOP testing equipment and P/U BHA. Running in hole at report time. April 19, 2013 Finish RIH to 6203’ and CBU. Monitor we// (static), and begin POOH. Monitor well at shoe (static). Change out top rams to 7”, R/U BOP testing equipment and test BOP’s. R/U casing equipment and begin running 7” casing. Cassin #6 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy COP tops refer to provisional picks by the town geologist . PROGNOSED COP TOPS FORMATION MD (ft) TVDSS (ft) MD (ft) TVDSS (ft) 16” Casing -- -- 107 -14 Base Permafrost 1094 -1000 -- -- K5 Marker 1704 -1515 1721 -1628 9 5/8” Casing -- -- 2314 -2221 Nanushuk/K3 2652 -2,563 2652 -2557 Torok 3978 -3,886 3978 -3884 Cassin Sand 5,314 -5,220 5315 -5221 Top of Core -- -- 5330 -5236 RTD Sample -- -- 5379 -5285 Cassin Base -- -- 5476 -5382 Wickersham Sand 5,514 -5,420 5506 -5412 Wickersham Base -- -- 5549 -5455 Blackburn Sand 5,569 -5,475 5572 -5478 Blackburn Base -- -- 5689 -5595 Sanford Sand 5,699 -5,605 5704 -5610 Base of Core -- -- 5827 -5733 Sanford Base -- -- 5930 -5836 TD 6,394 -6,300 6203 -6109 Cassin #6 7 3.2 Mudlog Summary 3.2.1 Colville Group 108’ to 2652’ MD / 108’ to 2651’ TVD / (-14’ to -2558’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 574 1.0 107.0 63 0 10.4 Cassin # 6 began drilling at 108 ft. in the Colville Group. The Colville was composed mainly of Claystone with small amounts of sand and siltstones. Claystone in this interval was medium gray to dark gray color; malleable with a clumpy lumpy consistency. A slight gritty texture due to loose entrained sands, black carbonaceous lithic fragments, and possible foram fossils. It had irregular fracture; blocky to wedge like cuttings; waxy shiny luster; and no apparent structure. It did come in great quantities. The claystone exhibited a very strong adhesive property and a very strong cohesive property. Siltstone was medium gray to medium dark gray color with soft clasts of a weak induration. The clasts had a crumbly to pulverulent tenacity with an splintery to irregular fracture. They had blocky rounded flaky cuttings habit; and a dull earthy luster. A spotty sample mineral fluorescence of <5% of the clasts were found with no cut fluorescence or petroleum odor. Sands in this section transitioned from trace amounts to larger intervals from 900 ft to the top of the Nanushuk formation. Sands are loose unconsolidated very fine to lower fine on the standard grain chart. It is dominantly quartz of an sub-angular to rounded angularity with fair sphericity and holding glauconite, lithic fragments and calcite as accessory minerals. Dark oil droplets were seen at 2670 ft. with dull yellow gold sample fluorescence and an instant cut fluorescence of milky white green. The top of the Permafrost was never suitably found. No gas appeared at all to give evidence of any hydrate methane gas. The K5 marker was at 1721’ MD/ -1628’ SSTVD), and the top of the Nanushuk/K3 marker at 2652’ MD/(-2558’ SSTVD). Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 913 63.441 18674.430 42.815 0 0 45.695 0 0 2652 45.207 8722.062 63.087 Cassin #6 8 3.2.2 Nanushuk 2652’ to 3978’ MD / 2651’ to 3977’ TVD / (-2558’ to -3884’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 268.7 3.5 131.8 65 1 14.3 The top of the Nanushuk began at 2652’ M.D. and continued to the top of the Torok at 3978’ MD The Nanushuk is composed of interbedded layers of claystone, siltstone, sand and sandstone. Claystone was medium gray to dark gray throughout with soft lumpy clumpy consistency that slowly firmed up to slightly crumbly tenacity; irregular fracture with rounded blocky cuttings; smooth texture with no obvious structure. Siltstone was a medium gray to dark medium gray color. The siltstone clasts were soft to slightly crumbly, with a splintery to irregular fracture, and a blocky to flaky cuttings habit, and an earthy dull luster. There were trace amounts of black carbonaceous lithic fragments, and trace shales. A fluorescence of <5% of clasts were found, and on other samples trace calcite mineral fluorescence. The sands were moderate to well sorted, and sub-angular to sub-rounded, with a moderate to high sphericity. The sands were dominantly translucent quartz. It had moderate to well aged textural maturity with very fine lower to fine upper grain size by the standard grain chart. Dark oil droplets were in evidence at 2670 ft. with a dull yellow gold sample fluorescence and a instantaneous white milky green cut fluorescence. Sandstone was present in a grain supported to matrix supported argillaceous to slightly calcareous matrix cement. Silty-sandstones were interbedded through out the Nanushuk as weakly indurated to firmer clasts. Sandstone had a salt and pepper appearance; which was dominantly composed of quartz grain in an upper very fine to lower medium grain size of sub angular to sub rounded angularity. They had a fair to moderate sphericity with a tight to low visual porosity as evidence in the silty sandstones. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 2653 47 9084.970 66.037 2702 55 10791.441 44.806 2903 35 7036.711 46.942 3955 65 11817.327 1357.069 606.572 87.572 125.695 Cassin #6 9 3.2.3 Torok 3978’ to 6203’ MD / 3977’ to 6202’ TVD (-3884’ to -6109’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 450 0.2 100.7 284 1 26.5 The Torok formation contains with in it the Cassin Sand, the Blackburn Sand, and the Sanford Sand. The Torok Formation stretches from 3978 ft. to 6203 ft. The upper section above the Cassin Sand has a composition of claystone, siltstone sand and sandstone. Claystones in this section are typically medium grayish brown to dark grayish brown to a very darker gray color. They have a soft to crumbly to pulverulent, mushy to lumpy consistency, irregular to earthy fracture and a dull to earthy to slightly waxy luster with a clayey to silty texture. Structure is not seen in the softer claystones. The siltstones in this section are typically dark medium brownish gray to dark medium gray with brown hues. They’re usually poorly indurated, display crumbly to brittle to mushy; to pulverulent consistency, irregular to blocky to planar fracture, dull to sparkly luster with silty to clayey texture. Some of the clasts include carbonaceous lamina and it’s occasionally deformed. The interval also includes a minor amount of lower very fine to extremely fine quartz sand, commonly sub rounded to rounded, good sphericity, and well sorted. Sandstone is present in minor amounts with a grain supported and matrix supported matrix cement composed mainly of argillaceous cement. There was only a trace amount of pale yellow to yellow-green fluorescence with no cut or odor. The following gas peaks will be contained in each Cassin Sand, Blackburn Sand and Sanford Sand section. Cassin #6 10 3.2.3.1 Cassin Sand and Shale 5315’ to 5506’ MD / 5314’ to 5505’ TVD / (-5221’ to -5412’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 86 2.2 30 284 6 31 The Cassin sand was made up of sand and sandstone with its’ lower section composed of siltstone and claystone. Overall gas was low; with one peak through this interval. The Cassin sand is made up of a well sorted sub rounded to rounded unconsolidated dark gray quartz. It is well sorted and has a moderate to high sphericity. It is sub- angular to rounded. The Cassin sandstone is grain supported to matrix supported. It has moderate visual porosity, sub angular to rounded grains, very fine lower to lower fine grain size. Sample fluorescence is 10% to 60%, green to yellow gold. No cut fluorescence and a slight petroleum odor. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5322 124.791 20433.893 2062.292 305.433 469.729 84.069 68.384 31.356 5332 284.110 53148.592 5532.048 1877.835 192.054 256.219 15.432 8.386 3.2.3.2 Wickersham Sand and Shale 5506’ to 5572’ MD / 5505’ to 5571’ TVD / (-5412’ to -5478’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 62 8 32 37 15 27 The Wickersham is a sandstone with a dark gray, salt and pepper appearance. Overall Cassin #6 11 it was very fine to fine, unconsolidated sands and grain supported. Sample fluorescence was pale greenish yellow on 80% of the sample with a more intense gold- yellow fluorescence on 10% of the sample. There was no cut or petroleum odor. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5552 37.6 4813.214 693.243 302.462 38.819 73.962 5.017 3.2.3.3 Blackburn Sand and Shale 5572’ to 5704’ MD / 5571’ to 5703’ TVD / (-5478’ to -5610’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 48 0.9 21.1 58 11 27.9 The Blackburn sand was made up of sand and sandstone with the lower section to the Sanford sand being made up of a claystone, siltstone and minor amounts of sand. The sandstones are composed of grain supported lower very fine to lower fine grains. The grains are sized from standard grain size charts, and well sorted. The sandstone clasts were consolidated but moderately indurated. The matrix cement is argillaceous and slightly calcareous in trace amounts. Grains are sub-angular to sub-rounded with moderate sphericity. Degassing is visible in sample clasts, with an overall moderate visual porosity, and poor visual permeability. The sandstone had deformed carbonaceous banding seen as a salt and pepper appearance. A weak yellow gold sample fluorescence was in evidence on 10% of the sample. A moderately bright spotty fluorescence in 5 % of the sample accompanied with a weak petroleum odor. Cassin #6 12 Sands were very fine to fine grain size and well sorted with moderate to high sphericity. The sands were loose unconsolidated primarily quartz of an opaque grayish white to translucent clear fill. Sands were a minor component with sandstone being dominant. Claystone was medium gray to dark gray with a soft to lumpy clumpy consistency. It grew firmer with a malleable crunchy tenacity, and irregular fracture. The claystone had a rounded blocky to wedge like cuttings. It had a smooth texture and irregular thick structure. Claystone displayed a dull to slightly shiny waxy luster. It had moderately strong cohesive and adhesive properties. Siltstone was medium gray to a dark gray in color. It had a firm crumbly to tough tenacity. The siltstone clasts fractured in an irregular to splintery manner. The cuttings were rectangular to wedge like. Siltstone had a gritty texture and dull luster. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5574 25 3600.090 521.087 240.942 24.205 59.539 1.792 5596 39 5449.892 785.982 359.147 50.812 90.176 5.096 5617 40 6012.357 845.962 493.219 74.102 145.714 21.350 4.005 5702 58 7976.268 1323.996 840.415 109.698 163.149 25.987 18.862 3.2.3.4 Sanford Sand 5704’ to 5930’ MD / 5703’ to 5929’ TVD / (-5610’ to -5836’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 110 0.2 39 186 21 69 The Sanford sand is composed of sand and sandstone with a minor amount of siltstone and claystone. The Sanford sand is medium gray with slight brown hues. Sand and sandstone compose the Sanford. It’s sands are unconsolidated and well sorted but sandstone is in dominant quantities. The sandstone has a deformed dark banding with the appearance of salt and pepper. The sandstone grains are loosely held in a weakly indurated argillaceous cement. The sandstone is dominantly quartz of a lower to upper Cassin #6 13 fine grain with sizes seen of lower medium. The quartz grains are moderate to poorly sorted, with sub-angular to sub-rounded angularity. The matrix cement is argillaceous but calcareous in part. The quartz found in the sand and sandstone is opaque grayish white to translucent clear filled. The sandstone’s salt and pepper appearance is due to abundant black carbonaceous material cemented in the sandstone and seen as loose material in the sands. Cut fluorescence was found on 5710 ft and 5720 samples. A pale white blue residual cut was also found along with a moderate petroleum odor. Moderately to strong white gold to greenish gold fluorescence continues sporadically through most of the Sanford Sand. At 5890 ft. the strong greenish yellow gold sample fluorescence continues, with an added instantaneous streaming of a milky white yellow color. The sample fluorescence is 60%. Claystones are medium gray to dark gray in color. They have a soft to malleable to firmer crumbly tenacity. The cuttings are blocky to rounded slumped cuttings of various consistencies to firmer tenacity or hardness. Siltstone is medium gray to dark gray in color. It has irregular fracture and blocky to flaky cuttings. It’s texture is very rough and gritty. The overall structure is thick. Both siltstone and claystone increase in the lower sequence as the Sanford sands diminish. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5702 58 7976.268 1323.996 840.415 109.698 293 25.987 18.862 5707 169 25869.427 4160.976 2580.150 326.266 467.340 79.676 60.043 5713 186 23364.906 3503.139 2085.286 261.730 377.544 68.919 53.742 5785 136 20160.220 3087.028 1954.520 259.682 391.254 82.690 58.683 5854 145 18725.070 2633.723 1571.942 234.449 324.858 76.659 36.498 5872 102 13410.035 1577.244 901.546 137.071 200.078 38.349 18.782 Cassin #6 14 3.3 Connection Gases Depth (MD/TVD) Gas (units above background) Depth (MD/TVD) Gas (units above background) 3654 8 4580 13 3747 14 4672 20 3840 8 4857 18 3930 16 4950 22 4023 24 5043 22 4116 23 5138 36 Connection Gases 4209 17 4857 18 3.4 Trip (Wiper) Gases 1 unit = 0.05% Methane Equivalent Depth (feet) Trip to (feet) Gas (units) Downtime (hours) 5214 Surface 50 17 5330 Surface 58 14 5498 Surface 84 24 5825 Surface 91 20 6203 Shoe 16 5 6203 Surface 41 18 Cassin #6 15 3.5 Sampling Program / Sample Dispatch Set Type/Purpose Frequency Interval Dispatched To A Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD Jon Kaplan Alaska Archives 1300 West 56 th Avenue, Unit 14 Anchorage, AK 99518 B Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD Jon Kaplan Alaska Archives 1300 West 56 th Avenue, Unit 14 Anchorage, AK 99518 C Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD Wayne Svejnoha, Chief Branch of Energy and Minerals BLM-Alaska State Office 222 W. 7 th Avenue #13 Anchorage, AK 99513 D Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD AOGCC Attn: Howard Okland 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 E Washed, screened and dried for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD Grogans Mill Records Center Attn: Kenny Bland 9190 Grogans Mill Road The Woodlands, TX 77380 F Wet, unwashed bagged for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD Halliburton Energy Services 6900 Arctic Boulevard Anchorage, AK 99518 Attn: Robert Haverfield G Wet, unwashed bagged for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD Halliburton Energy Services 6900 Arctic Boulevard Anchorage, AK 99518 Attn: Robert Haverfield H Wet, unwashed bagged for geologic analysis. 30 ft 10 ft 0’ to 5214’ MD 5214’’ to 6203’ MD Halliburton Energy Services 6900 Arctic Boulevard Anchorage, AK 99518 Attn: Robert Haverfield I Isotubes 500 ft 30 ft 10 ft 0’ to 2388’ MD 2388’ to 5214’ MD 5214’ to 6203’ MD Isotech Laboratories, Inc. CPAI samples, contact: Albert Holba 1308 Parkland Court Champaign, IL 61821 Ca s s i n # 6 16 4 P O R E P R E S S U R E E V A L U A T I O N In t e r v a l T o p s P o r e P r e s s u r e ( M W ) Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) MD (f t ) SS T V D (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators Ba s e P e r m a f r o s t C l a y s t o n e 8 0 % S a n d 2 0 % - - 9 . 9 1 0 . 1 e v e n M W , B G K5 M a r k e r C l a y s t o n e 9 0 % S a n d 1 0 % 1 7 2 1 - 1 6 2 8 9 . 9 1 0 . 1 e v e n M W , B G Na n u s h u k / K 3 S a n d s t o n 3 0 % S a n d 3 0 % 2 6 5 2 - 2 5 5 8 9 . 8 9 . 9 e v e n M W , B G To r o k S i l t s t o n e 5 0 % Cl a y s t o n e 40 % 39 7 8 - 3 8 8 4 9 . 8 9 . 9 S l i g h t i n c C G Ca s s i n S a n d Sa n d s t o n e 70 % Sa n d 1 0 % 5 3 1 5 - 5 2 2 1 9 . 8 9 . 9 S l i g h t i n c C G , B G , T G W i c k e r s h a m S a n d Sa n d s t o n e 50 % Si l t s t o n e 2 0 % 5 5 0 6 - 5 4 1 2 9 . 8 9 . 9 S l i g h t i n c B G , T G Bl a c k b u r n S a n d Sa n d s t o n e 60 % Cl a y s t o n e 20 % 55 7 2 - 5 4 7 8 9 . 8 9 . 9 M o d i n c B G , T G Sa n f o r d S a n d Sa n d s t o n e 70 % Cl a y s t o n e 20 % 57 0 4 - 5 6 1 0 9 . 8 9 . 9 M o d i n c B G , T G TD S i l t s t o n e 5 0 % S h a l e 2 0 % 6 2 0 3 - 6 1 0 9 9 . 8 9 . 9 d e c r e as e B G , T G NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i lt s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f , C S l t s t = C a r b o n a c e o u s S i l t s t o n e MW = m u d w e i g h t , B G = b a c k g r o u n d g a s , C G = c o n n e c t i on g a s , T G = t r i p g a s , W G = w i p e r g a s Ca s s i n # 6 17 4. 1 Q u a n t i t a t i v e M e t h o d s Th e p r i m a r y i n d i c a t o r s u s e d f o r P P G e v a l u a t i o n w e r e g a s t r e n d s r e l a t i v e t o m u d w e i g h t ( M W ) a n d e f f e c t i v e c i r c u lating de n s i t y ( E C D ) , i n c l u d i n g i n c r e a s e s i n b a c k g r o u n d g a s ( B G ) , ap p e a r a n c e a n d t r e n d s o f c o n n e c t i o n g a s ( C G ) , a n d ma g n i t u d e s o f t r i p g a s ( T G ) a n d w i p e r g a s ( W G ) . R e g i o na l p o r e p r e s s u r e t r e n d s f r o m s o n i c d a t a , p r o v i d e d b y Co n o c o P h i l l i p s , a n d s u r f a c e m a n i f e s t a t i o n s o f h o l e c o n d i t i on s w e r e a l s o c o n s i d e r e d . As a r e f e r e n c e , P P G i s c a l c u l a t e d i n i t i a l l y w i t h a f o r m u la p r o v i d e d b y C a n r i g D r i l l i n g T e c h n o l o g y L T D , a n d t hen modified us i n g t h e i n d i c a t o r s d e s c r i b e d a b o v e , D X C a n d r e s i s t i v i t y (R E S ) d a t a . T h e f o r m u l a u s e s D X , E C D , a n d B G a s m e a s u r ed by t o t a l d i t c h g a s : PP G = E C D – ( 0 . 6 - ( ( . 0 0 1 * T L G S U ) + ( 0 . 0 5 * D X ) ) ) Th e f o r m u l a h a s c e r t a i n l i m i t a t i o n s , s u c h t h a t i t d o e s n o t a l l o w f o r a P P G m o r e t h a n 1 p p g l e s s t h a n t h e E C D , and TLGSU mu s t b e d i f f e r e n t i a t e d f r o m s h o w g a s a n d g a s c a r r i e d f r o m o v e r p r e s s u r e z o n e s , a n d i s d e p e n d e n t o n r e l i a b l e D X data. Ho w e v e r , t h e f o r m u l a p r o v e d u s e f u l i n h e l p i n g f o r m u l at e a P P G r a n g e , w h e n e s t i m a t i n g t r e n d s , a s w i t h D X C d ata, with da t a p o i n t s i n s h a l e i n t e r v a l s . Cassin #6 18 5 DRILLING DATA 5.1 Survey Data : (Survey Data References NAD83) Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 27.4 0 0 27.4 0 0 0 0 224.37 0.87 123.86 224.36 -0.83 1.24 -0.83 0.44 312.96 1.42 130.97 312.93 -1.93 2.63 -1.93 0.64 407.6 1.44 132.83 407.54 -3.5 4.39 -3.5 0.05 499.72 1.42 128.6 499.64 -5 6.13 -5 0.12 589.84 1.36 131.1 589.73 -6.4 7.81 -6.4 0.09 685.12 1.37 134.44 684.98 -7.94 9.47 -7.94 0.08 775.25 1.26 134.04 775.09 -9.39 10.95 -9.39 0.12 870.75 1.36 133.9 870.56 -10.9 12.52 -10.9 0.1 963.17 1.24 134.35 962.96 -12.36 14.03 -12.36 0.13 1056.19 1.19 133.24 1055.96 -13.73 15.45 -13.73 0.06 1148.92 1.15 133.21 1148.67 -15.02 16.83 -15.02 0.04 1242.1 1.15 133.92 1241.83 -16.31 18.19 -16.31 0.02 1334.54 1.17 131.35 1334.25 -17.58 19.56 -17.58 0.06 1425.77 1.14 133.67 1425.46 -18.82 20.92 -18.82 0.06 1519.71 1.18 136.41 1519.38 -20.17 22.26 -20.17 0.07 1612.17 1.37 138.47 1611.82 -21.69 23.65 -21.69 0.21 1704.78 1.37 140.08 1704.41 -23.36 25.1 -23.36 0.04 1796.18 1.33 144.01 1795.78 -25.06 26.42 -25.06 0.11 1885.07 1.37 137.04 1884.65 -26.67 27.75 -26.67 0.19 1982.21 1.07 132.32 1981.76 -28.13 29.21 -28.13 0.33 2072.65 1.08 133.62 2072.19 -29.29 30.46 -29.29 0.03 2167.69 1.02 134 2167.21 -30.49 31.71 -30.49 0.06 2251.51 0.95 130.34 2251.02 -31.46 32.78 -31.46 0.11 2380.61 0.97 132.96 2380.1 -32.9 34.39 -32.9 0.04 2473.16 0.97 127.9 2472.64 -33.92 35.59 -33.92 0.09 2564.76 1 131.63 2564.22 -34.92 36.79 -34.92 0.08 2657.31 1.01 131.56 2656.76 -36 38.01 -36 0.01 2749.91 1.08 128.63 2749.34 -37.09 39.3 -37.09 0.1 2842.73 1.02 120.42 2842.15 -38.05 40.7 -38.05 0.17 2935.52 1.15 121.2 2934.92 -38.95 42.21 -38.95 0.14 3027.32 1.06 126.1 3026.71 -39.93 43.68 -39.93 0.14 3119.92 0.97 125.28 3119.29 -40.89 45.01 -40.89 0.1 3212.57 0.98 127.17 3211.93 -41.82 46.28 -41.82 0.04 3305.22 1.01 123.97 3304.56 -42.75 47.59 -42.75 0.07 3398.74 1.03 129.34 3398.07 -43.75 48.93 -43.75 0.1 3491.66 1.05 131.81 3490.97 -44.84 50.21 -44.84 0.05 3585.39 1.15 129.29 3584.69 -46.01 51.57 -46.01 0.12 3676.17 1.02 133.25 3675.45 -47.14 52.87 -47.14 0.17 3770.9 0.94 126.02 3770.17 -48.18 54.11 -48.18 0.16 Cassin #6 19 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 3863.31 0.86 124.91 3862.56 -49.02 55.29 -49.02 0.09 3956.03 0.87 134.78 3955.27 -49.91 56.36 -49.91 0.16 4046.44 0.84 140.25 4045.67 -50.91 57.27 -50.91 0.1 4137.95 0.83 145.73 4137.17 -51.97 58.08 -51.97 0.09 4230.97 0.98 149.85 4230.18 -53.21 58.85 -53.21 0.18 4322.62 0.94 149.36 4321.82 -54.54 59.63 -54.54 0.04 4414.69 0.93 157.41 4413.88 -55.88 60.3 -55.88 0.14 4510.24 0.7 167.61 4509.42 -57.16 60.73 -57.16 0.28 4603.91 0.91 179.24 4603.08 -58.47 60.86 -58.47 0.28 4694.15 0.91 186.26 4693.31 -59.9 60.79 -59.9 0.12 4788.79 0.85 186.39 4787.94 -61.34 60.63 -61.34 0.06 4881.62 0.66 195.23 4880.76 -62.54 60.41 -62.54 0.24 4974.26 0.65 203.86 4973.39 -63.54 60.06 -63.54 0.11 5067.04 0.78 223.19 5066.16 -64.48 59.41 -64.48 0.29 5145.13 0.8 231.83 5144.25 -65.2 58.62 -65.2 0.15 5250.94 0.65 228.63 5250.05 -66.06 57.59 -66.06 0.15 5292.12 0.63 230.85 5291.23 -66.35 57.24 -66.35 0.08 5345.25 0.54 233.58 5344.35 -66.69 56.81 -66.69 0.18 5437.06 0.66 227.16 5436.16 -67.3 56.08 -67.3 0.15 5530.47 0.67 232.03 5529.56 -68 55.25 -68 0.06 5622.99 0.67 233.79 5622.08 -68.66 54.39 -68.66 0.02 5717.6 0.6 238.14 5716.68 -69.24 53.52 -69.24 0.09 5807.07 0.62 245.15 5806.15 -69.7 52.68 -69.7 0.09 5901.19 0.68 285.43 5900.26 -69.76 51.68 -69.76 0.48 5992.37 0.94 271.74 5991.43 -69.59 50.41 -69.59 0.35 6085.04 0.85 232.99 6084.09 -69.98 49.11 -69.98 0.65 6132.92 0.91 220.73 6131.96 -70.49 48.57 -70.49 0.41 6203 0.91 220.73 6202.04 -71.33 47.85 -71.33 0 Ca s s i n # 6 20 5. 2 B i t R e c o r d Bi t S i z e M a k e T y p e / S # J e t s / T F A De p t h I n MD / To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) WO B (K l b s ) RP M W e a r B H A 1 1 2 . 2 5 B a k e r V M - 3 / 5 2 1 8 9 4 5 3x 1 8 , 1x 1 4 / 0. 8 9 5 8 10 8 ’ 2 0 1 ’ 2 . 7 7 3 . 3 3 . 3 4 2 N O T G R A D E D 1 RR 1 1 2 . 2 5 B a k e r V M - 3 / 5 2 1 8 9 4 5 3x 1 8 , 1x 1 4 / 0. 8 9 5 8 30 9 ’ 2 0 1 5 ’ 2 7 . 1 7 4 . 3 1 1 . 4 8 3 1 - 1 - W T - A - E - I - N O - T D 2 2 8 . 5 H D B S F X 5 6 / 1 2 0 0 7 3 0 2 3x 1 5 , 2x 1 6 / 0. 9 1 0 4 23 2 4 ’ 2 8 9 0 ’ 2 3 . 3 1 2 3 . 9 1 0 7 5 1 - 2 - C T - S - X - I - N O - B H A 3 2R R 1 8 . 5 H D B S F X 5 6 / 1 2 0 0 7 3 0 2 3x 1 5 , 2x 1 6 / 0. 9 1 0 4 52 1 4 ’ 8 6 ’ 3 . 3 4 6 . 0 4 . 9 1 0 0 1 - 2 - C T - S - X - I - N O - C P 4 3 8 . 5 H T C 4 0 6 Z / 7 1 3 8 3 9 5 N / A 5 3 3 0 ’ 1 6 8 ’ 8 . 5 1 9 . 7 1 2 .1 4 7 4 N O T G R A D E D 5 3R R 1 8 . 5 H T C 4 0 6 Z / 7 1 3 8 3 9 5 N / A 5 4 9 8 ’ 1 8 5 ’ 7 . 7 2 4 . 6 1 6 . 9 8 0 N O T G R A D E D 6 3R R 2 8 . 5 H T C 4 0 6 Z / 7 1 3 8 3 9 5 N / A 5 6 8 3 ’ 1 4 3 ’ 5 . 9 3 1 . 5 1 7 . 9 8 0 N O T G R A D E D 7 2R R 2 8 . 5 8 . 5 H D B S FX 5 6 / 12 0 0 7 3 0 2 58 2 6 ’ 3 7 7 ’ 3 4 . 6 4 9 . 4 8 . 3 8 0 1 - 2 - C T - S - X - I - N O - T D 8 Ca s s i n # 6 21 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O ; M u d T y p e : S p u d M u d Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 3/ 3 0 / 2 0 1 3 0 1 0 . 0 - 3 6 4 5 1 7 7 4 5 / 6 8 / 9 5 N C - / - 1 0 . 0 / 90 - 9 . 3 6 0 0 8 0 3/ 3 1 / 2 0 1 3 6 1 5 1 0 . 0 - 4 0 0 5 3 6 4 4 6 / 9 7 / 1 1 7 8 . 5 3 / - 8 . 5 / 9 2 - 9 . 1 1 4 0 0 1 0 0 4/ 0 1 / 2 0 1 3 2 2 1 5 1 0 . 1 - 3 6 8 5 0 6 5 6 0 / 9 9 / 1 1 1 5 . 8 3 / - 1 3. 0 2 / 8 6 - 9 . 5 7 5 0 8 0 4/ 0 2 / 2 0 1 3 2 3 2 4 1 0 . 0 - 1 6 7 4 5 5 4 5 0 / 8 3 / 9 9 5 . 5 3 / - 1 2 .5 1 / 8 7 1 . 5 8 . 6 8 0 0 8 0 4/ 0 3 / 2 0 1 3 2 3 2 4 9 . 8 - 5 5 2 4 1 5 5 / 1 5 / 1 9 - - / - 1 0 1 / 8 9 1 . 5 7 . 6 7 5 0 8 0 4/ 0 4 / 2 0 1 3 2 3 5 1 9 . 8 - 4 7 1 7 1 1 3 / 1 1 / 1 6 9 . 6 1 / - 1 0 1 / 89 1 . 5 1 0 . 2 7 5 0 8 0 MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o nt e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y W L = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t N C = N o t R e p o r t e d Ca s s i n # 6 22 Co n t r a c t o r : M I S W A C O ; M u d T y p e : 9 . 8 K l a - S h i e l d Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 4/ 0 5 / 2 0 1 3 4 1 2 0 9 . 8 - 5 6 1 6 2 8 6 / 1 3 / 2 1 3 . 9 - 2 / 9 4 / 8 7 - 9 . 8 3 4 0 0 0 1 0 0 4/ 0 6 / 2 0 1 3 5 2 1 4 9 . 8 - 6 8 1 7 2 7 7 / 1 1 / 1 6 3 . 8 - - / 2 1 0 4 /8 6 - 9 . 8 3 4 5 0 0 1 0 0 4/ 0 7 / 2 0 1 3 5 3 3 0 9 . 9 - 6 1 1 5 2 3 7 / 1 4 / 2 1 3 . 7 1 / 2 1 0 4 / 86 - 1 0 . 1 3 2 5 0 0 1 0 0 4/ 0 8 / 2 0 1 3 5 4 9 8 9 . 8 - 1 3 9 3 2 4 0 7 / 1 0 / 1 5 3 . 5 1 / 2 1 0 . 5 3 / 8 7 - 1 0 . 0 3 4 0 0 0 1 0 0 4/ 0 9 / 2 0 1 3 5 5 9 5 * 9 . 9 - 1 3 5 3 2 4 1 7 / 1 1 / 1 5 3 . 3 1 / 1 1 1 . 5 3 / 8 6 T r 9 . 8 3 6 0 0 0 1 0 0 4/ 1 0 / 2 0 1 3 5 6 8 3 * 9 . 9 - 1 4 9 3 1 3 5 6 / 8 / 1 1 3 . 2 3 . 2 1 1 . 5 3 / 8 6 T r 9 . 8 3 3 0 0 0 1 0 0 4/ 1 1 / 2 0 1 3 5 8 2 5 * 9 . 9 - 1 3 8 2 6 2 5 5 / 6 / 8 3 ½ 1 2 3 / 8 5 T r 9 . 8 3 5 0 0 0 8 0 4/ 1 2 / 2 0 1 3 6 0 3 8 * 9 . 9 - 1 1 4 3 3 3 9 6 / 9 / 1 0 3 ½ 1 2 4 / 8 4 Tr 9 . 6 3 5 0 0 0 8 0 4/ 1 3 / 2 0 1 3 6 2 0 3 9 . 8 1 0 . 5 9 6 6 1 9 2 6 6 / 1 1 / 1 7 3 . 4 ½ 1 1 4/ 8 5 T r 9 . 8 3 3 0 0 0 1 0 0 4/ 1 4 / 2 0 1 3 6 2 0 3 9 . 8 - 6 8 1 4 2 1 4 / 8 / 1 1 3 . 4 1 / - 1 1 4 / 8 5 T r 9 . 8 3 4 0 0 0 1 0 0 4/ 1 5 / 2 0 1 3 6 2 0 3 9 . 8 - 8 2 1 9 2 5 5 / 1 0 / 1 3 3 . 1 ½ 1 1 4 / 8 5 T r 1 0 . 0 3 3 0 0 0 1 0 0 4/ 1 6 / 2 0 1 3 6 2 0 3 9 . 8 - 6 4 1 5 2 1 5 / 8 / 1 1 3 . 1 1 / - 1 1 4 / 8 5 T r 1 0 . 0 3 1 0 0 0 1 0 0 4/ 1 7 / 2 0 1 3 6 2 0 3 9 . 8 - 8 5 1 9 2 8 7 / 1 0 / 1 4 3 . 2 1 / - 1 0 4 / 86 T r 1 0 . 0 3 4 0 0 0 1 0 0 4/ 1 8 / 2 0 1 3 6 2 0 3 9 . 9 - 9 5 1 9 2 8 7 / 1 1 / 1 4 3 . 2 1 / - 1 0 4 / 86 T r 1 0 . 