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214-198
TT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Exploration - Image logs Backlog DATE: 03/02/2024 Transmitted: North Slope, Exploration – Moraine 1 Via hard drive data drop 1 of 1 Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 214-198 T38546 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 08:45:34 -09'00' TTT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Moraine 1 DATE: 07/26/2022 Transmitted: Kuparuk River Unit Via SFTP ____ Moraine 1 RDT sample and water sample test data Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: Moraine 1 e-transmittal well folder Receipt: Date: Alaska Data Support |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 PTD:214-198 T36827 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.26 10:26:27 -08'00' ✓ ccCo 30 ConocoPhillips TRANSMITTAL RECEIVED FROM: Sandra D. Lemke, ATO3-0346 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC JAN 2 7 2016 P.O. Box 100360 333 W. 7`h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 AOGCC RE: Moraine 1 DATE: 01/28/2016 Transmitted: Kuparuk River Unit, Alaska Moraine 1 Via email- MAY 2 5 201 Routine core analysis reports CI ConocoPhillips Alaska Moraine 1 HH-75558 Core Data,xlsx(94 KB) 0113 ConocoPhillips Alaska Moraine 1 HH-75558 Karl Fischer Set Data,xlsx(107 KB) ConocoPhillips_Moraine 1_HH-75558_Karl Fischer Sw.xlsx(29 KB) Please promptly sign, scan and return electronically to Sandra.D.LemkeCa�Conocophi//ips.com CC: Moraine 1 transmittal folder, production well files, eSearch Approved for transmittal: Renee Hannon, 01/27/2016 via email Receipt:_ • Date: Sit �✓ r)%,,. GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 • 111 y 0 o I • o oJ . o W w o Z co C •- ,- ,- ,- ,- LL • • M U N 2 C C C CCD C 0 N N a) a p. O- ,,0 - :_, e CO 0 C D }I . .@ .@ .2 .@ .. 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Ilw W W W W W W LU w w w w w 113 • • GI1 kn O 0 0o a a a 1 rn Z Z Z � v o , 5 o Z(�1� } o N �JJ A _U aa)) I o co 0 L T Z co aci I ) = Z :E. t O ma) a) a) 20 0 0 9, U U I C.) a a a zto u) 9 z 1 of N CI 2 o 1 N Ct. �o m a. -1 v t) CD J O a 1 LU�/ = IL a m a) O ii E II o I 0 LU o co m co a 1 C.) C) 01 E- J to Zavi .0.s 0 Q NO V) I 1 CD 0. CD c E O 2 U U a 1C) c 20 ° N a) Oa CD r E Q - N V — w .. r U a) o r > E a J N c � E c.)0 0 on ICC — C.) cz co a E m N 0 as 1 11 II , E M Ca � F a) E I IP a) N c rn a) C o .) c a) c G !. as QO c a) Q • CD O O- co O lb Z o >' 1'Ii 1 0 °1 O b 2 0 Z II to d Lo O 0 0 C7 Z N N 2 0 .._.. � rn } 0 M " 1 I o p o >, 1 m e ~ co E a ISI O m o H N o ; c cA o O = N 1 F. a) O W i0ce o as V p 0 1 a) 0 c0 O c0 Q O D co w C C U .. .� U J a) d a) c6 '£ O. 7 O d a a3 H E a O — 0 0 E 2 a) E 13 E E • S ConocoPhillips RECEIVED TRANSMITTAL NOV 12 . FROM: Sandra D. Lemke,ATM-704 TO: Meredith Guhl AOGCC ConocoPhillips Alaska, Inc. AOGCC P.G. Box 100360 333 W.5T"Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: Moraine 1 DATE: 11/10/2015 Transmitted: 11 Kuparuk River Unit, Alaska 1 II Moraine 1 i 1 color print each: f 25.' • Schlumberger: Laminated Sand Analysis(electronic file name: ICPAI Moraine 1RTScanner LSA3900ft 5520ft__PDF.pdf) In 2, (,54{ Halliburton: Reservoir Description Tool(electronic file name: MORAINE-1_RDT_27FEB15,pdf) � 1 1 i CD 11 h Schlumberger: Sonic Scanner,Compressional and Shear DT Computations fl Schlumberger: Sonic Scanner Compressional and Shear Borehole Anisotropy Analysis 'd Please promptly sign, scan and return electronically to Sandra.D.Lemke000P.com II q CC: Moraine 1 transmittal folder,well files, eSearch RECEIVED NOV 1 6 2015 Receipt: • Date: AOGCC ,,,,,o.....,_.,_,.___ GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph:907.265.6947 • S Bettis, Patricia K (DOA) To: Akindipe,Tunde <Olutunde.Akindipe@conocophillips.com> Subject: Moraine-1 (PTD 214-198) Good afternoon Tunde, The AOGCC is authorized to require reports, logs, analyses, and all other subsurface information on a well.AS 31.05.035. Because only velocity surveys and experimental logs are specifically exempted from reporting requirements, 20 AAC 25.071, any reports, logs and analyses that have been performed, including laminated sand analysis, QFT logs, lithology logs, core analyses, geochemical and formation fluid analyses, paleontology studies and palynology studies, must be provided. 20 AAC 25.071 requires both paper prints and digital formats. For the Moraine-1 (PTD 214-198)the following paper copies are required: 1. Schlumberger: Laminated Sand Analysis (electronic file name: CPAI_Moraine_1_RTScanner_LSA_3900ft_5520ft_PDF.pdf); and 2. Halliburton: Reservoir Description Tool (electronic file name: MORAINE-1_RDT_27FEB15.pdf). ConocoPhillips needs to justify under AS 31.05.035 and 20 AAC 25.071 why the operator is not required to submit to AOGCC the aforementioned subsurface data from the Moraine-1 well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@ alaska.gov. 1 • S Guhl, Meredith D (DOA) From: Umlauf, Kelly K <Kelly.K.Umlauf@conocophillips.com> Sent: Thursday, September 24, 2015 11:57 AM To: Brunswick, Scott A Cc: Allsup-Drake, Sharon K; Bettis, Patricia K (DOA); Guhl, Meredith D (DOA) Subject: RE: Moraine 1, PTD 214-198, Complete list of Geologic Markers required Attachments: Moraine_1_fi na l_to ps_Fo rState.xlsx Hi Scott, Attached is an xls of the tops for Moraine-1. Please let me know if you need anything additional. Cheers, Kelly From: Brunswick, Scott A Sent: Thursday, September 24, 2015 8:28 AM To: Umlauf, Kelly K Cc: Allsup-Drake, Sharon K; Bettis, Patricia K(DOA) (patricia.bettis©alaska.gov); Guhl, Meredith D (DOA) (meredith.guhlalaska.gov) Subject: FW: Moraine 1, PTD 214-198, Complete list of Geologic Markers required Kelly Can you please provide the below requested information so we may comply and get it delivered to the AOGCC in a timely fashion? Thanks Scott From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@ alaska.gov] Sent: Thursday, September 24, 2015 8:23 AM To: Brunswick, Scott A Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]Moraine 1, PTD 214-198, Complete list of Geologic Markers required Scott, During a review of the 10-407 form submitted for Moraine 1, PTD 214-198, completed 3/7/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the top of the K3, base of the Coyote,top of Moraine, and base of Moraine are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore, for example C40,C50, C20,W. Sak, C80. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by October 8, 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. 2 II I 29 MORAINE 1 S° c * Name MD (feet) TVD (feet) TVDSS (feet) UGNU_B 1563 1541 1499 PERMAFROST 1718 1689 1647 UGNU_A 1793 1761 1718 NA 1809 1777 1734 NB 1840 1806 1763 NC 1867 1832 1790 NF 1988 1949 1907 WEST_SAK_D 1995 1957 1914 WEST_SAK 1996 1957 1915 W EST SAK C 2026 1987 1945 W EST_SAK_B 2053 2014 1971 WEST_SAK_A4 2081 2040 1998 WEST SAK A3 2099 2059 2016 WEST_SAK_A2 2181 2139 2097 WEST_SAK_A1 2301 2258 2215 WEST SAK BASE 2492 2448 2406 CAMP_SST 2514 2470 2428 C-35 3952 3909 3866 K-3 4127 4083 4041 TOPSET_BASE 4277 4233 4190 TOP_MORAINE 5150 5107 5064 TOP_MEGATURB 5250 5206 5163 BASE_MEGATURB 5256 5212 5170 BASE MORAINE 5387 5344 5301 D75 7'78 ConocoPhillips RECEIVED MAY 28 2015; TRANSMITTAL AOGCC FROM: Sandra D. Lemke, AT03-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: Moraine 1 DATE: 05/26/2015 Transmitted: Kuparuk River Unit, Alaska Moraine 1 (Via thumb drive Date modified Type incline View Overburden Plug Photograp... 5119/20151:35 PM File folder Incline View Routine Plug Photography 5.19+ 015 1:35 PM File folder Sideview Routine Plug Photography Lu151:38 PM File folder Sideview Vertical Tracer Plug Photography 5./.19,,2015 138 PM File folder • 10.5 GB (Please promptly sign, scan and return electronically to Sandra.D.Lemke )COP.com CC: Moraine 1 transmittal folder,well files, eSearch Receipt / ) Date: GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 411 D. ywo;ski O .195 4 Conte:.Phillips Alaska Inc 700 G Street 154D ATO 3-382 Anchorage,AK 99501 Phone: 907.263.4859 ConocoPhillips Dan.L.Przywojski@ConocoPhillips.com RECEIVED Date: May 4, 2015 MAY 0 5 2015 ConocoPhillips Alaska Inc. AOGCC 700 G St. ATO3-382 Anch., AK. 99501 Attn: D.L.Przywojski To: Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Well Name: Moraine 1 Sample Type: Dry Cuttings(1 Set) Depth Range 120'-5610' Please sign and return a copy of this transmittal to: ConocoPhillips Alaska Inc. 700 G St. ATO3-382 Anch., AK. 99501 Attn: D.L.Przywojski RECEIVED Dan.L.Przywojski@ConocoPhillips.com MAY 5 2015 M' AOGCC SIGNED: ( • i Guhl, Meredith D (DOA) From: Allsup-Drake, Sharon K [Sharon.K.Allsup-Drake@conocophillips.com] Sent: Tuesday, April 28, 2015 8:57 AM To: Guhl, Meredith D (DOA) Cc: Brunswick, Scott A; Piercey, Tiffany C Subject: FW: Moraine 1 core description Attachments: 20150428083412.pdf Meredith — Attached are 3 tables with core descriptions for the Moraine 1 well. Please attach to the original completion report we sent in March 2015. Let us know if you have any other questions. Thank you, Sharon 263-4612 From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake©conocophillips.com] Sent: Tuesday, April 28, 2015 8:52 AM To: Allsup-Drake, Sharon K Subject: • • Section THREE: Core#1 Chip Descriptions&Photos TABLE 3:TOROK-MORAINE FORMATION CORE#1 CHIP DESCRIPTIONS CORE DESCRIPTION REPORT: noraine 1 -Core#1 Date: 02/21115 (?u +1N9T: 50-103-2089900-o0IFp►fritpi5; Torok-Moraine F d'' Kuparuk-Moraine rt,�aiie hyla Do th Imd): 5100 ,moo..Ste'PiI Kd): 5.056' Core BaYtb f'p/p,,: Hughes 408 f�y,7 r F P �aa�m Barry Wright mid Depth(rad): 8,174 5,130' Core BakhL131ze: 4" if a,'t'r Geoii foplsls. • JeIF MoBefh E, ij ,,' olal Footage' 74 PilrCore'RecdW red BO 71' 'Cera RacoviF,ed:(%): 98% F , . ,, ,!.."