0 3 2 0 0 0 1 0 0 4/ 1 9 / 2 0 1 3 6 2 0 3 9 . 8 - 9 8 1 8 2 6 6 / 1 0 / 1 3 3 . 2 1 / - 1 0 4 / 86 T r 1 0 . 1 3 3 0 0 0 1 0 0 MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o nt e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y W L = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t N C = N o t R e p o r t e d T r = T r a c e * K l a C o r i n g F l u i d 23 6 DAILY REPORTS ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill L. Martin, S. Heim Date: 03/30/2013 Time: 00:01 Current Depth (MD): 108’ Current Depth (TVD): 108’ Current Operations: P/U BHA 24 hr Footage (MD): 0 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 MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue working on rig acceptant checklist. Load spud mud into pits and N/U diverter system. Load pipe shed with MWD tools and 96 joints of 5” drill pipe. Test diverter (good). P/U drill pipe and HWDP and rack back. P/U BHA at report time. Calibrations: THA, Chromatograph, Peak Simple Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill L. Martin, S. Heim Date: 03/31/2013 Time: 00:01 Current Depth (MD): 827’ Current Depth (TVD): 827’ Current Operations: Drilling 24 hr Footage (MD): 719’ Drilling Parameters ROP: Current: 70 Max: 574 Torque: Current: 1671 Max: 2390 WOB: Current 4.6 Max: 21 RPM: Current: 92 Max: 94 PP: Current: 957 Max: 1289 Lag: Strokes: 993 Time: 8.5 Surf-Surf: Strokes: 1080 Time: 9.3 ECD: Current: Max: Mud Properties MW: 10.0 FV: 400 PV: 53 YP: 64 FL: 8.5 Gels: 46/97/117 Sol: 8.5 pH: 9.1 Cl -: 1400 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 13 Max: 19 Depth (MD/TVD): 775 Avg BG : 2 Gas Events Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 500’ 0 Lithologies: Current: 90% Claystone 10% Siltstone/sand Last 24 hrs: 80% Claystone 10% Siltstone 10% Sand Operational Summary: Fill hole and test lines to 3500 psi (good). Circulate and Condition mud. Drill to 309’ and CBU. POOH and L/D BHA. P/U BHA #2 and RIH. Drilling ahead at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill L. Martin, S. Heim Date: 04/01/2013 Time: 00:01 Current Depth (MD): 2324’ Current Depth (TVD): 2324’ Current Operations: Circulating 24 hr Footage (MD): 1497’ Drilling Parameters ROP: Current: - Max: 253 Torque: Current: - Max: 3841 WOB: Current - Max: 41 RPM: Current: - Max: 92 PP: Current: - Max: 2117 Lag: Strokes: 2793 Time: 19.8 Surf-Surf: Strokes: 3144 Time: 22.3 ECD: Current: Max: Mud Properties MW: 10.1 FV: 368 PV: 50 YP: 65 FL: 5.8 Gels: 60/99/111 Sol: 13 pH: 9.5 Cl -: 750 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 63 Depth (MD/TVD): 775 Avg BG : 14 Gas Events Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 906’ 54 16773 40 0 42 1000’ 24 6884 6 0 3 1500’ 8.5 1727 2000’ 8 1607 Lithologies: Current: 95% Claystone 5%sand Last 24 hrs: 70% Claystone 20% Sand 10% Siltstone Operational Summary: Drill ahead to TD at 2324’ MD. CBU and waiting on geologist. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill L. Martin, S. Heim Date: 04/02/2013 Time: 00:01 Current Depth (MD): 2324’ Current Depth (TVD): 2324’ Current Operations: Prepping to cement 24 hr Footage (MD): 0’ 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 MW: 10.0 FV: 167 PV: 45 YP: 54 FL: 5.5 Gels: 50/83/99 Sol: 12.5 pH: 8.6 Cl -: 800 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 Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: POOH to 2235’ and monitor well (static). POOH to 664’ and circulate hole clean. RIH to 2235’, circulate and condition mud. Monitor well (static). POOH and L/D BHA. R/U casing equipment and run casing to 2313’. Condition mud and circulate, R/D casing equipment and R/U cementing equipment. Circulate and condition mud. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill L. Martin, S. Heim Date: 04/03/2013 Time: 00:01 Current Depth (MD): 2324’ Current Depth (TVD): 2324’ Current Operations: Testing BOP’s 24 hr Footage (MD): 0’ 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 Pit #5 MW: 9.8 FV: 55 PV: 24 YP: 15 FL: - Gels: 5/15/19 Sol: 10 pH: 7.6 Cl -: 750 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 Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Circulate and finish R/U cementing equipment. Pump cement and R/D cementing equipment. N/D diverter and M/U conduit to find TOC, tagged up at 7’ and wait on cement. M/U torque speed head and casing spool, L/D conduit, P/U mouse hole, strap 5” pipe. Decision made to N/U BOP. N/U BOP and testing equipment. Testing BOP at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill L. Martin, S. Heim Date: 04/04/2013 Time: 00:01 Current Depth (MD): 2324’ Current Depth (TVD): 2344’ Current Operations: Displacing 24 hr Footage (MD): 20’ Drilling Parameters ROP: Current: 103 Max: 212 Torque: Current: 1362 Max: 2063 WOB: Current 4 Max: 8 RPM: Current: 49 Max: 49 PP: Current: 1606 Max: 1744 Lag: Strokes: 1141 Time: 8 Surf-Surf: Strokes: 1497 Time: 10.5 ECD: Current: Max: Mud Properties MW: 9.8 FV: 47 PV: 17 YP: 11 FL: 9.6 Gels: 3/11/16 Sol: 10 pH: 10.2 Cl -: 750 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 2 Max: 2 Depth (MD/TVD): 2344 Avg BG : 2 Gas Events Down time (hours) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 2340 0 Lithologies: Current: Claystone 50% Siltstone 25% Sand 25% Last 24 hrs: Claystone 50% Siltstone 25% Sand 25% Operational Summary: Finish testing BOP’s and R/D test equipment. P/U 17 stands of 5” DP and M/U 8.5” BHA. Single into hole with 45 joints of 5” DP. Test casing and RIH to TOC @ 2204’. Drill out cement and casing shoe and 20’ of new hole. Circulate and condition mud. Perform FIT to 13.5 EMW. Displace well to 9.8 ppg Kla-Shield mud. Calibrations: Peak Simple Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill D. Coats Date: 04/05/2013 Time: 00:01 Current Depth (MD): 4129’ Current Depth (TVD): 4129’ Current Operations: Drilling 24 hr Footage (MD): 1785’ Drilling Parameters ROP: Current: 167 Max: 269 Torque: Current: 3136 Max: 4186 WOB: Current 12 Max: 21 RPM: Current: 81 Max: 109 PP: Current: 2413 Max: 2471 Lag: Strokes: 1953 Time: 13 Surf-Surf: Strokes: 2619 Time: 17.5 ECD: Current: Max: Mud Properties MW: 9.8 FV: 56 PV: 16 YP: 28 FL: 3.9 Gels: 6/13/21 Sol: 9 pH: 9.8 Cl -: 34000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 25 Max: 65 Depth (MD/TVD): 3955 Avg BG : 15 Gas Events Depth (MD) Gas (units above background) 3654’ 8 3747’ 14 3840’ 8 3930’ 16 Connection Gas 4023’ 24 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 3990’ 27 4804 545 229 30 52 4020’ 24 4428 497 198 25 49 4050’ 22 4066 451 172 20 46 4080’ 24 4508 491 195 27 55 4105’ 18 3161 339 139 22 40 Lithologies: Current: 50% Siltstone 40% claystone 10% sand Last 24 hrs: 50% Siltstone 40% claystone 10% sand Operational Summary: Drilled ahead to 2542’ and CBU. Pull to shoe and troubleshoot mud pump #2. RIH and drill ahead to 4129’ at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill D. Coats Date: 04/06/2013 Time: 00:01 Current Depth (MD): 5214’ Current Depth (TVD): 5214’ Current Operations: L/D BHA 24 hr Footage (MD): 1085’ Drilling Parameters ROP: Current: - Max: 450 Torque: Current: - Max: 6453 WOB: Current - Max: 27 RPM: Current: - Max: 89 PP: Current: - Max: 2955 Lag: Strokes: 2446 Time: 16.3 Surf-Surf: Strokes: 3307 Time: 22 ECD: Current: Max: Mud Properties MW: 9.8 FV: 68 PV: 17 YP: 27 FL: 3.8 Gels: 7/11/16 Sol: 10 pH: 9.8 Cl -: 34500 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 44 Depth (MD/TVD): 5177 Avg BG : 22 Gas Events Depth (MD) Gas (units above background) Depth (MD) Gas (units above background) 4116 23 4857 18 4209 17 4950 22 4580 13 5043 22 4672 20 5138 36 Connection Gas 4765 26 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 50% Siltstone 40% Claystone 10% Sand Last 24 hrs: 50% Siltstone 30% Claystone 20% Sand Operational Summary: Drilled to 5214’ and monitor well (static). POOH to 4950’, improper hole fill, trip back to bottom. CBU and pump out 10 stands. attempt to pull out on elevators, hole still swabbing, continue to pump out of hole to 2267’. Attempt to POOH on elevators but still getting improper hole fill. Monitor well. L/D BHA at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill D. Coats Date: 04/07/2013 Time: 00:01 Current Depth (MD): 5330’ Current Depth (TVD): 5330’ Current Operations: P/U Coring BHA 24 hr Footage (MD): 116’ Drilling Parameters ROP: Current: - Max: 113 Torque: Current: - Max: 4246 WOB: Current - Max: 15 RPM: Current: - Max: 101 PP: Current: - Max: 2682 Lag: Strokes: 2518 Time: 16.5 Surf-Surf: Strokes: 3399 Time: 23 ECD: Current: Max: Mud Properties MW: 9.9 FV: 61 PV: 15 YP: 23 FL: 3.7 Gels: 7/14/21 Sol: 10 pH: 10.1 Cl -: 32500 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 124 Depth (MD/TVD): 5322 Avg BG : 19 Gas Events Downtime (hrs) Gas (units) 17 50 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5220 10 1508 184 54 1 4 5250 9 1407 172 55 4 5 5280 10 1310 158 53 6 5 5310 10 1416 134 17 28 5 2 1 5329 80 20433 2062 305 469 84 68 31 Lithologies: Current: 50% sandstone 30% sand 10% siltstone 10% claystone Last 24 hrs: 50% sandstone 30% sand 10% siltstone 10% claystone Operational Summary: Finish L/D BHA and P/U new BHA. RIH to 2236 and slip and cut drill line. RIH to 5108. Wash and ream to 5160 and MAD pass. Drill ahead to 5330’ and CBU. Pump out of hole 10 stands then POOH on elevators to surface. L/D BHA and P/U coring BHA Calibrations: Peak Simple Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill D. Coats Date: 04/08/2013 Time: 00:01 Current Depth (MD): 5498’ Current Depth (TVD): 5330’ Current Operations: POOH 24 hr Footage (MD): 168’ Drilling Parameters ROP: Current: - Max: 86 Torque: Current: - Max: 4141 WOB: Current - Max: 23 RPM: Current: - Max: 76 PP: Current: - Max: 1400 Lag: Strokes: 2584 Time: 17.2 Surf-Surf: Strokes: 3628 Time: 23.6 ECD: Current: Max: Mud Properties MW: 9.8 FV: 139 PV: 32 YP: 40 FL: 3.5 Gels: 7/10/15 Sol: 10.5 pH: 10.0 Cl -: 34000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 284 Depth (MD/TVD): 5332 Avg BG : 28 Gas Events Downtime (hrs) Gas (units) 14 58 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5460 13.7 1584 343 177 41 46 4 5470 13.8 2327 375 39 122 23 31 5480 6 1121 244 169 21 15 57 5490 6.9 856 140 61 21 8 19 5500 5.5 n/a n/a n/a n/a n/a n/a n/a Lithologies: Current: 70% siltstone 20% Claystone 10% sandstone Last 24 hrs: 40% siltstone 30% sandstone 20% claystone 10% sand Operational Summary: P/U coring BHA and RIH to 5195’ and displace well to coring fluid. Drop ball and RIH to 5330. Core to 5498’ and monitor well (static). Pump out first 3 stands then begin POOH following coring procedure. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill D. Coats Date: 04/09/2013 Time: 00:01 Current Depth (MD): 5683’ Current Depth (TVD): 5683’ Current Operations: Circulating 24 hr Footage (MD): 185’ Drilling Parameters ROP: Current: - Max: 61 Torque: Current: - Max: 4444 WOB: Current - Max: 24 RPM: Current: - Max: 85 PP: Current: - Max: 1433 Lag: Strokes: 2669 Time: 33.4 Surf-Surf: Strokes: 3667 Time: 50.8 ECD: Current: Max: Mud Properties MW: 9.9 FV: 135 PV: 32 YP: 41 FL: 3.3 Gels: 7/11/15 Sol: 11.5 pH: 9.8 Cl -: 36000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 20 Max: 46 Depth (MD/TVD): 5617 Avg BG : 28 Gas Events Downtime (hrs) Gas (units) 24 84 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5640 34 5001 717 411 65 117 19 8 5650 31 4669 680 401 62 115 18 6 5660 33.5 4652 695 425 67 127 19 7 5670 27.2 3702 570 363 59 113 15 7 5680 22 3053 485 321 53 104 13 7 Lithologies: Current: 70% sandstone 10% siltstone 10% claystone 10% sand Last 24 hrs: 50% sandstone 20% claystone 20% siltstone 10% sand Operational Summary: Finish POOH with core barrel as per procedure. R/U and gamma ray core barrels. L/D core barrels and remove core. M/U core barrels. RIH and begin coring. Core to 5683’ and circulate. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill D. Coats Date: 04/10/2013 Time: 00:01 Current Depth (MD): 5761’ Current Depth (TVD): 5761’ Current Operations: Coring 24 hr Footage (MD): 78’ Drilling Parameters ROP: Current: 30 Max: 57 Torque: Current: 3071 Max: 6188 WOB: Current 18 Max: 24 RPM: Current: 80 Max: 84 PP: Current: 1319 Max: 1409 Lag: Strokes: 2704 Time: 33.8 Surf-Surf: Strokes: 3715 Time: 50.8 ECD: Current: Max: Mud Properties MW: 9.9 FV: 149 PV: 31 YP: 35 FL: 3.2 Gels: 6/8/11 Sol: 11.5 pH: 9.8 Cl -: 33000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 20 Max: 46 Depth (MD/TVD): 5617 Avg BG : 28 Gas Events Downtime (hrs) Gas (units) 20 91 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5790 70 11217 1713 1105 149 229 49 35 5800 54 7922 1203 807 113 178 40 30 5810 44 6888 1040 725 105 170 40 31 5820 39 5616 844 610 92 151 37 29 5825 50 7213 1081 797 122 203 51 40 Lithologies: Current: 70% sandstone 10% siltstone 10% claystone 10% sand Last 24 hrs: 60% sandstone 20% claystone 10% siltstone 10% sand Operational Summary: Finish circulating and POOH with core barrel as per coring procedure. L/D and gamma ray core. P/U coring barrels and RIH and begin coring run #3. Coring at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: L. Hill D. Coats Date: 04/11/2013 Time: 00:01 Current Depth (MD): 5825’ Current Depth (TVD): 5825’ Current Operations: Testing BOP’s 24 hr Footage (MD): 63’ Drilling Parameters ROP: Current: - Max: 73 Torque: Current: - Max: 5958 WOB: Current - Max: 26 RPM: Current: - Max: 81 PP: Current: - Max: 1382 Lag: Strokes: 2733 Time: 36.4 Surf-Surf: Strokes: 3755 Time: 51 ECD: Current: Max: Mud Properties MW: 9.9 FV: 138 PV: 26 YP: 25 FL: 3 Gels: 5/6/8 Sol: 12 pH: 9.8 Cl -: 35000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 136 Depth (MD/TVD): 5785 Avg BG : 62 Gas Events Downtime (hrs) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: 60% sandstone 20% claystone 10% siltstone 10% sand Operational Summary: Core to 5826’. Observe wt. not drilling off and pump pressure increase. Descision made to POOH and break off core. CBU and POOH as per procedure. L/D and gamma ray core. Rig up testing equipment and test BOP’s. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock D. Coats Date: 04/12/2013 Time: 00:01 Current Depth (MD): 6038’ Current Depth (TVD): 6038’ Current Operations: POOH 24 hr Footage (MD): 212’ Drilling Parameters ROP: Current: - Max: 110 Torque: Current: - Max: 4264 WOB: Current - Max: 19 RPM: Current: - Max: 102 PP: Current: - Max: 2293 Lag: Strokes: 2817 Time: 26.8 Surf-Surf: Strokes: 3822 Time: 36.4 ECD: Current: Max: Mud Properties MW: 9.9 FV: 114 PV: 33 YP: 39 FL: 3 Gels: 6/9/10 Sol: 12 pH: 9.6 Cl -: 35000 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 153 Depth (MD/TVD): 5826 Avg BG : 34 Gas Events Downtime (hrs) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5990 8.7 1001 167 97 36 35 7 3 6000 10.1 1229 150 116 39 55 6 4 6010 10.1 1572 166 147 48 75 7 6 6020 12.9 1929 295 186 67 74 13 6 6030 12 1698 348 169 67 47 13 3 Lithologies: Current: 60% Siltstone, 10% sandstone, 10% claystone, 10% shale Last 24 hrs: 40% sandstone 30% siltstone 20% sand 10% claystone Operational Summary: Core to 5826’. Observe wt. not drilling off and pump pressure increase. Descision made to POOH and break off core. CBU and POOH as per procedure. L/D and gamma ray core. Rig up testing equipment and test BOP’s. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock D. Coats Date: 04/13/2013 Time: 00:01 Current Depth (MD): 6203’ Current Depth (TVD): 6203’ Current Operations: POOH 24 hr Footage (MD): 171’ Drilling Parameters ROP: Current: - Max: 195 Torque: Current: - Max: 4418 WOB: Current - Max: 14 RPM: Current: - Max: 105 PP: Current: - Max: 2420 Lag: Strokes: 2886 Time: 27 Surf-Surf: Strokes: 3917 Time: 36.6 ECD: Current: Max: Mud Properties MW: 9.8 FV: 66 PV: 19 YP: 26 FL: 3.4 Gels: 6/11/17 Sol: 11 pH: 9.8 Cl -: 33000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: 14 Depth (MD/TVD): 6160 Avg BG : 9.8 Gas Events Downtime (hrs) Gas (units) 18 36 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: 60% Siltstone 30% Claystone/shale 10% Sandstone Operational Summary: Finish POOH and L/D BHA. P/U new BHA and RIH with drilling assembly. Displace to KlaShield mud. Drill to TD at 6203’ and CBU 3x. POOH on elevators at report time. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock D. Coats Date: 04/14/2013 Time: 00:01 Current Depth (MD): 6203’ Current Depth (TVD): 6203’ Current Operations: R/U wireline tools 24 hr Footage (MD): 0’ 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 MW: 9.8 FV: 68 PV: 14 YP: 21 FL: 3.4 Gels: 4/8/11 Sol: 11 pH: 9.8 Cl -: 34000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Avg BG : - Gas Events Downtime (hrs) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: RIH to bottom and CBU. MAD pass from 6203’ to 5340’. Monitor well (static) and POOH to surface. L/D BHA and R/U to run wireline. Calibrations: None Failures: None Daily Cost: $3010.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock D. Coats Date: 04/15/2013 Time: 00:01 Current Depth (MD): 6203’ Current Depth (TVD): 6203’ Current Operations: Wireline 24 hr Footage (MD): 0’ 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 MW: 9.8 FV: 82 PV: 19 YP: 25 FL: 3.1 Gels: 5/10/13 Sol: 11 pH: 10.0 Cl -: 33000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Avg BG : - Gas Events Downtime (hrs) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Troubleshoot and C/O wireline tools. RIH with tools. Calibrations: None Failures: None Daily Cost: $2395.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock D. Coats Date: 04/16/2013 Time: 00:01 Current Depth (MD): 6203’ Current Depth (TVD): 6203’ Current Operations: SONIC/XRMI wireline 24 hr Footage (MD): 0’ 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 MW: 9.8 FV: 64 PV: 15 YP: 21 FL: 3.1 Gels: 5/8/11 Sol: 11 pH: 10.0 Cl -: 31000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Avg BG : - Gas Events Downtime (hrs) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish wireline run #1 and R/D wireline. M/U cleanout BHA and RIH to 2228’ and slip and cut drill line. RIH to bottom and CBU 3x. Monitor well (static). POOH and L/D BHA. R/U wireline tools and RIH with RSWC. L/D tool and P/U sonic/XRMI tools and RIH. Calibrations: None Failures: None Daily Cost: $2395.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock R. Reinhardt Date: 04/17/2013 Time: 00:01 Current Depth (MD): 6203’ Current Depth (TVD): 6203’ Current Operations: RT Scanner wireline 24 hr Footage (MD): 0’ 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 MW: 9.8 FV: 85 PV: 19 YP: 28 FL: 3.2 Gels: 7/10/14 Sol: 10 pH: 10.0 Cl -: 34000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Avg BG : - Gas Events Downtime (hrs) Gas (units) 34 47 Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish sonic/XRMI wireline run and L/D tools. P/U and run MRIL/GEM/SGR tools. Finish running MRIL/GEM/SGR and L/D tools and all wireline equipment. M/U cleanout BHA and RIH. CBU 3x and monitor well (static). POOH to 2292’ and monitor well (static). POOH and rack back BHA. R/U wireline and run RT scanner. Calibrations: None Failures: None Daily Cost: $2395.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock R. Reinhardt Date: 04/18/2013 Time: 00:01 Current Depth (MD): 6203’ Current Depth (TVD): 6203’ Current Operations: Running in hole 24 hr Footage (MD): 0’ 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 MW: 9.9 FV: 95 PV: 19 YP: 28 FL: 3.2 Gels: 7/11/14 Sol: 10 pH: 10.0 Cl -: 32000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Avg BG : - Gas Events Downtime (hrs) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish running RT scanner and L/D tool. M/U VSP tool and RIH. Finish and L/D tool and wireline equipment. R/U and test BOP. R/D BOP testing equipment and P/U BHA. Running in hole at report time. Calibrations: None Failures: None Daily Cost: $2395.00 ConocoPhillips Alaska Inc. Cassin #6 Daily Report Report for: G. Whitlock R. Reinhardt Date: 04/19/2013 Time: 00:01 Current Depth (MD): 6203’ Current Depth (TVD): 6203’ Current Operations: Running 7” casing 24 hr Footage (MD): 0’ 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 MW: 9.8 FV: 98 PV: 18 YP: 26 FL: 3.2 Gels: 6/10/13 Sol: 10 pH: 10.1 Cl -: 33000 Ca ++: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Avg BG : - Gas Events Downtime (hrs) Gas (units) Trip Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish RIH to 6203’ and CBU. Monitor we// (static), and begin POOH. Monitor well at shoe (static). Change out top rams to 7”, R/U BOP testing equipment and test BOP’s. R/U casing equipment and begin running 7” casing. Calibrations: None Failures: None Daily Cost: $2395.00 24 7 SHOW REPORTS Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 2640 MD 2726 MD Country: 2639.494 TVD 2725.486 TVD Averages Before During After Maximum ROP (fph) 153 144 166 257 WOB 2 4 5 12 RPM 52 48 87 98 Mud Weight 10 10 10 10 Chloride 34,000 34,000 34,000 34,000 Total Gas 18 23 14 55 C1 (ppm) 3,426 4,458 2,805 10,791 C2 (ppm) 22 28 17 66 C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Moderate Fluorescence Cut Fluorescence Residual Cut Stain Amount 30% Type inst/strm Amount Amount 5% Distribution on clasts Intensity moderate Color Color grn/yellow Intensity mild Color wht/grn Residual Fluorescence Cut Color pale/yel/wht Intesity Color grn/yellow Color Oil Show Rating Free Oil in Mud Comments Report by: moderate Harry E. Bleys Oil droplets found through out cuttings. 30% sample fluorescence. Instant cut fluorescence of a milky white green. 1.6 pale yel NORTH SLOP BOUROUGH ALASKA UNITED STATES 50-103-20666-00-00 CASSIN #6 BEAR TOOTH UNIT DOYON 141 04/06/20130 09;15 Dominantly translucent quartz in loose unconsolidated silty sandstone and sands increasing; at 2670 ft dark oil droplets seen in numerous spots throughout the sample in silty sandstone and sands; at 2670 ft 30 % dull yellow gold sample fluorescence with instantaneous white milky green cut fluorescence which continues through to 2730 ft; at 2760 ft there is no sample fluorescence or cut; petroleum odor is slight but present; silty sandstone soft and dominantly matrix supported; angular to sub-angular grains; fair sorted; medium to high sphericity leading to young to middle aged textural maturity. low yel Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 2 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 5307 MD 5360 MD Country: 5306.234 TVD 5359.229 TVD Averages Before During After Maximum ROP (fph) 51.5 44.6 43.6 86.1 WOB 5.1 5.9 8.8 9.0 RPM 104.8 84.2 78.8 101.0 Mud Weight 9.9 9.9 9.9 9.9 Chloride 32,500 32,500 32,500 32,500 Total Gas 13 284 19 284 C1 (ppm) 1,943 53,148 3,233 53,148 C2 (ppm) 220 5,532 466 5,532 C3 (ppm) 64 1,877 74 1,877 C4 (ppm) 37 615 152 615 C5 (ppm) 3 111 32 111 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain none Amount Type opaque Amount Amount none Distribution 30% Intensity moderate Color Color Intensity moderate Color milky/wht Residual Fluorescence Cut Color yell/gold inst/cut Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: 20% yellow Sandstone has a salt and pepper appearance;. dark gray grain supported to matrix supported good visual porosity; sub angular to rounded grain; well sorted; very fine to lower fine grain size; moderate sphericity; loose unconsolidated sands in well sorted very fine to fine upper grain size; dominantly a quartz; a sample, with a mild yellow gold sample fluorescence, a milky white green cut fluorescence with a moderate yellow residual ring NORTH SLOP BOUROUGH ALASKA UNITED STATES 50-103-20666-00-00 CASSIN #6 BEAR TOOTH UNIT DOYON 141 04/10/20130 10:30 moderate Harry E. Bleys A mild yellow gold sample fluorescence, and a milky white green cut fluorescence with a moderate yellow residual ring. none 2 light yellow Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 3 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 5700 MD 5800 MD Country: TVD TVD Averages Before During After Maximum ROP (fph) 22 30 39 73 WOB 14 19 16 26 RPM 79 80 83 81 Mud Weight 9.9 9.9 9.9 10 Chloride 33,000 33,000 33,000 33,000 Total Gas 23 85 56 186 C1 (ppm) 3,117 13,001 8,014 29,484 C2 (ppm) 498 1,943 1,210 4,266 C3 (ppm) 325 1,204 847 2,580 C4 (ppm) 147 402 325 793 C5 (ppm) 20 81 128 152 Lithology Cuttings Analysis Odor Fluorescence Cut Fluorescence Residual Cut Stain Amount see Type see Amount Amount none Distribution fluorescence Intensity fluorescence Color Color Intensity tab Color tab Residual Fluorescence Cut Color Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: Medium gray with light brown hues; poor consolidation; lower fine to upper very fine with upper fine and lower medium common but not abundant; moderate to poor sorting; sub angular to sub rounded to angular; moderate sphericity; argillaceous; partially calcareous; mild reaction to hcl; grain supported; quartz dominated with clear to translucent grains; abundant carbonaceous sediment and trace lamina; thick structure interbedded with thin siltstone beds NORTH SLOP BOUROUGH ALASKA UNITED STATES 50-103-20666-00-00 CASSIN #6 BEAR TOOTH UNIT DOYON 141 04/10/20130 22:30 Joshua Dubowski Moderate to strong whitish gold to greenish gold fluorescence on samples; cut only observed on 5710 and 5720 sample; pale whitish blue residual cut; weak to occasionally moderate petroleum odor through out the interval. none Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 4 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 5847 MD 5896 MD Country: TVD TVD Averages Before During After Maximum ROP (fph) 40 50 39 110 WOB 14.8 7.1 16.0 10.0 RPM 96 100 83 100 Mud Weight 9.9 9.9 9.9 9.9+ Chloride 33,000 33,000 33,000 33,000 Total Gas 50 78 56 145 C1 (ppm) 6,700 9,793 8,014 18,725 C2 (ppm) 920 1,389 1,210 2,633 C3 (ppm) 636 778 847 1,571 C4 (ppm) 274 309 325 563 C5 (ppm) 60 61 128 118 Lithology Cuttings Analysis Odor wk-mod Fluorescence Cut Fluorescence Residual Cut Stain Amount 70% Type slw-strm Amount Amount none Distribution even Intensity bright Color Color Intensity bright Color wht-yel Residual Fluorescence Cut Color yel-gld Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: bright Joshua Dubowski/Harry E. Bleys strong green yellow gold sample fluorescence; instant streaming in 5890 ft. sample fluorescence 60% to 80%; slow bright milky white yellow cut fluorescence at 5890 ft none 2 yel-gld NORTH SLOP BOUROUGH ALASKA UNITED STATES 50-103-20666-00-00 CASSIN #6 BEAR TOOTH UNIT DOYON 141 04/12/20130 13:00 Salt and pepper appearance. Lower fine to upper fine grain size; grain supported sub angular to sub rounded; argillaceous matrix cement; strongly indurated and good visual porosity; well aged textural maturity; fair to high sphericity. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 CONOCOPHILLIPS CASSIN #6 Ratio Plot #1 APRIL 10, 2013 Depths 5250' to 5683' 1 10 100 1000 10000 1 2 3 4 DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 CONOCOPHILLIPS CASSIN #6 Ratio Plot #2 APRIL 10, 2013 Depths 5611' to 5683' 1 10 100 1000 10000 1 2 3 4 DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Reservoir Description Tool (RDT) Client: CONOCO PHILLIPS ALASKA, INC. Well: CASSIN # 6 Field: NPR-A Rig: DOYON 141 Country: USA Prepared by: Billy Wyrick Matthew Steele Jonathan Nicholson Date: April 21, 2013 Reservoir Testing Studio - RTS Report Reservoir Testing Studio - RTS Report Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 2 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. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 3 Table of Contents Disclaimer...................................................................................................................................................... 2 Table of Contents .......................................................................................................................................... 3 Overview ....................................................................................................................................................... 6 Log Header .................................................................................................................................................... 7 Tool String Diagram ...................................................................................................................................... 8 Test Summary ............................................................................................................................................. 11 Plots ............................................................................................................................................................ 18 Test No. 1.1; MD: 5331.07 ft; TVD: 5330.17 ft........................................................................................ 18 Test No. 1.2; MD: 5331.07 ft; TVD: 5330.17 ft........................................................................................ 19 Test No. 1.3; MD: 5331.07 ft; TVD: 5330.17 ft........................................................................................ 20 Test No. 1.4; MD: 5331.07 ft; TVD: 5330.17 ft........................................................................................ 21 Test No. 2.1; MD: 5332.01 ft; TVD: 5331.12 ft........................................................................................ 22 Test No. 2.2; MD: 5332.01 ft; TVD: 5331.12 ft........................................................................................ 23 Test No. 2.3; MD: 5332.01 ft; TVD: 5331.12 ft........................................................................................ 24 Test No. 3.1; MD: 5332.06 ft; TVD: 5331.17 ft........................................................................................ 25 Test No. 3.2; MD: 5332.06 ft; TVD: 5331.17 ft........................................................................................ 26 Test No. 3.3; MD: 5332.06 ft; TVD: 5331.17 ft........................................................................................ 27 Test No. 4.1; MD: 5332.10 ft; TVD: 5331.20 ft........................................................................................ 28 Test No. 5.1; MD: 5332.90 ft; TVD: 5332.00 ft........................................................................................ 29 Test No. 5.2; MD: 5332.90 ft; TVD: 5332.00 ft........................................................................................ 30 Test No. 6.1; MD: 5353.04 ft; TVD: 5352.14 ft........................................................................................ 31 Test No. 6.2; MD: 5353.04 ft; TVD: 5352.14 ft........................................................................................ 32 Test No. 7.1; MD: 5357.03 ft; TVD: 5356.13 ft........................................................................................ 33 Test No. 7.2; MD: 5357.03 ft; TVD: 5356.13 ft........................................................................................ 34 Test No. 7.3; MD: 5357.03 ft; TVD: 5356.13 ft........................................................................................ 35 Test No. 7.4; MD: 5357.03 ft; TVD: 5356.13 ft........................................................................................ 36 Test No. 8.1; MD: 5361.02 ft; TVD: 5360.12 ft........................................................................................ 37 Test No. 8.2; MD: 5361.02 ft; TVD: 5360.12 ft........................................................................................ 38 Test No. 8.3; MD: 5361.02 ft; TVD: 5360.12 ft........................................................................................ 39 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 4 Test No. 9.1; MD: 5361.14 ft; TVD: 5360.24 ft........................................................................................ 40 Test No. 9.2; MD: 5361.14 ft; TVD: 5360.24 ft........................................................................................ 41 Test No. 9.3; MD: 5361.14 ft; TVD: 5360.24 ft........................................................................................ 42 Test No. 10.1; MD: 5379.46 ft; TVD: 5378.56 ft...................................................................................... 43 Test No. 10.2; MD: 5379.46 ft; TVD: 5378.56 ft...................................................................................... 44 Test No. 10.3; MD: 5379.46 ft; TVD: 5378.56 ft...................................................................................... 45 Test No. 11.1; MD: 5379.62 ft; TVD: 5378.72 ft...................................................................................... 46 Test No. 11.2; MD: 5379.62 ft; TVD: 5378.72 ft...................................................................................... 47 Test No. 11.3; MD: 5379.62 ft; TVD: 5378.72 ft...................................................................................... 48 Test No. 12.1; MD: 5388.03 ft; TVD: 5387.13 ft...................................................................................... 49 Test No. 12.2; MD: 5388.03 ft; TVD: 5387.13 ft...................................................................................... 50 Test No. 12.3; MD: 5388.03 ft; TVD: 5387.13 ft...................................................................................... 51 Test No. 13.1; MD: 5389.48 ft; TVD: 5388.58 ft...................................................................................... 52 Test No. 13.2; MD: 5389.48 ft; TVD: 5388.58 ft...................................................................................... 53 Test No. 13.3; MD: 5389.48 ft; TVD: 5388.58 ft...................................................................................... 54 Test No. 14.1; MD: 5395.07 ft; TVD: 5394.17 ft...................................................................................... 55 Test No. 14.2; MD: 5395.07 ft; TVD: 5394.17 ft...................................................................................... 56 Test No. 14.3; MD: 5395.07 ft; TVD: 5394.17 ft...................................................................................... 57 Test No. 15.1; MD: 5434.00 ft; TVD: 5433.10 ft...................................................................................... 58 Test No. 15.2; MD: 5434.00 ft; TVD: 5433.10 ft...................................................................................... 59 Test No. 15.3; MD: 5434.00 ft; TVD: 5433.10 ft...................................................................................... 60 Test No. 15.4; MD: 5434.00 ft; TVD: 5433.10 ft...................................................................................... 61 Test No. 16.1; MD: 5529.05 ft; TVD: 5528.14 ft...................................................................................... 62 Test No. 16.2; MD: 5529.05 ft; TVD: 5528.14 ft...................................................................................... 63 Test No. 16.3; MD: 5529.05 ft; TVD: 5528.14 ft...................................................................................... 64 Test No. 17.1; MD: 5541.50 ft; TVD: 5540.59 ft...................................................................................... 65 Test No. 17.2; MD: 5541.50 ft; TVD: 5540.59 ft...................................................................................... 66 Test No. 17.3; MD: 5541.50 ft; TVD: 5540.59 ft...................................................................................... 67 Test No. 18.1; MD: 5596.02 ft; TVD: 5595.10 ft...................................................................................... 68 Test No. 19.1; MD: 5596.27 ft; TVD: 5595.36 ft...................................................................................... 69 Test No. 20.1; MD: 5620.02 ft; TVD: 5619.11 ft...................................................................................... 70 Test No. 20.2; MD: 5620.02 ft; TVD: 5619.11 ft...................................................................................... 71 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 5 Test No. 20.3; MD: 5620.02 ft; TVD: 5619.11 ft...................................................................................... 72 Test No. 21.1; MD: 5656.02 ft; TVD: 5655.10 ft...................................................................................... 73 Test No. 22.1; MD: 5706.06 ft; TVD: 5705.14 ft...................................................................................... 74 Test No. 23.1; MD: 5851.18 ft; TVD: 5850.25 ft...................................................................................... 75 Test No. 23.2; MD: 5851.18 ft; TVD: 5850.25 ft...................................................................................... 76 Test No. 24.1; MD: 5854.17 ft; TVD: 5853.25 ft...................................................................................... 77 Test No. 24.2; MD: 5854.17 ft; TVD: 5853.25 ft...................................................................................... 78 Test No. 25.1; MD: 5890.48 ft; TVD: 5889.55 ft...................................................................................... 79 Test No. 25.2; MD: 5890.48 ft; TVD: 5889.55 ft...................................................................................... 80 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 6 Overview At the request of CONOCO PHILLIPS ALASKA, INC., the RDT tool was run in the CASSIN 6 well, NPR-A field, USA in an 8.5 inch hole for formation pressures and establishe gradients in various formations. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 7 Log Header Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 8 Tool String Diagram Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 9 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 10 Test Summary PRESSURE TEST SUMMARY Test Identification Hydrostatic Pres. Eq. Mud Wt. Test Pressures - Temperatures Test Times Remarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) 1.1 1-2.1 5331.07 5330.17 2766.84 2766.46 8.71 9.98 2733.91 2017.11 2414.93 351.53 119.40 2.25 144.48 Fair Buildup Stability 1.2 1-2.2 5331.07 5330.17 2766.84 2766.46 8.67 9.98 2473.86 1982.79 2402.09 364.37 119.40 2.00 274.96 Fair Buildup Stability 1.3 1-2.3 5331.07 5330.17 2766.84 2766.46 8.64 9.98 2461.26 523.60 2393.40 373.06 119.40 4.00 460.93 Fair Buildup Stability 1.4 1-2.4 5331.07 5330.17 2766.84 2766.46 8.63 9.98 2436.05 508.77 2392.19 374.27 119.50 3.25 717.64 Fair Buildup Stability 2.1 1-4.1 5332.01 5331.12 2765.97 2765.69 8.60 9.98 3232.13 990.32 2383.64 382.05 120.50 10.00 615.43 Fair Buildup Stability 2.2 1-4.2 5332.01 5331.12 2765.97 2765.69 8.58 9.98 2411.52 842.40 2379.15 386.54 120.20 10.25 894.14 Fair Buildup Stability 2.3 1-4.3 5332.01 5331.12 2765.97 2765.69 8.58 9.98 2403.07 1025.14 2379.35 386.34 120.70 6.25 1046.37 Fair Buildup Stability 3.1 1-3.1 5332.06 5331.17 2767.03 2766.93 8.59 9.98 3134.07 692.45 2382.29 384.64 119.90 10.00 273.20 Fair Buildup Stability 3.2 1-3.2 5332.06 5331.17 2767.03 2766.93 8.59 9.98 2394.48 535.87 2380.59 386.34 119.90 10.00 581.89 Fair Buildup Stability 3.3 1-3.3 5332.06 5331.17 2767.03 2766.93 8.59 9.98 2387.17 600.58 2380.24 386.69 119.90 10.00 862.34 Fair Buildup Stability 4.1 1-25.1 5332.10 5331.20 2766.09 2767.66 8.51 9.98 3083.99 1746.49 2359.68 407.99 130.30 9.75 73.48 Fair Buildup Stability 5.1 1-26.1 5332.90 5332.00 2767.97 2767.67 8.34 9.98 3038.04 1673.11 2311.36 456.31 127.80 9.75 73.50 Fair Buildup Stability 5.2 1-26.2 5332.90 5332.00 2767.97 2767.67 8.34 9.98 3038.04 1673.11 2311.36 456.31 127.80 9.75 73.50 Fair Buildup Stability 6.1 1-5.1 5353.04 5352.14 2776.72 2776.49 8.55 9.98 3235.79 1289.29 2378.24 398.25 121.00 10.00 415.88 Fair Buildup Stability 6.2 1-5.2 5353.04 5352.14 2776.72 2776.49 8.54 9.98 2384.11 1857.06 2378.05 398.44 121.00 1.00 379.14 Fair Buildup Stability 7.1 1-6.1 5357.03 5356.13 2778.21 2778.67 8.58 9.98 3247.20 1871.05 2389.14 389.53 121.80 6.25 92.72 Good Buildup Stability 7.2 1-6.2 5357.03 5356.13 2778.21 2778.67 8.56 9.98 2385.32 1864.81 2385.43 393.24 121.90 1.00 107.72 Good Buildup Stability 7.3 1-6.3 5357.03 5356.13 2778.21 2778.67 8.56 9.98 2385.76 1359.53 2383.15 395.52 122.00 10.00 378.64 Fair Buildup Stability 7.4 1-6.4 5357.03 5356.13 2778.21 2778.67 8.56 9.98 2382.06 1410.55 2383.26 395.41 122.00 10.00 629.81 Fair Buildup Stability 8.1 1-7.1 5361.02 5360.12 2780.09 2780.81 8.55 9.98 3262.22 1859.40 2382.77 398.04 122.90 9.75 255.43 Good Buildup Stability 8.2 1-7.2 5361.02 5360.12 2780.09 2780.81 8.54 9.98 2380.78 1847.90 2381.55 399.26 123.00 20.24 474.61 Fair Buildup Stability 8.3 1-7.3 5361.02 5360.12 2780.09 2780.81 8.54 9.98 2381.51 2122.02 2380.67 400.14 122.90 39.74 407.13 Fair Buildup Stability 9.1 1-24.1 5361.14 5360.24 2780.81 2781.80 8.54 9.98 3106.97 1551.81 2381.01 400.79 128.80 9.75 357.74 Good Buildup Stability 9.2 1-24.2 5361.14 5360.24 2779.40 2781.81 8.42 9.98 2307.65 1401.67 2347.74 434.07 127.30 9.75 1409.20 Good Buildup Stability 9.3 1-24.3 5361.14 5360.24 2779.40 2781.81 8.42 9.98 2307.65 1401.67 2347.74 434.07 127.30 9.75 1409.20 Good Buildup Stability 10.1 1-23.1 5379.46 5378.56 2791.61 2790.76 8.53 9.98 3108.32 1864.59 2386.68 404.08 126.30 9.75 130.00 Good Buildup Stability 10.2 1-23.2 5379.46 5378.56 2790.99 2790.78 8.42 9.98 2340.18 1996.35 2354.09 436.68 126.50 10.00 823.98 Fair Buildup Stability 10.3 1-23.3 5379.46 5378.56 2790.99 2790.78 8.42 9.98 2340.18 1996.35 2354.09 436.68 126.50 10.00 823.98 Fair Buildup Stability 11.1 1-8.1 5379.62 5378.72 2791.00 2790.03 8.54 9.98 3250.52 1843.92 2387.42 402.61 122.40 9.75 69.24 Excellent Buildup Stability 11.2 1-8.2 5379.62 5378.72 2791.00 2790.03 8.53 9.98 2385.57 1928.25 2386.62 403.42 122.40 20.00 298.19 Good Buildup Stability 11.3 1-8.3 5379.62 5378.72 2791.00 2790.03 8.53 9.98 2387.04 1981.01 2386.37 403.66 122.40 20.25 452.41 Good Buildup Stability 12.1 1-10.1 5388.03 5387.13 2794.32 2794.48 8.55 9.98 3255.02 1361.79 2394.87 399.61 122.90 9.75 170.96 Good Buildup Stability 12.2 1-10.2 5388.03 5387.13 2794.32 2794.48 8.55 9.98 2395.82 1385.99 2394.02 400.46 123.10 19.99 394.90 Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 12 PRESSURE TEST SUMMARY Test Identification Hydrostatic Pres. Eq. Mud Wt. Test Pressures - Temperatures Test Times Remarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) 12.3 1-10.3 5388.03 5387.13 2794.32 2794.48 8.54 9.98 2375.82 1919.66 2393.55 400.93 123.30 39.74 439.64 Good Buildup Stability 13.1 1-9.1 5389.48 5388.58 2795.19 2795.20 8.55 9.98 3239.57 1357.17 2395.53 399.67 122.60 9.50 94.72 Good Buildup Stability 13.2 1-9.2 5389.48 5388.58 2795.19 2795.20 8.55 9.98 2392.57 1399.68 2394.49 400.71 122.60 10.00 185.44 Good Buildup Stability 13.3 1-9.3 5389.48 5388.58 2795.19 2795.20 8.55 9.98 2394.34 1915.07 2394.39 400.81 122.70 39.99 639.28 Good Buildup Stability 14.1 1-11.1 5395.07 5394.17 2798.23 2798.54 8.53 9.98 3297.01 1719.66 2393.00 405.54 123.20 9.75 120.21 Good Buildup Stability 14.2 1-11.2 5395.07 5394.17 2798.23 2798.54 8.53 9.98 2390.73 1772.91 2392.41 406.13 123.30 19.99 304.41 Good Buildup Stability 14.3 1-11.3 5395.07 5394.17 2798.23 2798.54 8.53 9.98 2393.70 2107.82 2392.17 406.37 123.40 40.24 305.66 Good Buildup Stability 15.1 1-12.1 5434.00 5433.10 2819.09 2818.26 8.58 9.98 3255.94 1051.44 2423.03 395.23 123.20 8.25 283.47 Good Buildup Stability 15.2 1-12.2 5434.00 5433.10 2819.09 2818.26 8.57 9.98 2425.58 1539.35 2422.28 395.98 123.20 10.25 424.46 Good Buildup Stability 15.3 1-12.3 5434.00 5433.10 2819.09 2818.26 8.57 9.98 2427.54 1550.12 2420.43 397.83 123.30 40.75 679.68 Fair Buildup Stability 15.4 1-12.4 5434.00 5433.10 2819.09 2818.26 8.56 9.98 2421.29 1584.02 2419.74 398.52 123.30 34.00 852.67 Fair Buildup Stability 16.1 1-13.1 5529.05 5528.14 2868.59 2866.94 8.73 9.97 3354.05 1088.12 2510.92 356.02 124.10 7.75 440.43 Good Buildup Stability 16.2 1-13.2 5529.05 5528.14 2868.59 2866.94 8.73 9.97 2522.71 1074.18 2510.20 356.74 124.20 1.75 649.90 Good Buildup Stability 16.3 1-13.3 5529.05 5528.14 2868.59 2866.94 8.73 9.97 2518.15 1030.89 2509.24 357.70 124.30 7.50 697.89 Good Buildup Stability 17.1 1-14.1 5541.50 5540.59 2873.70 2873.21 8.50 9.97 3312.27 1452.13 2449.77 423.44 124.80 10.25 308.70 Good Buildup Stability 17.2 1-14.2 5541.50 5540.59 2873.70 2873.21 8.50 9.97 2447.00 1476.52 2448.91 424.30 124.90 20.00 744.64 Good Buildup Stability 17.3 1-14.3 5541.50 5540.59 2873.70 2873.21 8.50 9.97 2450.37 1983.24 2448.38 424.83 125.00 40.24 722.14 Good Buildup Stability 18.1 1-16.1 5596.02 5595.10 2901.57 2901.55 9.70 9.97 2921.89 2045.60 2823.08 78.47 126.60 3.75 306.62 Low Perm, Still Building 19.1 1-15.1 5596.27 5595.36 2902.31 2901.63 9.61 9.97 2918.47 1055.40 2797.30 104.34 126.20 3.75 416.84 Low Perm, Still Building 20.1 1-17.1 5620.02 5619.11 2914.81 2913.71 9.42 9.97 3306.28 1569.92 2752.92 160.79 126.80 4.75 516.69 Fair Buildup Stability 20.2 1-17.2 5620.02 5619.11 2914.81 2913.71 9.36 9.97 2728.52 1413.77 2735.28 178.43 127.00 1.00 751.91 Fair Buildup Stability 20.3 1-17.3 5620.02 5619.11 2914.81 2913.71 9.34 9.97 2741.74 2016.88 2729.69 184.02 127.10 1.75 652.67 Fair Buildup Stability 21.1 1-18.1 5656.02 5655.10 2933.90 2932.20 9.57 9.97 3114.81 2041.76 2814.08 118.12 127.60 2.25 887.03 Fair Buildup Stability 22.1 1-19.1 5706.06 5705.14 2959.77 2958.01 9.48 9.97 3257.51 2077.47 2811.68 146.33 129.20 4.00 1071.29 Low Perm, Still Building 23.1 1-20.1 5851.18 5850.25 3033.67 3032.29 8.98 9.97 3163.32 1590.96 2732.34 299.95 132.90 4.00 687.59 Fair Buildup Stability 23.2 1-20.2 5851.18 5850.25 3033.67 3032.29 8.97 9.97 2735.47 2090.30 2729.66 302.63 132.90 1.25 802.57 Fair Buildup Stability 24.1 1-21.1 5854.17 5853.25 3033.90 3033.87 9.21 9.97 3407.44 1590.24 2801.89 231.98 133.10 6.50 204.71 Fair Buildup Stability 24.2 1-21.2 5854.17 5853.25 3033.90 3033.87 9.16 9.97 2804.85 528.11 2786.93 246.94 133.30 12.00 783.11 Fair Buildup Stability 25.1 1-22.1 5890.48 5889.55 3054.18 3052.64 9.65 9.97 2975.05 1059.54 2954.84 97.79 134.00 10.50 329.42 Tight Test, Still Building 25.2 1-22.2 5890.48 5889.55 3054.18 3052.64 9.68 9.97 2958.77 541.82 2965.81 86.83 134.20 6.75 707.08 Tight Test, Still Building Legend: Phyds1: Initial Hydrostatic Pressure Phyds2: Final Hydrostatic Pressure EqFmMw:Equivalent Formation Mud Weight (Pstop / (TVD * Constant)) Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 13 PRESSURE TEST SUMMARY Test Identification Hydrostatic Pres. Eq. Mud Wt. Test Pressures - Temperatures Test Times Remarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) EqBhMw: Equivalent Borehole Mud Weight (Phyds2 / (TVD * Constant)) Psdd: Initial Drawdown Pressure Pedd: Final Drawdown or End Drawdown Pressure Pstop: Final Buildup Pressure Temp: Final Temperature dTdd= Tedd-Tsdd: Tedd - End of Drawdown Time; Tsdd - Initial Drawdown Time dTbu=Tstop - Tedd:Buildup Time, Tedd - End of Drawdown Time, Tstop - Final Buildup Time dPob= Phyds2 - Pstop: Over Balance Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 14 PRESSURE TRANSIENT SUMMARY Test Identification Buildup Stability PTA Pressure PTA Mobilities Remarks Test No. File No. MD (ft) TVD (ft) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 1.1 1-2.1 5331.07 5330.17 -0.184 2414.93 4.83 1.09 7.14 Fair Buildup Stability 1.2 1-2.2 5331.07 5330.17 0.312 2402.10 6.34 0.217 2.60 Fair Buildup Stability 1.3 1-2.3 5331.07 5330.17 0.481 2393.40 15.75 0.158 0.846 Fair Buildup Stability 1.4 1-2.4 5331.07 5330.17 0.205 2392.19 6.33 0.124 0.784 Fair Buildup Stability 2.1 1-4.1 5332.01 5331.12 0.525 2383.64 6.37 0.681 0.854 Fair Buildup Stability 2.2 1-4.2 5332.01 5331.12 0.440 2379.15 10.14 0.404 0.757 Fair Buildup Stability 2.3 1-4.3 5332.01 5331.12 0.503 2379.35 6.48 0.364 0.851 Fair Buildup Stability 3.1 1-3.1 5332.06 5331.17 0.188 2382.29 3.19 2.04 2.19 Fair Buildup Stability 3.2 1-3.2 5332.06 5331.17 0.282 2380.59 3.64 1.79 1.95 Fair Buildup Stability 3.3 1-3.3 5332.06 5331.17 0.307 2380.24 2.89 1.85 2.02 Fair Buildup Stability 4.1 1-25.1 5332.10 5331.20 14.693 2359.68 14.94 1.82 1.91 Fair Buildup Stability 5.1 1-26.1 5332.90 5332.00 15.404 2311.36 14.56 1.82 1.88 Fair Buildup Stability 5.2 1-26.2 5332.90 5332.00 15.404 2311.36 14.56 1.82 1.88 Fair Buildup Stability 6.1 1-5.1 5353.04 5352.14 0.074 2378.24 1.12 1.08 1.09 Fair Buildup Stability 6.2 1-5.2 5353.04 5352.14 0.025 2378.05 1.03 0.497 0.867 Fair Buildup Stability 7.1 1-6.1 5357.03 5356.13 1.361 2389.14 0.91 2.24 2.25 Good Buildup Stability 7.2 1-6.2 5357.03 5356.13 0.650 0.049 2385.43 0.92 0.708 1.18 Good Buildup Stability 7.3 1-6.3 5357.03 5356.13 0.478 2383.15 3.51 1.14 1.15 Fair Buildup Stability 7.4 1-6.4 5357.03 5356.13 0.203 2383.26 2.62 1.20 1.20 Fair Buildup Stability 8.1 1-7.1 5361.02 5360.12 0.077 2382.77 0.41 2.27 2.27 Good Buildup Stability 8.2 1-7.2 5361.02 5360.12 0.139 2381.56 1.48 2.25 2.25 Fair Buildup Stability 8.3 1-7.3 5361.02 5360.12 0.220 2380.67 1.68 2.36 2.36 Fair Buildup Stability 9.1 1-24.1 5361.14 5360.24 0.078 2381.01 0.47 1.41 1.41 Good Buildup Stability 9.2 1-24.2 5361.14 5360.24 0.642 2347.74 11.12 1.11 1.24 Good Buildup Stability 9.3 1-24.3 5361.14 5360.24 0.642 2347.74 11.12 1.11 1.24 Good Buildup Stability 10.1 1-23.1 5379.46 5378.56 0.052 2386.67 0.12 2.24 2.24 Good Buildup Stability 10.2 1-23.2 5379.46 5378.56 0.574 2354.09 4.74 3.23 3.23 Fair Buildup Stability 10.3 1-23.3 5379.46 5378.56 0.574 2354.09 4.74 3.23 3.23 Fair Buildup Stability 11.1 1-8.1 5379.62 5378.72 0.064 2387.42 0.10 2.16 2.16 Excellent Buildup Stability 11.2 1-8.2 5379.62 5378.72 0.068 2386.62 0.46 2.61 2.61 Good Buildup Stability 11.3 1-8.3 5379.62 5378.72 0.056 2386.37 0.38 2.96 2.96 Good Buildup Stability 12.1 1-10.1 5388.03 5387.13 0.037 2394.87 0.20 1.14 1.15 Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 15 PRESSURE TRANSIENT SUMMARY Test Identification Buildup Stability PTA Pressure PTA Mobilities Remarks Test No. File No. MD (ft) TVD (ft) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 12.2 1-10.2 5388.03 5387.13 0.137 2394.02 1.03 1.19 1.19 Fair Buildup Stability 12.3 1-10.3 5388.03 5387.13 0.097 2393.55 0.90 1.29 1.29 Good Buildup Stability 13.1 1-9.1 5389.48 5388.58 -0.080 0.113 2395.53 0.24 1.17 1.17 Good Buildup Stability 13.2 1-9.2 5389.48 5388.58 0.243 2394.49 0.93 1.18 1.18 Good Buildup Stability 13.3 1-9.3 5389.48 5388.58 0.045 2394.39 0.59 1.27 1.27 Good Buildup Stability 14.1 1-11.1 5395.07 5394.17 -0.013 2393.01 0.14 1.80 1.80 Good Buildup Stability 14.2 1-11.2 5395.07 5394.17 0.061 2392.41 0.56 1.93 1.93 Good Buildup Stability 14.3 1-11.3 5395.07 5394.17 0.095 2392.17 0.54 2.15 2.15 Good Buildup Stability 15.1 1-12.1 5434.00 5433.10 -0.128 2423.03 0.18 0.822 0.831 Good Buildup Stability 15.2 1-12.2 5434.00 5433.10 0.078 2422.28 0.76 0.655 0.660 Good Buildup Stability 15.3 1-12.3 5434.00 5433.10 0.126 2420.43 1.76 0.691 0.691 Fair Buildup Stability 15.4 1-12.4 5434.00 5433.10 0.078 2419.74 1.43 0.724 0.724 Fair Buildup Stability 16.1 1-13.1 5529.05 5528.14 0.036 2510.92 0.50 0.734 0.837 Good Buildup Stability 16.2 1-13.2 5529.05 5528.14 -0.055 2510.20 0.36 0.266 0.676 Good Buildup Stability 16.3 1-13.3 5529.05 5528.14 0.044 2509.24 0.84 0.318 0.381 Good Buildup Stability 17.1 1-14.1 5541.50 5540.59 0.044 2449.77 0.32 1.17 1.17 Good Buildup Stability 17.2 1-14.2 5541.50 5540.59 0.050 2448.91 0.85 1.23 1.23 Good Buildup Stability 17.3 1-14.3 5541.50 5540.59 0.057 2448.38 0.93 1.31 1.31 Good Buildup Stability 18.1 1-16.1 5596.02 5595.10 9.913 2823.64 18.89 0.057 0.678 Low Perm, Still Building 19.1 1-15.1 5596.27 5595.36 12.321 2797.62 45.22 0.043 0.578 Low Perm, Still Building 20.1 1-17.1 5620.02 5619.11 0.220 2752.92 8.96 0.195 0.904 Fair Buildup Stability 20.2 1-17.2 5620.02 5619.11 -0.024 2735.28 11.14 0.025 0.774 Fair Buildup Stability 20.3 1-17.3 5620.02 5619.11 0.013 2729.69 6.87 0.034 0.514 Fair Buildup Stability 21.1 1-18.1 5656.02 5655.10 -1.501 2814.08 6.94 0.067 1.13 Fair Buildup Stability 22.1 1-19.1 5706.06 5705.14 -0.405 2811.68 20.19 0.071 1.40 Low Perm, Still Building 23.1 1-20.1 5851.18 5850.25 0.054 2732.34 6.74 0.310 0.932 Fair Buildup Stability 23.2 1-20.2 5851.18 5850.25 0.009 2729.66 2.22 0.096 0.938 Fair Buildup Stability 24.1 1-21.1 5854.17 5853.25 3.959 2801.89 22.02 0.480 0.946 Fair Buildup Stability 24.2 1-21.2 5854.17 5853.25 0.764 2786.93 22.33 0.111 0.261 Fair