•!•'•, ,;r -;: is fima f..::...- tNxnP$o1?'Sglrlmer 6„_:...:._ R:_0sgr°seP.[,. ' ;!- *. Depth , Lithology Color Cement Matrix Structures Grain Size Soiling Porosity Odor Staining Fluorescence Cut Fluor? Comments 5100 shale dark gray thin lams clay _ none no no no overburden 5103 shale dark gray Olin lams clay none no no no overburden 5106 shale dark gray thin lams clay none no no _ no overburden 5109 shale dark gray thin lams clay none no no no overburden 5112 shale dark gray thin lams clay none no no no overburden 5115 shale dark gray, thin lams clay none no no no overburden 5118 shale dark gray thin lams clay none no no no overbwden 5121 shale dark gray thin tams clay none no no no oseiburden 5124 shale dark gray thin fans clay none no no no overburden 5127 shale dark gay thin lams clay none no no no overburden 5130 shale dark gray thin Karns clay none no no no asrbrrden 5133 shale _dark grey • thin lams clay none no no no pyrite blebs(pic) 5136 shale dark gray thin lams clay none , no no no overburden 5139 shale dark gray _ thin tarns clay none no no no silly 5142 shale dark gray thin lame clay _ none no no no pyrite blebs(pic) 5145 shale dark gray thin lams - clay none no no no o erburden 5148 shale dark gray thin lams clay none no no no overburden Top of Moraine-M50'and 5151 silly shale dark gray tin lams clay none no no no overburden 5154 sandstone brown—gray sll silica none thinly bedded very fine well sorted poor moderate yes dull yellow diffuse blue-white 6157 _ silty shale dare gray massive clay to silt slight no no diffuse blue-white 5160 sandstone brown-gray at silica- none thinly bedded very fine well sorted poor moderate yes bright yellow slow streaming bleeding gas 5163 sandstorm brown-gray ei silica none thinly bedded very fine well sorted poor moderate yes bright yellow,slow streaming 5166 sandstone brown-gray si silica none thinly bedded very fine well sorted poor strong yes bright yellow slow streaming 5169 _sandstone brawn gray si silica none thinly bedded_ wiry fine well sorted poor strong yes bright yellow slow streaming bleedng gas 1 ;:: a --: 'i1i•i - - • Comments_ s -• ••,,:;••••'ria«a,•.n: ...2 Ik Core'motored white culling at—5,166'and and jammed the core-Approximately 3 of core was lost white drilling ahead from 5,171'and to 5,174'rad ,Contact Phone We Geetogy:850k148Z Deectlonal Driller 659-1730;-Mud Engineer 6559-7211;Company.Adan 6597718. t'. • • Section FOUR: Core#2 Chip Descriptions&Photos TABLE 4:TOROK-MORAINE FORMATION CORE#2 CHIP DESCRIPTIONS CORE DESCRIPTION REPORT: Moraine 1 Core#2 Mme: 02/23/15 [..iAPJN.b 50-103-206ssoo-ao[ Torok Moraine mi(re)d:Yr Kuparuk-Moraine rl ivii; to :Depth..rid), 5174 i , StartdeptK(tld 5,130' imilotowiligywo Hughes 506 J w✓At-r Barry Wright . M 171'41(int ; 5.261. .:—aitztriadottilmil 5,21r cBelh t t>- .... d 5 ; ' '`: Garai••41,;=:1,w.,: JeffM1113 n ti 5r 41,90e ReccwN4ejifj 66 ,n� �.r* ire, ., s, ee .fl. s ff�trdN$4t8tayy� srt$4t�;+ct M _ n Depth Lithology Color Cement Matrix Structures Grain Size : Soiling Porosity 0dor Staining Fluoieecen-se •Ctitfliiir? ...Cominehta` 5174 silty aandst It-mod gry eh silica silty weak thin lams nig well poor moder#e Ugh( bright yellow diffuse blue-white 5177 silly sandst II-med gry sli silica silty weak thin lams wig well poor moderate light bright yellow/diffuse blue*•itlle 5180 silty sander It-med gry sli silica silty weak thin lams nfg well poor moderate light bright yellow diruse blue-while shalalaat contact 5183 silty sandst Il-med gry sli silica silty weak Thin lams mfg well poor strong tight bright yellow dlfuee blue-While 5186 silly sandst II-med gry sli silica silty weak thin lams rig well poor strong tight bright yellow/Muse blue-white 5189 silt and sand It-med gry silty laminated wig well poor moderate moderate bright yellow diffuse blue-while pails Mang sand 5192 ' silly sandal It-med gry sl silica ally sli thin lams Kg well poor strong light bright yellow/diffuse blue-while 5195 siltstone med gray auto laminated sat wry poor slight none hard 5198 sandstone brown-grey\ all silica none none rig-mfg well poor-mod strong moderate bnght yellow blue-whfle friable 5201 sandstone II brwn gry sl slice all silly none rfg well poor moderate moderate bright yellow blue-whirls friable 52134 sndst and silt II bran gry al silica silty slllesl contact vfg well poor moderate licit bright yellow diffuse blue-white alt/sat=lad 5207 silly sandal II lawn gry sli silica silty all thin lams Mg well poor slight fight dull yellow diffuse blue-white 5210 sandy slkal ltcted gry silty week thin tams vfg-sill well poor slight light dull yellow diffuse blue-white 5213 sandstone browngray all silica all silly none rig well poor-mod strong moderate bright yellow blue-while 5216 sandy shill lined gry silty thin lams Ng-sill well poor slight light din to bright diffuse blue-while sst micro lens 5219 _clayey sikst med gray silt-clay poor slight none none none wary had 5222 sest-sndst It biwn gry sii silica silty thin lams rfg-silt well poor moderate light dill to bright diffuse blue-while 5225 sltsl-sndst It baro gry sli silica silty thin lams rig-slit well poor moderate light dull to bright diffuse blue-while 5227 clayey sillst med gray silt-clay very poor slight none none none 5231 clayey sillst med gay thin lams sill-clay very poor slight none none none est micro lams 5234 shale mddrk gry clay-silt very poor slight none none none very hard 5237 clayey sillst med gay silt-clay wry poor slight none none none hard 5240 shale md-ik gry clay-silt very poor none none nme none very had 5243 shale med gray clay-silt wary poor slight none none none oil pops on mud 5246 sandstone brown-gray se silica none none rig well poor-mod moderate light dill yellow diffuse flue-whilefree oil on surface. 5249 sandy sillst It brat gry ally none rig-sill well poor slight light dull yellow dlFueo blue-white wry hard _ 5252 sandy silts! It lawn gry ally node vig-silt well poor slight lig i dul yellow diffuse blue-while wry herd 5255 clayey silts! med gray clayey none silt-clay very poor slight none none none hard 5257 sandy siker It brei gryally thin lame sill+Ag well poor slight light dull yellow diffuse blue-white herd 5259_25 black-blue rusted iron rich flake poornone sli mineral dull none black lathy d Core#2 jammed while culling all—5,261'rod.Core lively jammed at 5,259`and Approximately 1.9 of core was last while drilling ahead from 5,259' to5,261'rod. I I I due to unconsolidated formation i i I I. } � .: _ .. I I . I ' i . .. I...... .... .I I CgHiot P oiiti7 s:,Reoldgy 659-1462:Directional Driller 659-173(3 Mi7vl r4 T21:'11`i 1pelrell Alla 3$ r« :c:a57`a:79. 4,'.4 rW^,•-3931 e.'9 _-;1: ; • • Section FIVE: Core#3 Chip Descriptions& Photos • TABLE 5:TOROK-MORAINE FORMATION CORE#3 CHIP DESCRIPTIONS CORE IJESCRIPTION REPORT: Moraine 1-Core#3 µDate; 02125/15 I:AL1No; 50-10320e990000 ForPjlfUo11; Task-Moraine cfilplala$4Kuparuk-Moraine Siaigitkjitrift De'tith{rad): 5,26t' Start drilplit'twdh 5,217' ;-: LCorle" aeei 17 Hughes 506 tarsi . Barry Wright rand Depth'imdp% 5,308' k 'End de pilot k 5,262' rt5'l Cgte t5alr@I KtiiI 4" res• k_, Geo Jeff McBeth ,tr.Tout.F.00tage: ASi 9 -�Coreiile6oiNtrei3,(Ny 35' tiiag6.[�c;ysr�d.i fJ: 7996 ok7c ^;AKI;4"ix1-,MKA ' sM>• . !...",+:a,L,,,,:-'-.2,. ..: . ." ., '"Discriphotl gU1 W'S' X int : l M . t ilM r ,.s... .. :,'Depth`.-:flitheiopf :Teter -Cement Matrix Structures Grain Size Sorting Porosity Odor Staining Fluorescence: Cut Fluor? Comments 5264 silty sandal IL-med gry at silica silty none fg well poor to fork moderate light bright yellow diffuse blue-writ 5267 sandstone lt-med gry all silica _ none sk partings big well far moderate moderate bright yellow slow streaming bleeding gas 5270 silty shale med gray clayey none clay-sal well very poor none none none none its 5273 silty amidst It-med gry sli siica silty none rig well poor moderate light bright yellow dime blue-whit km 5276 sandy stint Inbred gry sli siica silty none big•silt well poor slight light none diffuse mud contain? 5279 sandy sitar med gray silly sli thin lams big-sill wen poor slight light none diffuse mud contam? 5282 stay shale reed gray clayey none clay-sill welt wry poor none none none diffuse firm 5285 sandstone 'Lined gry sli silica none none Ng well poor to fair moderate light bright yellow diffuse blue-whit liable 5288 silty sandal It-med gry sir silica sky none rig well poor-mod moderate light bright yellow&fuse Wire-whit sli friable 5291 silly sandal Il-med gry all silica sky none K9 well poor-mod moderate light , bright yellow ckause blue-whit all friable 5294 silty shale reed gray clayey none clay-slit well wry poor none none none none firm 5296.35 sky swat It lawn gry sti mica sky none *wit well poor-mod slight , light dull yellow diffuse blue-whit base core bit Mz .-tom ?;1 V.. . • nu<.t99( r .. Air m Wlr II s: Mtr P asl g SIAVAIWIPVININItMaRginkitalF1 Core slopped drilling al 5308'and Noticed dung processing that the cone was seized In the ogre banal at 5,285 and j I f // jir I { lv contact Phdktets'_Gedogy 659-1462;Directional Driler-659-1730;Mud Englneer_.85$-72110DOMMOgi tRarA3777: f, ,aurrrwvO?ItGIE a s _ ag9t _,:i4/67.1 • 214198 2 ,V- Lt' iDD ConocoPhillips APR 2 8 2015 TRANSMITTAL AOGCC DATA LOGGED FROM: Sandra D. Lemke,AT01412 TO: Makana Bender 5 i1OG GE5 ConocoPhilips Alaska, Inc. AOGCC M.K BENDER P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: Moraine 1 DATE: 04/27/2015 Transmitted: [Kuparuk River Unit, Alaska Moraine 1 1 CD each 1 Core 1 Core photos UU WL 4/27//2015 3:54 PM File folder 11 11 Core 2 Core Photos UV WL 4/27/2015 3:54 PM File folder Core 3 Core Phctes UV WL 4/27/2015 3:54 PM File folder11 I Final_Wellsite'_Geoiogist_Reports 4/27/2015 3:54 PM File folder11 FinalBoxPhotos 4/27/2015 3:54 PM File folder ii FinalFootbyFootPhotos 4/27/2015 3:54 PM File folder FinalSamplesSectionPhotos 4/27/2015 3:54 PM File folder Graphiclog 4/27/2015 3:54 PM File folder n weatherferd data 4/27/2015 3:54 PM File folder wellsite core gamma 4/27/2015 3:54 PM File folder } J HH-75558 Gamma Profile 2-25-15.xlsx 3/3/2015 9:46 AM Microsoft Excel W... 319 KB r .s-71..1 Morainelcore_plug facies.xlsx 3'20/2015 10:53 AM Microsoft Excel W.,. 170 KB 11 Please promptly sign, scan and return electronically to Sandra.D.Lemke( COP.com I CC: Morainel transmittal folder, production well files, eSearch 1 lib 8//5— Receipt: 41,4_ Date: GIS-Technical Data Management I Can Phillips I Anchorage,Alaska I Ph: 907.265 6947 • • 21 4198 ConocoPhillips TRANSMITTAL DATA LOGGED 5 n3/2oig M.K.BENDER FROM: Sandra D. Lemke,ATQ1412 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: Moraine 1 DATE: 04/022/2015 Transmitted: Kuparuk River Unit, Alaska Moraine 1 1 CD each: Schlumberger LithoScanner(revised); CD contains DLIS, LAS, PDF files 1 5 7 0 4 n _ Schlumberger RT Scanner; CD contains DLIS, LAS, PDF files 2 5 7 0 5 1 Color print each: Schlumberger RT Scanner 1D Inversion 3/2/2015 Schlumberger LithoScanner Revised 3/2/2015 Schlumberger Sonic Scanner Compressional and Shear Anistrophy Analysis3/2/2015 Schlumberger Sonic Scanner Compressional and Shear-DT computations 3/2/2015 1Please promptly sign, scan and return electronically to Sandra.D.LemkecCOP.com n _ _ CC: Maraifl eeptailiyt5oduction well files, eSearch Receipt: APR 22 2015 Date: - = di CC GIS-Technical Data Management I ConocoPhillips 'Anchorage, Alaska I Ph: 907.2656947 • Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, April 20, 2015 3:20 PM To: Brunswick, Scott A Cc: Bettis, Patricia K(DOA) Subject: Moraine 1, PTD 214-198, Core Data Scott, Conventional cores were acquired in Moraine 1, PTD 214-198, but in Box 28 on the 10-407 form nothing was filled in. Per the instructions: "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)." I checked the rest of the 10-407 packet and did not locate the core information. Please provide the required core information via email and I will append it to the 10-407 report. Please provide the core information by April 27, 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(a)alaska.gov. 1 0 114198 Conoco%Mi s RECEIVED APR 0 9 2015 25 65 4 TRANSMITTAL AOGGC 25 65 5 2 565 6 DATA LOGGED 2 5 6 5 7 FROM: Sandra D. Lemke, AT01412 TO: Makana Bender 5 K 6/2015 2 5 6 5 8 M.K.BENDER ConocoPhillips Alaska, Inc. AOGCC 1 5 6 5 9 P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: Moraine 1 DATE: 04/08/2015 Transmitted: IKuparuk River Unit, Alaska II Moraine 1 n 1 CD each: Halliburton MRIL-RDT Digital data, digital log, Interpretation report Schlumberger PEX-GR Comp Neutron data in .las/dlis; graphic pdf's L Schlumberger Sonic Scanner-GR; Monopole P&S+ Dipole Shear Delta T; data in ,las/dlis; graphic pdf's Schlumberger FM!-GR: Formation Micro Imager data in.las/dlis; graphic pdfs 11 Schlumberger ZAIT; Array Induction Resistivity data in .1as/dlis; graphic pdfs Schlumberger Triple Combo AIT-TLD-CNL-GR data in .las/dlis; graphic pdfs ' 1 Color print each: _—Halliburton MRIL logs 2"&5"; MRIL prime report and color log; ROT Interpretation Report;formation testing & n sampling Schlumberger FMI-GR Formation Micro Image-GR;field image log ' Schlumberger MAST-GR; Sonic Scanner GR; Monopole P&S+ Dipole Shear Delta T log 11 Schlumberger PEX-GR; Compensated Neutron Lithology Density Log 11 Schlumberger Platform Express; Combo print; AIT-TLD-CNL-GR Schlumberger AIT-GR; Array Induction Resistivity Log I l 'Please promptly sign, scan and return electronically to Sandra.D.LemkeOCOP,com CC: Moraines transmittal folder, production well files, eSearch (1)Receipt: 1/ z4V 6...e1,44ekte: .Awisso. '" 06,- GIS Teci nica/Data Manageineiit I ConocoPhillips tAnchorage,Alaska I Ph:907265.6947 • 21 4198 2255663332 �•�` ConocoPhillips 2 5 6 4 TRANSMITTAL APR 03 2015 AOGCC FROM: Sandra D. Lemke,AT01412 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave. Suite 100 Anchorage AK 99510-0350 Anchorage,Alaska 99501 DATA LOGGED 9 g 5iyi2oiS M.K.BENDER RE: Moraine 1 DATE:04/01/2015 Transmitted: 11 1Kuparuk River Unit, Alaska Moraine 1 1 CD each: Schlumberger LWD Ecoscope; partner final EOW; graphics/data/final directional surveys(NAD27&NAD83 pdf/txt) 9 p Schlumberger Sonic Scanner Best DT-P&S Processing Anistrophy; DLIS/LAS/PDF I Schlumberger Best DT-Sonic Scanner; DLIS, LAS, PDF Schlumberger FMI Processed Images; DLIS/PDF and LAS files 11 Color print each: Schlumberger FMI Processed Log Summary 1:10 Schlumberger Sonic Scanner Anistrophy Processing-Fast and Slow Shear Slowness I Schlumberger Best DT-Sonic Scanner-Far momopole and Dipole Processing 1:240 Schlumberger Ecoscope;2"MD; 5"MD;2"TVD; 5"TVD;2"SSTVD Schlumberger final definitive directional survey hardcopy reports(NAD27 and NAD 83) Please promptly sign, scan and return electronically to Sandra.D.LemkeOCOP.com CC: Moraine1 transmittal folder, production well files, eSearch ReceiriMAL""L117) O_étate: .711111111111.1bilikt CIS-Technical Data Management I CanocaPhiilios I Anchorage,, Alaska j Ph:907.265.6947 • • 21 4198 25632 RECEIVED r � FINAL APR 0 3 2015 AOGCC NADConversion North Alaska ASP4 Moraine Moraine 1 Definitive Survey Report , NAD 27 20 March, 2015 • S Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Project North Alaska ASP4 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 Moraine 1 Well Position +N/-S 0.00 usft Northing: 5,997,105.06 usft Latitude: 70°24'11.299 N +El-W 0.00 usft Easting: 468,098.69 usft Longitude: 150°15'34.812 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 14.00 usft Wellbore Moraine 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 2/5/2015 18.79 80.92 57,566 Design Moraine 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.57 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 28.57 0.00 0.00 29.17 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 50.15 232.43 MWD Svy1 Inc+Trend(Moraine 1) INC+TREND Inclinometer+known azi trend 3/13/2015 11:54: 328.18 2,423.89 MWD Svy2 MWD+DMag(Moraine 1) MWD+SCC MWD+Short Collar correction 3/13/2015 11:59: 2,536.29 5,545.22 MWD Svy3 MWD(Moraine 1) MWD MWD-Standard 3/13/2015 12:14 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 28.57 0.00 0.00 28.57 -14.00 0.00 0.00 5,997,105.06 468,098.69 0.00 0.00 UNDEFINED 50.15 0.07 15.81 50.15 7.58 0.01 0.00 5,997,105.07 468,098.69 0.32 0.01 INC+TREND(1) 108.20 0.12 55.46 108.20 65.63 0.08 0.06 5,997,105.14 468,098.75 0.14 0.10 INC+TREND(1) � 16"x 42" 143.12 0.16 65.13 143.12 100.55 0.12 0.14 5,997,105.18 468,098.82 0.14 0.17 INC+TREND(1) 232.43 0.60 236.09 232.43 189.86 -0.09 -0.14 5,997,104.97 468,098.55 0.85 -0.14 INC+TREND(1) 328.18 0.51 247.16 328.17 285.60 -0.53 -0.95 5,997,104.53 468,097.74 0.15 -0.93 MWD+SCC(2) 417.48 0.44 324.33 417.47 374.90 -0.41 -1.51 5,997,104.66 468,097.17 0.67 -1.09 MWD+SCC(2) 505.97 0.84 344.58 505.96 463.39 0.49 -1.88 5,997,105.56 468,096.81 0.51 -0.49 MWD+SCC(2) 599.49 1.86 8.96 599.45 556.88 2.65 -1.83 5,997,107.72 468,096.87 1.23 1.43 MWD+SCC(2) 687.75 4.25 21.88 687.58 645.01 7.10 -0.39 5,997,112.16 468,098.33 2.80 6.01 MWD+SCC(2) 779.88 4.66 25.03 779.43 736.86 13.66 2.47 5,997,118.71 468,101.21 0.52 13.13 MWD+SCC(2) 3/20/2015 2:05:26PM Page 2 COMPASS 5000.1 Build 65 . • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 878.30 7.03 31.61 877.33 834.76 22.42 7.32 5,997,127.44 468,106.10 2.50 23.14 MWD+SCC(2) 972.19 8.42 32.85 970.37 927.80 33.08 14.06 5,997,138.08 468,112.88 1.49 35.74 