Buildup Stability 25.1 1-22.1 5890.48 5889.55 12.979 2954.92 53.47 0.168 0.608 Tight Test, Still Building 25.2 1-22.2 5890.48 5889.55 5.367 2965.84 60.54 0.025 0.236 Tight Test, Still Building Legend: Pexact: Projected formation pressure based on exact model. Pstdev: Standard deviation of actual pressures from exact model Mexact: Spherical Mobility based on exact model Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 16 PRESSURE TRANSIENT SUMMARY Test Identification Buildup Stability PTA Pressure PTA Mobilities Remarks Test No. File No. MD (ft) TVD (ft) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) Msdd: Spherical Drawdown Mobility Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 17 SAMPLE SUMMARY Sample Identification Conditions Fluid Properties* Pumpout - Anisotropy** Remarks Sample Test File No. MD (ft) Event Ts (sec) Ps (psia) Pop (psia) Vs (cc) Temp (degF) Density (sg)* B.P. (psia) Com. (1/psia) Mposph (md/cp) Mpoh (md/cp) ANISO (Kv/Kh) 10.1 1-23.1 5379.46 OpenSc 12573.75 1861.79 2795.82 126.50 1.02 10.1 1-23.1 5379.46 CloseSc 13049.00 2320.12 9367.82 885.13 126.50 1.04 Legend: Ts: Time Sample Taken Ps: Pressure of Sample B.P.:Bubble Point Pressure Temp: Pretest Temperature Com.: Compressibility Density: Density Pop: Over Pressure Vs: Sample Volume Mposph: Pump out Spherical Mobility Mpoh: Pump out Horizontal Mobility ANISO: Anisotropy, Kv/Kh Options: *: Fluid density available with advanced fluid properties tool option **: Permeability - Mposph, Mpoh is available with pump-out and advanced fluid properties option Plots Test No. 1.1; MD: 5331.07 ft; TVD: 5330.17 ft RDT Test File # 1-2.1 Date: 15-Apr-13 02:23:44 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5331.07 5330.17 2017.11 2414.93 2414.93 1.09 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.66 0.74 0.33 0.25 9.40e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 4.83 -0.18 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 19 Test No. 1.2; MD: 5331.07 ft; TVD: 5330.17 ft RDT Test File # 1-2.2 Date: 15-Apr-13 02:23:44 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5331.07 5330.17 1982.79 2402.09 2402.10 0.217 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 0.57 0.28 0.33 0.25 3.30e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 6.34 0.31 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 20 Test No. 1.3; MD: 5331.07 ft; TVD: 5330.17 ft RDT Test File # 1-2.3 Date: 15-Apr-13 02:23:44 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5331.07 5330.17 523.60 2393.40 2393.40 0.158 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 3.29 0.82 0.66 0.25 4.72e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 15.75 0.48 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 21 Test No. 1.4; MD: 5331.07 ft; TVD: 5330.17 ft RDT Test File # 1-2.4 Date: 15-Apr-13 02:23:44 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5331.07 5330.17 508.77 2392.19 2392.19 0.124 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.50 0.77 0.66 0.25 4.21e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 6.33 0.21 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 22 Test No. 2.1; MD: 5332.01 ft; TVD: 5331.12 ft RDT Test File # 1-4.1 Date: 15-Apr-13 03:39:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.01 5331.12 990.32 2383.64 2383.64 0.681 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.24 1.92 2.04 0.15 1.49e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 6.37 0.52 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 23 Test No. 2.2; MD: 5332.01 ft; TVD: 5331.12 ft RDT Test File # 1-4.2 Date: 15-Apr-13 03:39:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.01 5331.12 842.40 2379.15 2379.15 0.402 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.31 1.88 2.04 0.15 1.02e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 10.14 0.44 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 24 Test No. 2.3; MD: 5332.01 ft; TVD: 5331.12 ft RDT Test File # 1-4.3 Date: 15-Apr-13 03:39:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.01 5331.12 1025.14 2379.35 2379.35 0.364 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 11.65 1.86 2.04 0.15 1.45e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 6.48 0.50 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 25 Test No. 3.1; MD: 5332.06 ft; TVD: 5331.17 ft RDT Test File # 1-3.1 Date: 15-Apr-13 02:58:07 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.06 5331.17 692.45 2382.29 2382.29 2.04 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.63 0.96 0.33 0.25 1.25e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 3.19 0.19 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 26 Test No. 3.2; MD: 5332.06 ft; TVD: 5331.17 ft RDT Test File # 1-3.2 Date: 15-Apr-13 02:58:07 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.06 5331.17 535.87 2380.59 2380.59 1.79 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.35 0.94 0.33 0.25 7.82e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 3.64 0.28 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 27 Test No. 3.3; MD: 5332.06 ft; TVD: 5331.17 ft RDT Test File # 1-3.3 Date: 15-Apr-13 02:58:07 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.06 5331.17 600.58 2380.24 2380.24 1.85 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.36 0.94 0.33 0.25 7.84e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 2.89 0.31 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 28 Test No. 4.1; MD: 5332.10 ft; TVD: 5331.20 ft RDT Test File # 1-25.1 Date: 15-Apr-13 20:31:32 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.10 5331.20 1746.49 2359.68 2359.68 1.82 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.42 1.89 2.04 0.15 2.55e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 14.94 14.69 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 29 Test No. 5.1; MD: 5332.90 ft; TVD: 5332.00 ft RDT Test File # 1-26.1 Date: 15-Apr-13 20:48:44 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.90 5332.00 1673.11 2311.36 2311.36 1.82 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.89 1.94 2.04 0.15 2.36e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 14.56 15.40 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 30 Test No. 5.2; MD: 5332.90 ft; TVD: 5332.00 ft RDT Test File # 1-26.2 Date: 15-Apr-13 20:48:44 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5332.90 5332.00 1673.11 2311.36 2311.36 1.82 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.89 1.94 2.04 0.15 2.36e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 14.56 15.40 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 31 Test No. 6.1; MD: 5353.04 ft; TVD: 5352.14 ft RDT Test File # 1-5.1 Date: 15-Apr-13 04:34:06 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5353.04 5352.14 1289.29 2378.24 2378.24 1.08 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.15 1.92 2.04 0.15 2.34e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 1.12 0.07 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 32 Test No. 6.2; MD: 5353.04 ft; TVD: 5352.14 ft RDT Test File # 1-5.2 Date: 15-Apr-13 04:34:06 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5353.04 5352.14 1857.06 2378.05 2378.05 0.497 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 0.73 0.73 2.04 0.15 4.82e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 1.03 0.03 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 33 Test No. 7.1; MD: 5357.03 ft; TVD: 5356.13 ft RDT Test File # 1-6.1 Date: 15-Apr-13 05:01:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5357.03 5356.13 1871.05 2389.14 2389.14 2.24 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 11.78 1.88 2.04 0.15 2.26e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.91 1.36 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 34 Test No. 7.2; MD: 5357.03 ft; TVD: 5356.13 ft RDT Test File # 1-6.2 Date: 15-Apr-13 05:01:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5357.03 5356.13 1864.81 2385.43 2385.43 0.708 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 0.99 0.99 2.04 0.15 6.93e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.92 0.65 0.05 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 35 Test No. 7.3; MD: 5357.03 ft; TVD: 5356.13 ft RDT Test File # 1-6.3 Date: 15-Apr-13 05:01:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5357.03 5356.13 1359.53 2383.15 2383.15 1.14 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.99 1.90 2.04 0.15 1.21e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 3.51 0.48 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 36 Test No. 7.4; MD: 5357.03 ft; TVD: 5356.13 ft RDT Test File # 1-6.4 Date: 15-Apr-13 05:01:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5357.03 5356.13 1410.55 2383.26 2383.26 1.20 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.94 1.89 2.04 0.15 1.28e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 2.62 0.20 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 37 Test No. 8.1; MD: 5361.02 ft; TVD: 5360.12 ft RDT Test File # 1-7.1 Date: 15-Apr-13 05:30:23 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5361.02 5360.12 1859.40 2382.77 2382.77 2.27 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.72 1.92 2.04 0.15 2.51e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.41 0.08 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 38 Test No. 8.2; MD: 5361.02 ft; TVD: 5360.12 ft RDT Test File # 1-7.2 Date: 15-Apr-13 05:30:23 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5361.02 5360.12 1847.90 2381.56 2381.56 2.25 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.33 1.94 2.04 0.15 1.84e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 1.48 0.14 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 39 Test No. 8.3; MD: 5361.02 ft; TVD: 5360.12 ft RDT Test File # 1-7.3 Date: 15-Apr-13 05:30:23 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5361.02 5360.12 2122.02 2380.67 2380.67 2.36 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.18 0.99 2.04 0.15 2.52e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 1.68 0.22 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 40 Test No. 9.1; MD: 5361.14 ft; TVD: 5360.24 ft RDT Test File # 1-24.1 Date: 15-Apr-13 17:33:38 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5361.14 5360.24 1551.81 2381.01 2381.01 1.41 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.42 1.89 2.04 0.15 2.27e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.47 0.08 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 41 Test No. 9.2; MD: 5361.14 ft; TVD: 5360.24 ft RDT Test File # 1-24.2 Date: 15-Apr-13 17:33:38 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5361.14 5360.24 1401.67 2347.74 2347.74 1.11 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.44 1.89 2.04 0.15 1.29e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 11.12 0.64 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 42 Test No. 9.3; MD: 5361.14 ft; TVD: 5360.24 ft RDT Test File # 1-24.3 Date: 15-Apr-13 17:33:38 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5361.14 5360.24 1401.67 2347.74 2347.74 1.11 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.44 1.89 2.04 0.15 1.29e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 11.12 0.64 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 43 Test No. 10.1; MD: 5379.46 ft; TVD: 5378.56 ft RDT Test File # 1-23.1 Date: 15-Apr-13 13:33:05 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5379.46 5378.56 1864.59 2386.67 2386.67 2.24 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.44 1.89 2.04 0.15 2.81e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.12 0.05 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 44 Test No. 10.2; MD: 5379.46 ft; TVD: 5378.56 ft RDT Test File # 1-23.2 Date: 15-Apr-13 13:33:05 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5379.46 5378.56 1996.35 2354.09 2354.09 3.23 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.66 1.87 2.04 0.15 1.81e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 4.74 0.57 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 45 Test No. 10.3; MD: 5379.46 ft; TVD: 5378.56 ft RDT Test File # 1-23.3 Date: 15-Apr-13 13:33:05 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5379.46 5378.56 1996.35 2354.09 2354.09 3.23 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.66 1.87 2.04 0.15 1.81e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 4.74 0.57 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 46 Test No. 11.1; MD: 5379.62 ft; TVD: 5378.72 ft RDT Test File # 1-8.1 Date: 15-Apr-13 05:58:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5379.62 5378.72 1843.92 2387.42 2387.42 2.16 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.53 1.90 2.04 0.15 2.48e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.10 0.06 0.00 REMARKS Excellent Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 47 Test No. 11.2; MD: 5379.62 ft; TVD: 5378.72 ft RDT Test File # 1-8.2 Date: 15-Apr-13 05:58:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5379.62 5378.72 1928.25 2386.62 2386.62 2.61 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 38.71 1.94 