MWD+SCC(2) 1,065.74 10.98 30.60 1,062.57 1,020.00 46.51 22.31 5,997,151.47 468,121.19 2.77 51.48 MWD+SCC(2) 1,159.66 12.72 30.02 1,154.49 1,111.92 63.16 32.04 5,997,168.08 468,130.99 1.86 70.77 MWD+SCC(2) 1,254.76 14.89 31.12 1,246.84 1,204.27 82.69 43.59 5,997,187.55 468,142.63 2.30 93.45 MWD+SCC(2) 1,348.98 16.59 31.82 1,337.52 1,294.95 104.48 56.94 5,997,209.29 468,156.07 1.82 118.99 MWD+SCC(2) 1,443.23 18.60 32.79 1,427.36 1,384.79 128.56 72.18 5,997,233.29 468,171.40 2.16 147.43 MWD+SCC(2) 1,541.36 18.08 32.64 1,520.50 1,477.93 154.53 88.86 5,997,259.20 468,188.20 0.53 178.25 MWD+SCC(2) 1,632.47 17.53 33.08 1,607.25 1,564.68 177.94 103.98 5,997,282.53 468,203.41 0.62 206.05 MWD+SCC(2) 1,726.28 16.85 33.77 1,696.87 1,654.30 201.08 119.25 5,997,305.60 468,218.78 0.76 233.70 MWD+SCC(2) 1,819.99 15.26 28.04 1,786.92 1,744.35 .223.26 132.60 5,997,327.72 468,232.22 2.39 259.57 MWD+SCC(2) 1,914.34 15.06 28.54 1,877.99 1,835.42 244.98 144.29 5,997,349.40 468,244.01 0.25 284.24 MWD+SCC(2) 2,007.85 11.95 25.83 1,968.90 1,926.33 264.37 154.31 5,997,368.74 468,254.11 3.39 306.06 MWD+SCC(2) 2,102.27 11.06 27.45 2,061.43 2,018.86 281.21 162.75 5,997,385.54 468,262.62 1.00 324.87 MWD+SCC(2) 2,196.45 9.62 27.24 2,154.08 2,111.51 296.22 170.52 5,997,400.52 468,270.45 1.53 341.77 MWD+SCC(2) 2,291.25 6.91 27.86 2,247.88 2,205.31 308.31 176.81 5,997,412.58 468,276.79 2.86 355.39 MWD+SCC(2) 2,384.85 3.77 32.87 2,341.06 2,298.49 315.87 181.11 5,997,420.12 468,281.13 3.39 364.09 MWD+SCC(2) 2,423.89 1.83 52.14 2,380.06 2,337.49 317.34 182.30 5,997,421.58 468,282.32 5.46 365.94 MWD+SCC(2) 2.486.80 0.89 58.47 2,442.95 2,400.38 318.21 183.51 5,997,422.45 468,283.53 1.52 367.29 MWD(3) 9-5/8"x 12-1/4" 111111111111111 2,536.29 0.22 104.60 2,492.44 2,449.87 318.38 183.92 5,997,422.62 468,283.95 1.52 367.65 MWD(3) 2,631.39 0.06 60.09 2,587.54 2,544.97 318.36 184.14 5,997,422.60 468,284.17 0.19 367.74 MWD(3) 2,725.23 0.09 23.91 2,681.38 2,638.81 318.45 184.22 5,997,422.69 468,284.24 0.06 367.85 MWD(3) 2,819.77 0.06 156.10 2,775.92 2,733.35 318.48 184.27 5,997,422.71 468,284.29 0.15 367.90 MWD(3) 2,913.81 0.09 313.33 2,869.96 2,827.39 318.48 184.23 5,997,422.72 468,284.26 0.16 367.89 MWD(3) 3,007.68 0.09 251.92 2,963.83 2,921.26 318.51 184.11 5,997,422.75 468,284.14 0.10 367.85 MWD(3) 3,101.93 0.06 325.19 3,058.08 3,015.51 318.53 184.01 5,997,422.76 468,284.04 0.10 367.82 MWD(3) 3,195.68 0.11 103.19 3,151.83 3,109.26 318.55 184.07 5,997,422.78 468,284.10 0.17 367.86 MWD(3) 3,289.79 0.06 96.32 3,245.94 3,203.37 318.52 184.21 5,997,422.76 468,284.23 0.05 367.91 MWD(3) 3,384.25 0.06 39.98 3,340.39 3,297.82 318.55 184.29 5,997,422.79 468,284,31 0.06 367.98 MWD(3) 3,572.50 0.06 311.74 3,528.64 3,486.07 318.69 184.28 5,997,422.93 468,284.31 0.04 368.09 MWD(3) 3,759.61 0.09 137.59 3,715.75 3,673.18 318.65 184.30 5,997,422.89 468,284.33 0.08 368.07 MWD(3) 3,853.81 0.09 58.52 3,809.95 3,767.38 318.63 184.42 5,997,422.87 468,284.44 0.12 368.11 MWD(3) 3,948.64 0.09 19.22 3,904.78 3,862.21 318.74 184.51 5,997,422.98 468,284,53 0.06 368.25 MWD(3) 4,042.70 0.09 63.71 3,998.84 3,956.27 318.85 184.60 5,997,423.08 468,284.62 0.07 368.38 MWD(3) 4,137.28 0.06 93.38 4,093.42 4,050.85 318.88 184.71 5,997,423.11 468,284.74 0.05 368.46 MWD(3) 4,232.51 0.09 295.36 4,188.65 4,146.08 318.91 184.69 5,997,423.14 468,284.72 0.15 368.48 MWD(3) 4,326.94 0.09 71.16 4,283.08 4,240.51 318.96 184.70 5,997,423.20 468,284.73 0.18 368.53 MWD(3) 4,421.03 0.09 216.54 4,377.17 4,334.60 318.93 184.72 5,997,423.16 468,284.75 0.18 368.51 MWD(3) 4,515.67 0.06 17.18 4,471.81 4,429.24 318.91 184.69 5,997,423.15 468,284.72 0.16 368.49 MWD(3) 3/20/2015 2:05:26PM Page 3 COMPASS 5000.1 Build 65 . ' •• Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,610.28 0.09 332.90 4,566.42 4,523.85 319.03 184.67 5,997,423.26 468,284.70 0.07 368.58 MWD(3) 4,704.10 0.09 151.28 4,660.24 4,617.67 319.03 184.68 5,997,423.26 468,284.70 0.19 368.58 MWD(3) 4,797.74 0.06 261.05 4,753.88 4,711.31 318.96 184.66 5,997,423.19 468,284.69 0.13 368.51 MWD(3) 4,891.66 0.06 325.28 4,847.80 4,805.23 318.99 184.59 5,997,423.22 468,284.61 0.07 368.50 MWD(3) 5,038.29 0.12 333.74 4,994.43 4,951.86 319.19 184.47 5,997,423.42 468,284.50 0.04 368.62 MWD(3) 5,087.78 0.04 141.71 5,043.92 5,001.35 319.22 184.46 5,997,423.46 468,284.49 0.32 368.64 MWD(3) 5,181.59 0.09 50.16 5,137.73 5,095.16 319.24 184.54 5,997,423.48 468,284.57 0.11 368.70 MWD(3) 5,278.18 0.04 84.51 5,234.32 5,191.75 319.30 184.63 5,997,423.53 468,284.66 0.06 368.79 MWD(3) 5,371.42 0.09 90.77 5,327.56 5,284.99 319.30 184.74 5,997,423.53 468,284.77 0.05 368.84 MWD(3) 5,466.45 0.12 334.35 5,422.59 5,380.02 319.39 184.77 5,997,423.62 468,284.80 0.19 368.94 MWD(3) 5,545.22 0.09 68.95 5,501.36 5,458.79 319.48 184.79 5,997,423.72 468,284.82 0.20 369.03 MWD(3) 5,610.00 0.09 68.95 5,566.14 5,523.57 319.52 184.89 5,997,423.75 468,284.92 0.00 369.11 PROJECTED to TD a 3/20/2015 2:05:26PM Page 4 COMPASS 5000.1 Build 65 r . • 1 0 a a) I C"' as (13 13 Gam) E 1 co C �c„'iO v" A L o&30 O Ol N > N v O O o c U o .� \:\ o O U IL > (13 w } y (7) O (A a) ; OOp Q N w i a C • w a) m J U 0 Q N Et C a) U 21 41 98 • • 25632 RECEIVED APR 032015 FINAL AOGGC ConocoPhillips (Alaska) Inc. -Expl North Alaska ASP4 Moraine Moraine 1 Definitive Survey Report Nay 83 20 March, 2015 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Project North Alaska ASP4 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 4 Using geodetic scale factor Well Moraine 1 Well Position +N/-S 0.00 usft Northing: 5,996,855.38 usft Latitude: 70°24'10.203 N +E/-W 0.00 usft Easting: 1,608,130.73 usft Longitude: 150°15'46.110 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 14.00 usft Wellbore Moraine 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/5/2015 18.79 80.92 57,566 Design Moraine 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.57 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.57 0.00 0.00 29.17 Survey Program Date 3/20/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 50.15 232.43 MWD Svy1 Inc+Trend(Moraine 1) INC+TREND Inclinometer+known azi trend 3/13/2015 11:54: 328.18 2,423.89 MWD Svy2 MWD+DMag(Moraine 1) MWD+SCC MWD+Short Collar correction 3/13/2015 11:59: 2,536.29 5,545.22 MWD Svy3 MWD(Moraine 1) MWD MWD-Standard 3/13/2015 12:14 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 28.57 0.00 0.00 28.57 -14.00 0.00 0.00 5,996,855.38 1,608,130.73 0.00 0.00 UNDEFINED 50.15 0.07 15.81 50.15 7.58 0.01 0.00 5,996,855.39 1,608,130.73 0.32 0.01 INC+TREND(1) 108.20 0.12 55.46 108.20 65.63 0.08 0.06 5,996,855.46 1,608,130.79 0.14 0.10 INC+TREND(1) ° >«t"_ 16"x 42" 143.12 0.16 65.13 143.12 100.55 0.12 0.14 5,996,855.50 1,608,130.87 0.14 0.17 INC+TREND(1) 232.43 0.60 236.09 232.43 189.86 -0.09 -0.14 5,996,855.29 1,608,130.59 0.85 -0.14 INC+TREND(1) 328.18 0.51 247.16 328.17 285.60 -0.53 -0.95 5,996,854.85 1,608,129.78 0.15 -0.93 MWD+SCC(2) 417.48 0.44 324.33 417.47 374.90 -0.41 -1.51 5,996,854.98 1,608,129.22 0.67 -1.09 MWD+SCC(2) 505.97 0.84 344.58 505.96 463.39 0.49 -1.88 5,996,855.88 1,608,128.85 0.51 -0.49 MWD+SCC(2) 599.49 1.86 8.96 599.45 556.88 2.65 -1.83 5,996,858.04 1,608,128.91 1.23 1.43 MWD+SCC(2) 687.75 4.25 21.88 687.58 645.01 7.10 -0.39 5,996,862.49 1,608,130.37 2.80 6.01 MWD+SCC(2) 779.88 4.66 25.03 779.43 736.86 13.66 2.47 5,996,869.03 1,608,133.26 0.52 13.13 MWD+SCC(2) 3/20/2015 10:50:31AM Page 2 COMPASS 5000.1 Build 65 • • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 878.30 7.03 31.61 877.33 834.76 22.42 7.32 5,996,877.76 1,608,138.14 2.50 23.14 MWD+SCC(2) 972.19 8.42 32.85 970.37 927.80 33.08 14.06 5,996,888.40 1,608,144.93 1.49 35.74 MWD+SCC(2) 1,065.74 10.98 30.60 1,062.57 1,020.00 46.51 22.31 5,996,901.79 1,608,153.24 2.77 51.48 MWD+SCC(2) 1,159.66 12.72 30.02 1,154.49 1,111.92 63.16 32.04 5,996,918.40 1,608,163.04 1.86 70.77 MWD+SCC(2) 1,254.76 14.89 31.12 1,246.84 1,204.27 82.69 43.59 5,996,937.87 1,608,174.67 2.30 93.45 MWD+SCC(2) 1,348.98 16.59 31.82 1,337.52 1,294.95 104.48 56.94 5,996,959.61 1,608,188.12 1.82 118.99 MWD+SCC(2) 1,443.23 18.60 32.79 1,427.36 1,384.79 128.56 72.18 5,996,983.61 1,608,203.45 2.16 147.43 MWD+SCC(2) 1,541.36 18.08 32.64 1,520.50 1,477.93 154.53 88.86 5,997,009.51 1,608,220.25 0.53 178.25 MWD+SCC(2) 1,632.47 17.53 33.08 1,607.25 1,564.68 177.94 103.98 5,997,032.85 1,608,235.47 0.62 206.05 MWD+SCC(2) 1,726.28 16.85 33.77 1,696.87 1,654.30 201.08 119.25 5,997,055.92 1,608,250.83 0.76 233.70 MWD+SCC(2) 1,819.99 15.26 28.04 1,786.92 1,744.35 223.26 132.60 5,997,078.04 1,608,264.28 2.39 259.57 MWD+SCC(2) 1,914.34 15.06 28.54 1,877.99 1,835.42 244.98 144.29 5,997,099.71 1,608,276.06 0.25 284.24 MWD+SCC(2) 2,007.85 11.95 25.83 1,968.90 1,926.33 264.37 154.31 5,997,119.06 1,608,286.17 3.39 306.06 MWD+SCC(2) 2,102.27 11.06 27.45 2,061.43 2,018.86 281.21 162.75 5,997,135.86 1,608,294.68 1.00 324.87 MWD+SCC(2) 2,196.45 9.62 27.24 2,154.08 2,111.51 296.22 170.52 5,997,150.83 1,608,302.51 1.53 341.77 MWD+SCC(2) 2,291.25 6.91 27.86 2,247.88 2,205.31 308.31 176.81 5,997,162.89 1,608,308.85 2.86 355.39 MWD+SCC(2) 2,384.85 3.77 32.87 2,341.06 2,298.49 315.87 181.11 5,997,170.44 1,608,313.18 3.39 364.09 MWD+SCC(2) 2,423.89 1.83 52.14 2,380.06 2,337.49 317.34 182.30 5,997,171.89 1,608,314.38 5.46 365.94 MWD+SCC(2) 2,486.80 0.89 58.47 2,442.95 2,400.38 318.21 183.51 5,997,172.76 1,608,315.59 1.52 367.29 MWD(3) 9-5/8"x 12-1/4" 2,536.29 0.22 104.60 2,492.44 2,449.87 318.38 183.92 5,997,172.93 1,608,316.01 1.52 367.65 MWD(3) 2,631.39 0.06 60.09 2,587.54 2,544.97 318.36 184.14 5,997,172.91 1,608,316.23 0.19 367.74 MWD(3) 2,725.23 0.09 23.91 2,681.38 2,638.81 318.45 184.22 5,997,173.00 1,608,316.30 0.06 367.85 MWD(3) 2,819.77 0.06 156.10 2,775.92 2,733.35 318.48 184.27 5,997,173.02 1,608,316.35 0.15 367.90 MWD(3) 2,913.81 0.09 313.33 2,869.96 2,827.39 318.48 184.23 5,997,173.03 1,608,316.32 0.16 367.89 MWD(3) 3,007.68 0.09 251.92 2,963.83 2,921.26 318.51 184.11 5,997,173.06 1,608,316.20 0.10 367.85 MWD(3) 3,101.93 0.06 325.19 3,058.08 3,015.51 318.53 184.01 5,997,173.08 1,608,316.10 0.10 367.82 MWD(3) 3,195.68 0.11 103.19 3,151.83 3,109.26 318.55 184.07 5,997,173.10 1,608,316.16 0.17 367.86 MWD(3) 3,289.79 0.06 96.32 3,245.94 3,203.37 318.52 184.21 5,997,173.07 1,608,316.29 0.05 367.91 MWD(3) 3,384.25 0.06 39.98 3,340.39 3,297.82 318.55 184.29 5,997,173.10 1,608,316.37 0.06 367.98 MWD(3) 3,572.50 0.06 311.74 3,528.64 3,486.07 318.69 184.28 5,997,173.24 1,608,316.37 0.04 368.09 MWD(3) 3,759.61 0.09 137.59 3,715.75 3,673.18 318.65 184.30 5,997,173.20 1,608,316.39 0.08 368.07 MWD(3) 3,853.81 0.09 58.52 3,809.95 3,767.38 318.63 184.42 5,997,173.18 1,608,316.50 0.12 368.11 MWD(3) 3,948.64 0.09 19.22 3,904.78 3,862.21 318.74 184.51 5,997,173.29 1,608,316.59 0.06 368.25 MWD(3) 4,042.70 0.09 63.71 3,998.84 3,956.27 318.85 184.60 5,997,173.39 1,608,316.68 0.07 368.38 MWD(3) 4,137.28 0.06 93.38 4,093.42 4,050.85 318.88 184.71 5,997,173.42 1,608,316.80 0.05 368.46 MWD(3) 4,232.51 0.09 295.36 4,188.65 4,146.08 318.91 184.69 5,997,173.45 1,608,316.78 0.15 368.48 MWD(3) 4,326.94 0.09 71.16 4,283.08 4,240.51 318.96 184.70 5,997,173.51 1,608,316.79 0.18 368.53 MWD(3) 4,421.03 0.09 216.54 4,377.17 4,334.60 318.93 184.72 5,997,173.47 1,608,316.81 0.18 368.51 MWD(3) 4,515.67 0.06 17.18 4,471.81 4,429.24 318.91 184.69 5,997,173.46 1,608,316.78 0.16 368.49 MWD(3) 3/20/2015 10:50:31AM Page 3 COMPASS 5000.1 Build 65 ' • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 4,610.28 0.09 332.90 4,566.42 4,523.85 319.03 184.67 5,997,173.57 1,608,316.76 0.07 368.58 MWD(3) 4,704.10 0.09 151.28 4,660.24 4,617.67 319.03 184.68 5,997,173.58 1,608,316.76 0.19 368.58 MWD(3) 4,797.74 0.06 261.05 4,753.88 4,711.31 318.96 184.66 5,997,173.50 1,608,316.75 0.13 368.51 MWD(3) 4,891.66 0.06 325.28 4,847.80 4,805.23 318.99 184.59 5,997,173.54 1,608,316.67 0.07 368.50 MWD(3) 5,038.29 0.12 333.74 4,994.43 4,951.86 319.19 184.47 5,997,173.74 1,608,316.56 0.04 368.62 MWD(3) 5,087.78 0.04 141.71 5,043.92 5,001.35 319.22 184.46 5,997,173.77 1,608,316.55 0.32 368.64 MWD(3) 5,181.59 0.09 50.16 5,137.73 5,095.16 319.24 184.54 5,997,173.79 1,608,316.63 0.11 368.70 MWD(3) 5,278.18 0.04 84.51 5,234.32 5,191.75 319.30 184.63 5,997,173.84 1,608,316.72 0.06 368.79 MWD(3) 5,371.42 0.09 90.77 5,327.56 5,284.99 319.30 184.74 5,997,173.84 1,608,316.83 0.05 368.84 MWD(3) 5,466.45 0.12 334.35 5,422.59 5,380.02 319.39 184.77 5,997,173.93 1,608,316.86 0.19 368.94 MWD(3) 5,545.22 0.09 68.95 5,501.36 5,458.79 319.48 184.79 5,997,174.03 1,608,316.88 0.20 369.03 MWD(3) 5,610.00 0.09 68.95 5,566.14 5,523.57 319.52 184.89 5,997,174.07 1,608,316.98 0.00 369.11 PROJECTED to TD 3/20/2015 10:50:31AM Page 4 COMPASS 5000.1 Build 65 • • ci i L., 0 e 14 d > -a os V C 3 0 0 m -0 ,° a) a) CO "oE •L m �, as k1-' C O c 6E °' s N ) t z E - - - ° 0 o a > C o, 4Z � U o C t CO C 05 U c 0 dU 0 � � r NNW � • F 00 w U al >, .,-_----3 \(\ a: > m > 8 (n cts di til o m a) 9j J NCU u) 2 o Q N EY C a7 U RECEIVED • STATE OF ALASKA S MAR 2 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG3C( la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑, Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test LII 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 7,2015 214-198/315-117 3.Address: 6.Date Spudded: 13.API Number: P. O. Box 100360,Anchorage,AK 99510-0360 • February 7,2015 50-103-20699-00-c0- 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4620'FNL,4368'FEL,Sec. 12,T12N, R7E, UM • February 26,2015 Moraine 1 I Top of Productive Horizon: 8. KB(ft above MSL): 43'RKB 15.Field/Pool(s): 978'FSL, 1098'FWL, Sec. 12,T12N, R7E, UM GL(ft above MSL): 14'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 979'FSL, 1098'FWL, Sec. 12,T12N, R7E, UM surface Undefined Torok Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-468099 y- 5997105 Zone-4 •5610'MD/5566'TVD ADL 25528 TPI: x-468285 y- 5997423 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-468285 y- 5997424 Zone-4 none 2639 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) na (fi f;1SL) 1555'MD/1533'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res/Neutron/Density, RDT log FM I M Ql L I.A4 not applicable 23. t 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" 164.8# 1.031 28' 108' 28' 108; 24" 250 sx AS 9.625" 40# L-80 26' 2485' 26' 2441' 12.25" 1047 sx Class G, 179 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) none none Vu/- none ,;::31..5, • 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. a , .- Was hydraulic fracturing used during completion? Yes❑ No❑ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED •. 3 P&A plugs from 5610-3687 189 bbls 15.8 Class G 2362'retainer 104 sx Class G CIBP @ 508'-cement to surface 254 sx AS I 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) plugged and abandoned 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 a 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. Form 110-407 G�vi,se t2012 1 012 V,1- g f //9 , CONTINUEDEVEI IDMS r� APR 1 0 2015 Submit original only <29. GEOLOGIC MARKERS(List all formations and mark countered): 30. • FORMATION TESTS NAME MD TVD Well tested? Yes O 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 1555' 1533' needed,and submit detailed test information per 20 AAC 25.071. K-3(Top of Coyote) 4127' 4083' Base of Coyote 4277' 4234' Top of Moraine 5149' 5105' Base of Moraine 5387' 5343' ac( .ev►,a.:L Vv./ cb uik, L3+ cC ,,e_ 1t5114 N/A Formation at total depth: Moraine 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic, photos of well head,cement reports,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Brunswick @ 263-4249 Email: Scott.A.Brunswick a(.conocophillips.com Printed Name G./L�.Alvord Title: Alaska Drilling Manager Signature ,K. Phone 265-6120 Date 3(24IL0 t+r 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 • 0 MORAINE 1 'E3° c * Name MD (feet) TVD (feet) TVDSS (feet) UGNUB 1563 1541 1499 PERMAFROST 1718 1689 1647 UGNU_A 1793 1761 1718 NA 1809 1777 1734 NB 1840 1806 1763 NC 1867 1832 1790 NF 1988 1949 1907 WEST_SAK_D 1995 1957 1914 WEST_SAK 1996 1957 1915 WEST SAK_C 2026 1987 1945 W EST_SAK_B 2053 2014 1971 W EST_SAK_A4 2081 2040 1998 WEST_SAK_A3 2099 2059 2016 W EST_SAK_A2 2181 2139 2097 W EST_SAK_A1 2301 2258 2215 WEST_SAK_BASE 2492 2448 2406 CAMP_SST 2514 2470 2428 C-35 3952 3909 3866 K-3 4127 4083 4041 TOPSET_BASE 4277 4233 4190 TOP MORAINE 5150 5107 5064 TOP MEGATURB 5250 5206 5163 BASE_MEGATURB 5256 5212 5170 BASE MORAINE 5387 5344 5301 Moraine #1 Strmanent Abandonment 11/conocoPhinips Brunswick 3/20/15 16"Conductor: Li-tircb 28 ft N9ES 16"62.6#H-40 114' MD A k Cement Laid on Top of Bridge Plug w/11 ppg ALC to Surface Cap must be a minimum of 150 ft-laid in cement to surface Bridge Plug Set @-508' — — Build to 15.97°@ 29.22°drop back to 0°by surface casing pointCement Laid on Top of Retainer w/15.8 Class G f/2,400'to 2,300' ,s,091°6 Cap above retainer must be @ least 50' Must be tested to 1500 psi minimum&24 hours notice to AOGCC Total of 3.5 bbl above retainer Surface Casing: — Cement Retainer Set @-2,362'(no less than 50'&no more than 9-5/8"40#L-80 HYD563 low above casing shoe) 2,485.21' MD/2,441'TVD @ 0° 4 k. Squeezed P&A Plug w/15.8 Class G f/2,600'to 2,400' Volume of cement must be able to fill @ least 100'below the casing shoe Total of 31 bbl squeezed below retainer P&A Plug#3w!15.8 Class G f/4,410'to 3,687'(tag depth) K-3/Top Coyote 4128'MD/4084'SSTVD Top plug must be at minimum 100'above all hydrocarbon ;a] bearing formations,&tagged with AOGCC 24 hour notice to witness Pi;;;; i; •• '•" K-3/Coyote Hydrocarbon Possible -"""'• "" """"----- • ••••••• : :::: :•:•:::::: •: :::::::::::::::::::::: ., ,.•••••:•:•:•: H ]H HHHHHM : !H!!M M;1 . .