2.04 0.15 1.77e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.46 0.07 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 48 Test No. 11.3; MD: 5379.62 ft; TVD: 5378.72 ft RDT Test File # 1-8.3 Date: 15-Apr-13 05:58:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5379.62 5378.72 1981.01 2386.37 2386.37 2.96 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.24 1.94 2.04 0.15 1.54e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.38 0.06 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 49 Test No. 12.1; MD: 5388.03 ft; TVD: 5387.13 ft RDT Test File # 1-10.1 Date: 15-Apr-13 06:43:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5388.03 5387.13 1361.79 2394.87 2394.87 1.14 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.65 1.91 2.04 0.15 1.97e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.20 0.04 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 50 Test No. 12.2; MD: 5388.03 ft; TVD: 5387.13 ft RDT Test File # 1-10.2 Date: 15-Apr-13 06:43:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5388.03 5387.13 1385.99 2394.02 2394.02 1.19 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 38.71 1.94 2.04 0.15 1.15e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 1.03 0.14 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 51 Test No. 12.3; MD: 5388.03 ft; TVD: 5387.13 ft RDT Test File # 1-10.3 Date: 15-Apr-13 06:43:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5388.03 5387.13 1919.66 2393.55 2393.55 1.29 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.26 0.99 2.04 0.15 1.67e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.90 0.10 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 52 Test No. 13.1; MD: 5389.48 ft; TVD: 5388.58 ft RDT Test File # 1-9.1 Date: 15-Apr-13 06:19:19 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5389.48 5388.58 1357.17 2395.53 2395.53 1.17 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.63 1.96 2.04 0.15 2.10e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.24 -0.08 0.11 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 53 Test No. 13.2; MD: 5389.48 ft; TVD: 5388.58 ft RDT Test File # 1-9.2 Date: 15-Apr-13 06:19:19 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5389.48 5388.58 1399.68 2394.49 2394.49 1.18 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.01 1.90 2.04 0.15 1.39e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.93 0.24 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 54 Test No. 13.3; MD: 5389.48 ft; TVD: 5388.58 ft RDT Test File # 1-9.3 Date: 15-Apr-13 06:19:19 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5389.48 5388.58 1915.07 2394.39 2394.39 1.27 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.47 0.99 2.04 0.15 1.34e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.59 0.05 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 55 Test No. 14.1; MD: 5395.07 ft; TVD: 5394.17 ft RDT Test File # 1-11.1 Date: 15-Apr-13 07:08:20 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5395.07 5394.17 1719.66 2393.01 2393.01 1.80 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.06 1.96 2.04 0.15 2.02e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.14 -0.01 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 56 Test No. 14.2; MD: 5395.07 ft; TVD: 5394.17 ft RDT Test File # 1-11.2 Date: 15-Apr-13 07:08:20 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5395.07 5394.17 1772.91 2392.41 2392.41 1.93 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 38.57 1.93 2.04 0.15 1.64e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.56 0.06 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 57 Test No. 14.3; MD: 5395.07 ft; TVD: 5394.17 ft RDT Test File # 1-11.3 Date: 15-Apr-13 07:08:20 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5395.07 5394.17 2107.82 2392.17 2392.17 2.15 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.76 0.99 2.04 0.15 1.74e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.54 0.09 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 58 Test No. 15.1; MD: 5434.00 ft; TVD: 5433.10 ft RDT Test File # 1-12.1 Date: 15-Apr-13 07:29:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5434.00 5433.10 1051.44 2423.03 2423.03 0.822 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 15.21 1.84 2.04 0.15 1.47e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.18 -0.13 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 59 Test No. 15.2; MD: 5434.00 ft; TVD: 5433.10 ft RDT Test File # 1-12.2 Date: 15-Apr-13 07:29:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5434.00 5433.10 1539.35 2422.28 2422.28 0.655 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.66 0.94 2.04 0.15 1.16e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.76 0.08 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 60 Test No. 15.3; MD: 5434.00 ft; TVD: 5433.10 ft RDT Test File # 1-12.3 Date: 15-Apr-13 07:29:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5434.00 5433.10 1550.12 2420.43 2420.43 0.691 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.65 0.97 2.04 0.15 1.13e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 1.76 0.13 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 61 Test No. 15.4; MD: 5434.00 ft; TVD: 5433.10 ft RDT Test File # 1-12.4 Date: 15-Apr-13 07:29:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5434.00 5433.10 1584.02 2419.74 2419.74 0.724 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 33.25 0.98 2.04 0.15 1.15e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 1.43 0.08 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 62 Test No. 16.1; MD: 5529.05 ft; TVD: 5528.14 ft RDT Test File # 1-13.1 Date: 15-Apr-13 08:19:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5529.05 5528.14 1088.12 2510.92 2510.92 0.734 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 14.92 1.92 2.04 0.15 1.55e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.50 0.04 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 63 Test No. 16.2; MD: 5529.05 ft; TVD: 5528.14 ft RDT Test File # 1-13.2 Date: 15-Apr-13 08:19:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5529.05 5528.14 1074.18 2510.20 2510.20 0.266 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.75 1.57 2.04 0.15 7.15e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.36 -0.06 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 64 Test No. 16.3; MD: 5529.05 ft; TVD: 5528.14 ft RDT Test File # 1-13.3 Date: 15-Apr-13 08:19:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5529.05 5528.14 1030.89 2509.24 2509.24 0.318 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 6.82 0.91 2.04 0.15 8.57e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.84 0.04 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 65 Test No. 17.1; MD: 5541.50 ft; TVD: 5540.59 ft RDT Test File # 1-14.1 Date: 15-Apr-13 08:59:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5541.50 5540.59 1452.13 2449.77 2449.77 1.17 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.37 1.89 2.04 0.15 2.72e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.32 0.04 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 66 Test No. 17.2; MD: 5541.50 ft; TVD: 5540.59 ft RDT Test File # 1-14.2 Date: 15-Apr-13 08:59:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5541.50 5540.59 1476.52 2448.91 2448.91 1.23 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 38.67 1.93 2.04 0.15 1.56e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.85 0.05 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 67 Test No. 17.3; MD: 5541.50 ft; TVD: 5540.59 ft RDT Test File # 1-14.3 Date: 15-Apr-13 08:59:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5541.50 5540.59 1983.24 2448.38 2448.38 1.31 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 39.60 0.98 2.04 0.15 1.12e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 0.93 0.06 0.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 68 Test No. 18.1; MD: 5596.02 ft; TVD: 5595.10 ft RDT Test File # 1-16.1 Date: 15-Apr-13 09:56:31 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5596.02 5595.10 2045.60 2823.08 2823.64 0.057 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 3.19 0.85 2.04 0.15 1.17e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 18.89 9.91 0.00 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 69 Test No. 19.1; MD: 5596.27 ft; TVD: 5595.36 ft RDT Test File # 1-15.1 Date: 15-Apr-13 09:40:48 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5596.27 5595.36 1055.40 2797.30 2797.62 0.043 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 6.10 1.63 2.04 0.15 1.12e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 45.22 12.32 0.00 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 70 Test No. 20.1; MD: 5620.02 ft; TVD: 5619.11 ft RDT Test File # 1-17.1 Date: 15-Apr-13 10:09:33 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5620.02 5619.11 1569.92 2752.92 2752.92 0.195 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 8.22 1.73 2.04 0.15 1.26e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 8.96 0.22 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 71 Test No. 20.2; MD: 5620.02 ft; TVD: 5619.11 ft RDT Test File # 1-17.2 Date: 15-Apr-13 10:09:33 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5620.02 5619.11 1413.77 2735.28 2735.28 0.025 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.65 1.65 2.04 0.15 2.43e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 11.14 -0.02 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 72 Test No. 20.3; MD: 5620.02 ft; TVD: 5619.11 ft RDT Test File # 1-17.3 Date: 15-Apr-13 10:09:33 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5620.02 5619.11 2016.88 2729.69 2729.69 0.034 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.04 0.59 2.04 0.15 4.19e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 6.87 0.01 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 73 Test No. 21.1; MD: 5656.02 ft; TVD: 5655.10 ft RDT Test File # 1-18.1 Date: 15-Apr-13 10:53:49 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5656.02 5655.10 2041.76 2814.08 2814.08 0.067 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 3.17 1.41 2.04 0.15 1.26e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 6.94 -1.50 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 74 Test No. 22.1; MD: 5706.06 ft; TVD: 5705.14 ft RDT Test File # 1-19.1 Date: 15-Apr-13 11:20:34 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5706.06 5705.14 2077.47 2811.68 2811.68 0.071 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 6.66 1.67 2.04 0.15 1.63e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 20.19 -0.41 0.00 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 75 Test No. 23.1; MD: 5851.18 ft; TVD: 5850.25 ft RDT Test File # 1-20.1 Date: 15-Apr-13 11:57:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5851.18 5850.25 1590.96 2732.34 2732.34 0.310 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 6.88 1.72 2.04 0.15 1.71e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 6.74 0.05 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 76 Test No. 23.2; MD: 5851.18 ft; TVD: 5850.25 ft RDT Test File # 1-20.2 Date: 15-Apr-13 11:57:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5851.18 5850.25 2090.30 2729.66 2729.66 0.096 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.21 0.97 2.04 0.15 5.68e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 2.22 0.01 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 77 Test No. 24.1; MD: 5854.17 ft; TVD: 5853.25 ft RDT Test File # 1-21.1 Date: 15-Apr-13 12:29:30 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5854.17 5853.25 1590.24 2801.89 2801.89 0.480 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 12.05 1.85 2.04 0.15 1.80e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 22.02 3.96 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 78 Test No. 24.2; MD: 5854.17 ft; TVD: 5853.25 ft RDT Test File # 1-21.2 Date: 15-Apr-13 12:29:30 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5854.17 5853.25 528.11 2786.93 2786.93 0.111 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 11.45 0.95 2.04 0.15 8.31e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 22.33 0.76 0.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 79 Test No. 25.1; MD: 5890.48 ft; TVD: 5889.55 ft RDT Test File # 1-22.1 Date: 15-Apr-13 12:54:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5890.48 5889.55 1059.54 2954.85 2954.92 0.168 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.57 1.86 2.04 0.15 2.18e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 53.47 12.98 0.00 REMARKS Tight Test, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 21 April 2013 Confidential Page 80 Test No. 25.2; MD: 5890.48 ft; TVD: 5889.55 ft RDT Test File # 1-22.2 Date: 15-Apr-13 12:54:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5890.48 5889.55 541.82 2965.81 2965.84 0.025 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 6.26 0.93 2.04 0.15 9.04e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face (deg). 60.54 5.37 0.00 REMARKS Tight Test, Still Building