„ P&A Plug#2w!15.8 Class G f/5,010'to 4,410' Moraine Top 5150'MD 5107'SSTVD P&A Plug#1 w/15.8 Class G f!TD @ 5,610'to 5,010' 77.71 Moraine Predicted Hkain ii HM Pore Pressure:8.7 ppg . . Moraine Bottom 5387MD 5302'SSTVD Total Depth 5.610' MD @ 0° 8-1/2" Open Hole 0 • :iiii 0 Cement Detail Report MORAINE 1 Coro iihps String: Surface Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Cement 2/11/2014 23:00 2/12/2014 02:30 MORAINE 1 Comment Flood lines w/5 bbls of Fresh H2O, PT to 3,500 psi-Good. Pump 100 bbls of 10.5 ppg Mud Push II @ 5-7 bpm, Batch up while dropping bottom plug, Pump 360 bbls of 11 ppg Lead Cement @ 5-7 bpm, Batch and Pump 52 bbls of 12 ppg Tail Cement @ 5-7 bpm and Drop Top Plug,Flush with 10 bbls of Fresh H20. Displace with 171 bbls of 9.7 ppg MI Swaco DrilPlex mud @ 7 bpm @ 433 psi. Bump plug @ 2,031 stks and increase pressure to 500 psi over FCP to 933 psi, Bleed off pressure and Check floats-Good. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Cement 28.0 2,485.2 No Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 7 6 320.0 433.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 28.0 2,495.0 1,047 360.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.93 5.39 12.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,300.0 2,495.0 179 52.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.63 6.74 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 3/23/2015 • • Cement Detail Report Ofa MORAINE 1 ConocoPhillips String: Conductor Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 1/23/2015 12:00 1/23/2015 18:00 MORAINE 1 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement Cement Conductor 0.0 80.0 No 0.0 No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Surface Cement 0.0 80.0 26.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 3/23/2015 • • 0 t Cement Detail Report MORAINE 1 ConocoPhitlips String: Cement Plug Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 3/3/2015 04:00 3/4/2015 20:00 MORAINE 1 Comment Staged in 993 cuft3 abandonment plug from TD @ 5610 ft. pumped 3-840 LN ft plugs 600 ft+40%excess. G cement @ 3-5 BPM TOP of plug tagged @ 3687 ft after 14.5 hrs wait Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug 5,010.0 5,610.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 6 5 250.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa...'Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug 4,410.0 5,010.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 6 4 150.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix 1-120 Ratio(gal/sa... Free Water(%) Density(Iblgal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug 3,687.0 4,410.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 6 5 200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 3,687.0 Tubing Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 3/23/2015 • • i 0 Cement Detail Report 6 MORAINE 1 ConocoPhiillips String: Cement Squeeze Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 3/5/2015 18:00 3/5/2015 22:20 MORAINE 1 Comment Set retainer @ 2362.0 ft PT to 1500 psi for 30 mins. Est injection rate @ 3 BPM©300 psi.21 BBLs total injection away. MX&pumped 104 sxs of G cement Bull head away©3 BPM @ 100 psi.final injection pressure 100 psi. Pulled from reatiner and dumped 3 bbls above.CIP©22:20 hrs Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Squeeze 2,362.0 2,562.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 100.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 3/23/2015 • • Cement Detail Report 01% MORAINE 1 Con String: Surface plug Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface plug 3/6/2015 05:30 3/6/2015 07:30 MORAINE 1 Comment Mx&pumped 254 Sxs pf AS-1 cement from 508"to surface.Topped of well after DP displacement.TOC @ 13.5 ft from starter flage. Measured with tape measure. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface plug 13.5 508.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 500.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 3/23/2015 • NADConversion North Alaska ASP4 Moraine Moraine 1 Definitive Survey ReportNAD 27 20 March, 2015 • • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Project North Alaska ASP4 ... 41 I.RAMMVAMMEINKMAMOMIN 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 Moraine 1 Well Position +N/-S 0.00 usft Northing: 5,997,105.06 usft Latitude: 70°24'11.299 N +E/-W 0.00 usft Easting: 468,098.69 usft Longitude: 150°15'34.812 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 14.00 usft Wellbore Moraine 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/5/2015 18.79 80.92 57,566 Design Moraine 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.57 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.57 0.00 0.00 29.17 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 50.15 232.43 MWD Svy1 Inc+Trend(Moraine 1) INC+TREND Inclinometer+known azi trend 3/13/2015 11:54: 328.18 2,423.89 MWD Svy2 MWD+DMag(Moraine 1) MWD+SCC MWD+Short Collar correction 3/13/2015 11:59: 2,536.29 5,545.22 MWD Svy3 MWD(Moraine 1) MWD MWD-Standard 3/13/2015 12:14 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°)j (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 28.57 0.00 0.00 28.57 -14.00 0.00 0.00 5,997,105.06 468,098.69 0.00 0.00 UNDEFINED 50.15 0.07 15.81 50.15 7.58 0.01 0.00 5,997,105.07 468,098.69 0.32 0.01 INC+TREND(1) 108.20 0.12 55.46 108.20 65.63 0.08 0.06 5,997,105.14 468,098.75 0.14 0.10 INC+TREND(1) t,,,,,,,..- „:n; as«^ 16"x 42" , 143.12 0.16 65.13 143.12 100.55 0.12 0.14 5,997,105.18 468,098.82 0.14 0.17 INC+TREND(1) 232.43 0.60 236.09 232.43 189.86 -0.09 -0.14 5,997,104.97 468,098.55 0.85 -0.14 INC+TREND(1) 328.18 0.51 247.16 328.17 285.60 -0.53 -0.95 5,997,104.53 468,097.74 0.15 -0.93 MWD+SCC(2) 417.48 0.44 324.33 417.47 374.90 -0.41 -1.51 5,997,104.66 468,097.17 0.67 -1.09 MWD+SCC(2) 505.97 0.84 344.58 505.96 463.39 0.49 -1.88 5,997,105.56 468,096.81 0.51 -0.49 MWD+SCC(2) 599.49 1.86 8.96 599.45 556.88 2.65 -1.83 5,997,107.72 468,096.87 1.23 1.43 MWD+SCC(2) 687.75 4.25 21.88 687.58 645.01 7.10 -0.39 5,997,112.16 468,098.33 2.80 6.01 MWD+SCC(2) 779.88 4.66 25.03 779.43 736.86 13.66 2.47 5,997,118.71 468,101.21 0.52 13.13 MWD+SCC(2) 3/20/2015 2:05:26PM Page 2 COMPASS 5000.1 Build 65 SSchlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting OLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 878.30 7.03 31.61 877.33 834.76 22.42 7.32 5,997,127.44 468,106.10 2.50 23.14 MWD+SCC(2) 972.19 8.42 32.85 970.37 927.80 33.08 14.06 5,997,138.08 468,112.88 1.49 35.74 MWD+SCC(2) 1,065.74 10.98 30.60 1,062.57 1,020.00 46.51 22.31 5,997,151.47 468,121.19 2.77 51.48 MWD+SCC(2) 1,159.66 12.72 30.02 1,154.49 1,111.92 63.16 32.04 5,997,168.08 468,130.99 1.86 70.77 MWD+SCC(2) 1,254.76 14.89 31.12 1,246.84 1,204.27 82.69 43.59 5,997,187.55 468,142.63 2.30 93.45 MWD+SCC(2) 1,348.98 16.59 31.82 1,337.52 1,294.95 104.48 56.94 5,997,209.29 468,156.07 1.82 118.99 MWD+SCC(2) 1,443.23 18.60 32.79 1,427.36 1,384.79 128.56 72.18 5,997,233.29 468,171.40 2.16 147.43 MWD+SCC(2) 1,541.36 18.08 32.64 1,520.50 1,477.93 154.53 88.86 5,997,259.20 468,188.20 0.53 178.25 MWD+SCC(2) 1,632.47 17.53 33.08 1,607.25 1,564.68 177.94 103.98 5,997,282.53 468,203.41 0.62 206.05 MWD+SCC(2) 1,726.28 16.85 33.77 1,696.87 1,654.30 201.08 119.25 5,997,305.60 468,218.78 0.76 233.70 MWD+SCC(2) 1,819.99 15.26 28.04 1,786.92 1,744.35 223.26 132.60 5,997,327.72 468,232.22 2.39 259.57 MWD+SCC(2) 1,914.34 15.06 28.54 1,877.99 1,835.42 244.98 144.29 5,997,349.40 468,244.01 0.25 284.24 MWD+SCC(2) 2,007.85 11.95 25.83 1,968.90 1,926.33 264.37 154.31 5,997,368.74 468,254.11 3.39 306.06 MWD+SCC(2) 2,102.27 11.06 27.45 2,061.43 2,018.86 281.21 162.75 5,997,385.54 468,262.62 1.00 324.87 MWD+SCC(2) 2,196.45 9.62 27.24 2,154.08 2,111.51 296.22 170.52 5,997,400.52 468,270.45 1.53 341.77 MWD+SCC(2) 2,291.25 6.91 27.86 2,247.88 2,205.31 308.31 176.81 5,997,412.58 468,276.79 2.86 355.39 MWD+SCC(2) 2,384.85 3.77 32.87 2,341.06 2,298.49 315.87 181.11 5,997,420.12 468,281.13 3.39 364.09 MWD+SCC(2) 2,423.89 1.83 52.14 2,380.06 2,337.49 317.34 182.30 5,997,421.58 468,282.32 5.46 365.94 MWD+SCC(2) 2,486.80 0.89 58.47 2,442.95 2,400.38 318.21 183.51 5,997,422.45 468,283.53 1.52 367.29 MWD(3) „ `t ' ...., 9-5/8"x 12-1/4 2,536.29 0.22 104.60 2,492.44 2,449.87 318.38 183.92 5,997,422.62 468,283.95 1.52 367.65 MWD(3) 2,631.39 0.06 60.09 2,587.54 2,544.97 318.36 184.14 5,997,422.60 468,28417 0.19 367.74 MWD(3) 2,725.23 0.09 23.91 2,681.38 2,638.81 318.45 184.22 5,997,422.69 468,28424 0.06 367.85 MWD(3) 2,819.77 0.06 156.10 2,775.92 2,733.35 318.48 184.27 5,997,422.71 468,284.29 0.15 367.90 MWD(3) 2,913.81 0.09 313.33 2,869.96 2,827.39 318.48 184.23 5,997,422.72 468,284.26 0.16 367.89 MWD(3) 3,007.68 0.09 251.92 2,963.83 2,921.26 318.51 184.11 5,997,422.75 468,284.14 0.10 367.85 MWD(3) 3,101.93 0.06 325.19 3,058.08 3,015.51 318.53 184.01 5,997,422.76 468,284.04 0.10 367.82 MWD(3) 3,195.68 0.11 103.19 3,151.83 3,109.26 318.55 184.07 5,997,422.78 468,284.10 0.17 367.86 MWD(3) 3,289.79 0.06 96.32 3,245.94 3,203.37 318.52 184.21 5,997,422.76 468,284.23 0.05 367.91 MWD(3) 3,384.25 0.06 39.98 3,340.39 3,297.82 318.55 184.29 5,997,422.79 468,284.31 0.06 367.98 MWD(3) 3,572.50 0.06 311.74 3,528.64 3,486.07 318.69 184.28 5,997,422.93 468,284.31 0.04 368.09 MWD(3) 3,759.61 0.09 137.59 3,715.75 3,673.18 318.65 184.30 5,997,422.89 468,284.33 0.08 368.07 MWD(3) 3,853.81 0.09 58.52 3,809.95 3,767.38 318.63 184.42 5,997,422.87 468,284.44 0.12 368.11 MWD(3) 3,948.64 0.09 19.22 3,904.78 3,862.21 318.74 184.51 5,997,422.98 468,284.53 0.06 368.25 MWD(3) 4,042.70 0.09 63.71 3,998.84 3,956.27 318.85 184.60 5,997,423.08 468,284.62 0.07 368.38 MWD(3) 4,137.28 0.06 93.38 4,093.42 4,050.85 318.88 18471 5,997,423.11 468,284.74 0.05 368.46 MWD(3) 4,232.51 0.09 295.36 4,188.65 4,146.08 318.91 184.69 5,997,423.14 468,284.72 0.15 368.48 MWD(3) 4,326.94 0.09 71.16 4,283.08 4,240.51 318.96 184.70 5,997,423.20 468,284.73 0.18 368.53 MWD(3) 4,421.03 0.09 216.54 4,377.17 4,334.60 318.93 184.72 5,997,423.16 468,284.75 0.18 368.51 MWD(3) 4,515.67 0.06 17.18 4,471.81 4,429.24 318.91 184.69 5,997,423.15 468,284.72 0.16 368.49 MWD(3) 3/20/2015 2:05:26PM Page 3 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Ni-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,610.28 0.09 332.90 4,566.42 4,523.85 319.03 184.67 5,997,423.26 468,284.70 0.07 368.58 MWD(3) 4,704.10 0.09 151.28 4,660.24 4,617.67 319.03 184.68 5,997,423.26 468,284.70 0.19 368.58 MWD(3) 4,797.74 0.06 261.05 4,753.88 4,711.31 318.96 184.66 5,997,423.19 468,284.69 0.13 368.51 MWD(3) 4,891.66 0.06 325.28 4,847.80 4,805.23 318.99 184.59 5,997,423.22 468,284.61 0.07 368.50 MWD(3) 5,038.29 0.12 333.74 4,994.43 4,951.86 319.19 184.47 5,997,423.42 468,284.50 0.04 368.62 MWD(3) 5,087.78 0.04 141.71 5,043.92 5,001.35 319.22 184.46 5,997,423.46 468,284.49 0.32 368.64 MWD(3) 5,181.59 0.09 50.16 5,137.73 5,095.16 319.24 184.54 5,997,423.48 468,284.57 0.11 368.70 MWD(3) 5,278.18 0.04 84.51 5,234.32 5,191.75 319.30 184.63 5,997,423.53 468,284.66 0.06 368.79 MWD(3) 5,371.42 0.09 90.77 5,327.56 5,284.99 319.30 184.74 5,997,423.53 468,284.77 0.05 368.84 MWD(3) 5,466.45 0.12 334.35 5,422.59 5,380.02 319.39 184.77 5,997,423.62 468,284.80 0.19 368.94 MWD(3) 5,545.22 0.09 68.95 5,501.36 5,458.79 319.48 184.79 5,997,423.72 468,284.82 0.20 369.03 MWD(3) 5,610.00 0.09 68.95 5,566.14 5,523.57 319.52 184.89 5,997,423.75 468,284.92 0.00 369.11 PROJECTED to TD 3/20/2015 2:05:26PM Page 4 COMPASS 5000.1 Build 65 , ` • • \ k 0 3 \ a » / / c k 7 § 2 / 4- a) % / \ .0 # (i;§ $ )\}/ /\}\ \ k j y§ ff;; o k ° e �e ,�.. c z E / !a)! ' k / /$ \ % / e / /F \ / § . ® � G — % wf/ § c »\ 2 g % > . ` k k 'E / { N\ ) / 4) m O m !) EI � El 0D 3 "74-C \ ƒ / ® W W/ 2 2 CI/ ƒ / • • ConocoPhillips Time Log & Summary Weilview Web Reporting Report Well Name: MORAINE 1 Rig Name: NABORS 9ES Job Type: DRILLING ORIGINAL Rig Accept: 2/6/2015 12:00:00 PM Rig Release: 3/8/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/01/2015 24hrsummary Move rig-moved welding shope&rig office camp to location-Prep pit module&Mechanic shop for move -Moved pit&shop to location-Prep to lay over derrick -first two load on location @ 0230 hrs. -Second two loads on location @ 2230 hrs. 00:00 12:00 12.00 MIRU MOVE MOB P Moved welding shop&office camp f/ 2N to Moraine#1 -Layed herculite set camp&welding shop&set up beams-Prep pits&mechanic shop for move 12:00 00:00 12.00 MIRU MOVE MOB P Hook up truck to pits-Pull mats- clean up herculite-Move mech. shop&pit complex f/2N to Morine #1 -Prep to lay over derrick-Change out plug valves on mud manifold- Bridle down, RU on blocks-LD cattle shute. Knock out pins-Lay over derrick 02/02/2015 Move pit complex&shop to Moraine ice pad, lay over derrick, move sub of well pull matting boards and herculite, pick diverter assy.with crane, load trucks send to location, move sub off location. Install diverter and diverter line on moraine 1. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Continue moving pit complex and shop V pad, pull sub off well, Pull matting boards and herculite off well, Pick diverter and equipment from behind well, load on trucks send to Moraine 1, clean pad. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Move sub off 2N pad move to Moraine 1, Sub @ four corners. SimOps: Nipple up starting head& diverter, start laying diverter line& herculite for sub. 02/03/2015 Continue to move sub from 4 corners to DS-3F. Nipple up Diverter and lay herculite and mats for sub. 00:00 12:00 12.00 MIRU MOVE MOB P Continue to move sub to CPF 2 staged for crew change. continue to mob to Moraine pad. Sim Ops : continue to install diverter line from stack 12:00 00:00 12.00 MIRU MOVE MOB P Continue to move sub to DS-1Q,wait for CPF 2 crew change at 18:00 hrs. Continue to move sub from DS-1Q to DS-3F, stop for Doyon 141 crew change. 32/04/2015 Move rig from 3-F pad to Moraine#1 ice pad. Spot rig over well, raise the derrick and berm around the subbase.Wait on trucks to move the pit module into place. Page 1 of 18 Time Logs 4110 • Date From To Dur S. Depth E. Depth Phase Code Subcode T_ Comment 00:00 12:00 12.00 MIRU MOVE MOB P Move rig from 3-F pad to Moraine#1 ice pad. Position rig on pad so Herculite can be Layed out. 12:00 18:00 6.00 MIRU MOVE MOB P Spot rig over well/lay Herculite under subbase of rig. 18:00 00:00 6.00 MIRU MOVE WAIT T Set mats and berm around subbase while waiting on trucks to move the pit module. (trucks are busy moving 2ES and camps) 02/05/2015 Wait on trucks to spot pit module, spot pit module, lay out Herculite, set rig mats and begin rigging up Deverter riser and flow line. 00:00 04:00 4.00 0 0 MIRU MOVE WAIT T R/U while waiting on trucks to spot pit module. 04:00 12:00 8.00 0 0 MIRU MOVE MOB P Spot pit module/lay out Herculite and set mats,drag electric lines for camp and shops. 12:00 00:00 12.00 0 0 MIRU MOVE RURD P Finish berming around subbase/ repair flow line/service rig/R/U interconnect/Install riser on Diverter. 02/06/2015 Continue to rig up equipment.Take on spud mud. Rig accepted @ 12:00. Function test the diverter, witnessed by Jeff Jones AOGCC. Diverter line was packed off with snow. R/D diverter line, clear and clean packed snow. R/U diverter line and start picking up 5"DP. 00:00 12:00 12.00 0 0 MIRU MOVE RURD P Continue to rig up equipment. Take on spud mud. Rig accepted @ 12:00 hrs. 12:00 15:00 3.00 0 0 MIRU MOVE RURD P Test gas alarms and PVT sensors prior to calling state. Notify State of ready to test, Continue Rigging up, load and strap pipe in shed. 15:00 17:00 2.00 0 0 MIRU MOVE BOPE P Test PVT's, gas alarms and diverter valve.Test Koomey: Koomey pressure 2960 psi/function diverter bag/closing pressure 2100 psi/36 secs to 200 psi/120 secs full charge/6 NO2 bottles/Average charge 1975 psi. Diverter line failed test due to packed in line. 17:00 23:00 6.00 0 0 MIRU MOVE RURD T R/D diverter line and load line sections into the pipe shed and clear packed snow. Took pictures of the clear and clean diverter lines and diverter valve. R/U the diverter line sections and sent pictures to Jeff Jones @ AOGCC. 23:00 00:00 1.00 0 0 MIRU MOVE PULD P P/U 5" DP and stand it back in the derrick. 32/07/2015 Continue pcking up 5" DP and BHA#1. Fluid test equipment and drill 12 1/4"surface hole to 282', POOH 4 L/D BHA, M/U BHA#2 00:00 06:30 6.50 0 0 MIRU MOVE PULD P Continue P/U 5" DP Standing back in the derrick, P/U 5" HWDP stand back in the derrick. 25 Stands of DP 7 stands of HWDP 06:30 07:00 0.50 0 0 MIRU MOVE SVRG P Service top drive and crown,grease and inspect drawworks. page 2of18 Time Logs 4110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:30 3.50 0 0 MIRU MOVE BHAH P P/U BHA components to rig floor, prep BHA in pipe shed, adjust blower hose on top drive. 10:30 12:00 1.50 0 0 MIRU MOVE BHAH P P/U Dumb iron BHA#1 as per DD 12:00 15:00 3.00 0 0 MIRU MOVE RURD P Fluid test all equipment and Est SPP, Torque, prior to drilling out conductor shoe. 15:00 19:00 4.00 0 282 SURFA( DRILL DDRL P Drill 12 1/4"surface hole f/85' t/282'.WOB 5-10 K/GPM 350-420/ PSI ON 260/PSI OFF 235/RPM 40-60/TQ ON 1.1 K/PUW51 K/ SOW 50 K/RTW 50 K. 19:00 21:00 2.00 282 0 SURFA( DRILL BHAH P POOH and L/D BHA#1 (dumb iron) 21:00 00:00 3.00 0 0 SURFA( DRILL BHAH P P/U Directional BHA#2 02/08/2015 P/U Directional 12 1/4"Surface hole BHA#2. Drill from 282'to 1894'. 00:00 03:00 3.00 0 154 SURFA( DRILL BHAH T P/U the 4 1/2"OD Source shield, Pony collar ID 3 1/2". L/D the Pony collar/loaded the Source through the X-O into the SABN tool. 03:00 05:00 2.00 154 282 SURFA( DRILL BHAH P P/U Pony collar and continue to P/U the 12 1/4"Directional BHA#2. 05:00 12:00 7.00 282 857 SURFA( DRILL DDRL P Drill f/282't/857'/TVD 757'/WOB 12 K/GPM 600/PSI ON 1491 /PSI OFF 1390/PUW94 K/SOW/82 K /RWT 84 K/ART 3.93 hrs/ADT 5.68 hrs/AST 1.75 hrs/BIT 5.68 hrs/JARS 5.68 hrs/Mud wt 9.6 ppg. 12:00 00:00 12.00 857 1,894 SURFA( DRILL DDRL P Drill f/857't/1894'/TVD 1733'/WOB 5-20 K/GPM 600/PSI ON 1550/ PSI OFF 1515/RPM 60/TQ ON 4-8K/TQ OFF 3-6 K/PUW 115 K/ SOW 100 K/RWT 105 K/ART 2.15 hrs/ADT 6.08 hrs/AST 5.21 hrs/ BIT 11.29 hrs/JARS 11.29 hrs/ Mud wt 9.6/ECD's 10.3-10.6. 02/09/2015 Drill form 1,894'to 2,495', circulate and condition mud, back ream out of the hole and L/D BHA#2. 00:00 09:00 9.00 1,894 2,495 SURFA( DRILL DDRL P Drill from 1894'to 2495'TD/2418' TVD/WOB 10-20 K/GPM 600/ PSI on 1675/PSI off 1570/RPM 60 /TQ on 6 k/TQ off 4 k/PUW 130 k /SOW 115 K/RWT 120 K/ART 9,98 hrs/ADT 6.57 hrs/AST 2.67 hrs/Bit 17.86 hrs/Jars 17.86 hrs/ Mud wt 9.8 ppg. 09:00 10:30 1.50 2,495 2,495 SURFA( CASING CIRC P Circulate until shakers clean up/ GPM 600/1670 psi/PUW130K/ SOW 115K/RWT120K/RPM 60. _ Monitor well/Static. 10:30 12:00 1.50 2,495 1,900 SURFA( CASING BKRM P Back ream from 2495'to 1900'/ GPM 550/1265 psi/RPM 60/ PUW110K/SOW 98K/RWT105 K. Page 3 of 18 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 17:30 5.50 '1,900 900 SURFA( CASING BKRM P Back ream out of the hole to HWDP 1,900'to 900'. 17:30 19:00 1.50 900 280 SURFA( CASING TRIP P POOH/7 stands of 5"HWDP. 19:00 00:00 5.00 280 0 SURFA( CASING BHAH P L/D 12 1/4"BHA#2 02/10/2015 Run 9 5/"casing to 673', repair Top Drive, run casing to 2495', circulate and condition mud for cement job. 00:00 05:00 5.00 0 0 SURFA( CASING RURD P R/U casing tools to run 9 5/8"L-80 40#casing. 05:00 08:30 3.50 0 673 SURFA( CASING PUTB P Run 9 5/8"L-80,40#, Hydril 563 casing to 673'. 08:30 12:00 3.50 673 673 SURFA( CASING RGRP T Change out wash pipe on TD. 12:00 22:30 10.50 673 2,392 SURFA( CASING PUTB P Run 9 5/8"casing from 673'to 2,392'.Tight spot at 1,294', Pick up and rotate and work through tight spot. Continue running in the hole. 22:30 00:00 1.50 2,392 2,392 SURFA( CASING PUTB T Work casing through tight or hard spot at 2,392'. Slowly rotate at 3 bpm 160 psi. Slowly increase pump pressure to 4 bpm while watching returns. 02/11/2015 Work 9 5/8"casing past ledge or hard spot. Circulate and condition mud and R/D casing running tools. Condition mud and begin casing cement job. 00:00 12:00 12.00 2,394 2,395 SURFA( CASING PUTB T Work 9 5/8"casing past ledge or hard spot from 2,392'to 2,394'. PUW 130K/SOW 100K/94 psi/5 BPM. 12:00 16:30 4.50 2,395 2,495 SURFA( CASING PUTB T Continue to work 9 5/8"casing past ledge or hard spot,from 2,394'to 2,395'.Worked casing past ledge 2,395'to 2,495'. PUW 125k/SOW 100K. 16:30 18:30 2.00 2,495 2,495 SURFA( CEMEN'CIRC P Circulate and condition mud, reciprocate casing form 2,495 to 2,465'pump 6 bpm at 115 psi. 18:30 20:30 2.00 2,495 2,495 SURFA( CEMEN-RURD P R/D Volant tool, long bails and casing equipment. 20:30 23:00 2.50 2,485 2,485 SURFA( CEMEN'CIRC P Condition mud ,YP<20 lb/100 before cementing. Reciprocate casing while conditioning mud. 23:00 00:00 1.00 2,485 2,485 SURFA( CEMEN CMNT P Begin cement job/Pump 5 bbls of water through cement lines and test to 3000 psi/Pump 100 bbls of MudPush II. 02/12/2015 Cement 9 5/8"surface casing, R/D cementing equipment, N/D diverter system and install FMC wellhead. Tag surface cement 29"below top of conductor,just below 4"conductor outlets. Page 4 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 2,485 2,485 SURFA( CEMEN-CMNT P Flood lines w/5 bbls of Fresh H2O, PT to 3,500 psi-Good. Pump 100 bbls of 10.5 ppg Mud Push II @ 5-7 bpm, Batch up while dropping bottom plug, Pump 360 bbls of 11 ppg Lead Cement @ 5-7 bpm, Batch and Pump 52 bbls of 12 ppg Tail Cement @ 5-7 bpm and Drop Top Plug, Flush with 10 bbls of Fresh H2O. Displace with 171 bbls of 9.7 ppg MI Swaco DrilPlex mud @ 7 bpm @ 433 psi. Bump plug @ 2,031 stks and increase pressure to 500 psi over FCP to 933 psi, Bleed off pressure and Check floats-Good. 02:30 08:30 6.00 2,485 2,485 SURFA( CEMEN-RURD P R/D cementers, all cement equipment, pull landing joint, flush Diverter and riser and clean up rig floor and cellar. 08:30 20:00 11.50 2,485 2,485 SURFA(WHDBO NUND P N/D Diverter system,diverter line, riser and diverter. 20:00 00:00 4.00 2,485 2,485 SURFA( WHDBO NUND P Remove adapter flange and install FMC wellhead. Top of surface casing cement is 29"below the top of the conductor,just below the 4'outlets. 02/13/2015 Nipple up 13 5/8" BOP stack and test, Rig down test equipment. 00:00 09:00 9.00 0 0 SURFA( WHDBO NUND P N/U BOPE/change out top VBR's to 2 7/8"X 5"and open doors on lower VBR's to veryify correct size. Cut down flow nipple to install under rotary. 09:00 10:00 1.00 0 0 SURFA( WHDBO BOPE P Body test BOP's,door hinge on top ram leaking hydraulic fluid. 10:00 14:00 4.00 0 0 SURFA( WHDBO RGRP T Repair ram door hydraulic fluid leak. 14:00 20:00 6.00 0 0 SURFA( WHDBO BOPE P Test BOPE/test Annular preventer, upper and lower rams, blinds, kill line valves, choke line valves, Super choke, and choke manifold to/250 psi low-3500 psi high. 1 fail/pass, upper VBR's would not hold pressure. Perform AOGCC Koomey test-Good. Perform CPAI Koomey draw down test/close Koomey bottle valve/close rams and HCR valve/start air pumps-2 min 53 secs to 2500 psi. Close rams and HCR valve/start electric pump-1 minute 2500 psi. 20:00 21:30 1.50 0 0 SURFA( WHDBO RGRP P Change upper VBR's 21:30 23:30 2.00 0 0 SURFA(WHDBO BOPE T Finsish testing BOPE/upper rams, test spool, and IA-250 psi low/3500 psi high. 23:30 00:00 0.50 0 0 SURFA(WHDBO SEQP P R/D test epuipment. Page 5 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/14/2015 24 hr Summary Continue to P/U 5"DP, slip and cut the drilling line and service the rig. P/U 8 1/2"BHA#3, P/U 24 joints of 5" DP and TIH to 2,287'. 00:00 01:00 1.00 0 0 SURFA( WHDBO RURD P R/D BOP test equipment, pull test plug and set ware bushing. 01:00 05:00 4.00 0 0 SURFA( CEMEN'OTHR T Thaw ice plug in Kelly hose. 05:00 07:00 2.00 0 0 SURFA( CEMEN-PRTS P PJSM, PT 9-5/8,40#, L-80 to 3,100 psi for 30 minutes with MP#1 -lost 50 psi-(Good Test). RD and BD test equipment 07:00 08:00 1.00 0 60 SURFA( CEMEN-SEQP T PU and RIH w/5"NC-50 mule shoe joint-29.67-ft, 1 jt of 5"DP. Fill lines and circulate. Close IBOP and RU test equipment-PT kelly hose to 5,000 psi for 5 minutes-good test. Blow down test equipment 08:00 08:30 0.50 60 120 SURFA( CEMEN PULD P PU 2 jts and RIH to 120-ft-had hose failure on Iron Roughneck 08:30 09:00 0.50 120 120 SURFA( CEMEN RURD T Pull hose, secure lines. Replace and Repair. 09:00 13:00 4.00 120 1,913 SURFA( CEMEN-PULD P Continue to RIH w/5"DP while using manual tongs until hose was replaced on Iron Roughneck. Continue to RIH to 1,913-ft(60 jts) 13:00 14:30 1.50 1,913 1,913 SURFA( CEMEN-SLPC P PJSM, Slip and Cut 63-ft of 1-1/8" Drill line, inspect and service draw works, Brake bands and dead man bracket. 14:30 15:00 0.50 1,913 1,913 SURFA( CEMEN-SVRG P PJSM, Service Top Drive unit and check crown. 15:00 16:00 1.00 1,913 0 SURFA( CEMEN-TRIPP POOH standing back 5"DP, laydown 5"Mule shoe 16:00 20:00 4.00 0 810 SURFA( CEMEN'BHAH P PU, MU and RIH w/8-1/2" PDC Drlg BHA#1 20:00 21:00 1.00 810 1,564 SURFA( CEMEN-PULD P P/U 24 joints of 5" DP 810'to 1,564' 21:00 23:00 2.00 1,564 1,564 SURFA( CEMEN-DHEQ P MWD shallow hole pulse test. 23:00 00:00 1.00 1,564 2,287 SURFA( CEMEN-TRIP P Run in the hole to 2,287' 32/15/2015 Run in the hole tag cement at 2,396'. Drill out float collar and shoe track to 2,485'. Drill 20'of new hole 2,515' and perform FIT/LOT. Displace Drilplex mud with KlaShield mud and wash and clean pits and mud system. Drill from 2,515'to 3,515'. 00:00 01:00 1.00 2,287 2,396 SURFA( CEMEN-TRIP P Run in the hole tag cement at 2,396'. 01:00 01:30 0.50 2,396 2,402 SURFA( CEMEN"COCF P Clean out cement to float collar _ 2,402'. 01:30 03:30 2.00 2,402 2,515 SURFA( CEMEN DDRL P Drill out float shoe,shoe track and _ 20'of new hole to 2,515'. 03:30 05:30 2.00 2,515 2,413 SURFA( CEMEN CIRC P Circulate B/U/500 GPM/PUW 110K/SOW 90k. Pull into the casing for FIT/LOT. 05:30 06:00 0.50 2,413 2,413 SURFA( CEMEN-FIT P Perform FIT/LOT/pressure formation _ to 815 psi, EMW 16.0 ppg. 06:00 07:00 1.00 2,413 2,515 PROD1 DRILL DISP P Run back to bottom and displace Drilplex surface fluid with KlaShield drilling fluid. Page 6 of 18 Time Logs 4111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:30 3.50 2,515 2,515 PROD1 1DRILL OTHR P Wash,clean and ready pits and mud system for KlaShield drilling fluid. 10:30 18:00 7.50 2,515 3,218 PROD1 DRILL DDRL P Drill 2,515'to 3,218'/WOB 5K-10K/ GPM 500/PSI ON 1400, OFF 11250 /RPM 120/TQ ON 5.3K, OFF 3.4K/PUW 140K/SOW 120K /RTW 122K/ART 4,24 hrs/ADT 4.24 hrs/BIT 6.66 hrs/Jars 6.66 hrs. SPR's taken at 13:30 hrs/MD 3017' /TVD 3027'. Pump#1 @ 2 bpm 100 psi, 3 bpm 140 psi. Pump#2 @ 2 bpm 100 psi, 3 bpm 140 psi. Mud wt 9.5//ECD 10.4 ppg. 18:00 00:00 6.00 3,218 3,513 PROD1 DRILL DDRL P Drill 3,218"to 3,513'/WOB 5K/ GPM 562/PSI ON 1535, OFF 1521 /RPM 120/TQ ON 6.2K, OFF 5.4K /PUW 148K/SOW 119K/RTW 127K/ART 4,39 hrs/ADT 4.39 hrs/ BIT 10.51 hrs/Jars 10.51 hrs.. Mud wt 9.4//ECD 10.62 ppg. 32/16/2015 Drill 8 1/2"intermediate hole from 3,513'to 4,810'. 00:00 12:00 12.00 3,513 4,202 PROD1 DRILL DDRL P Drill 3,513'to 4,202'/WOB 5K/ GPM 569/PSI ON 1655 , OFF 1642 /RPM 120/TQ ON 7K, OFF 6K/ PUW 170K/SOW 130K/RTW 140K/ART 9.8hrs/ADT 9.8 hrs/ BIT 20.32 hrs/Jars 20.32 hrs.. Mud wt 9.6//ECD 10.98 ppg. SPR's take at 08:00 hrs, MD 3936', TVD 3936'. Pump#1 @ 2 bpm 140 psi, 3 bpm 190 psi. Pump#2 @ 2 bpm 140 psi, 3 bpm 190 psi. Connection gas at 3700', bring mud wt up from 9.4 to 9.6 ppg. 12:00 00:00 12.00 4,202 4,810 PROD1 DRILL DDRL P Drill 4,202'to 4,810'/WOB 5K/ GPM 565/PSI ON 1800 , OFF 1740 /RPM 120/TQ ON 9.4K, OFF 7.8K /PUW 184K/SOW 1137K/RTW 149K/ART 4.8hrs/ADT 4.58 hrs/ BIT 29.8 hrs/Jars 29.8 hrs.. Mud wt 9.6//ECD 11.0 ppg. SPR's take at 17:30 hrs, MD 4484',TVD 4432'. Pump#1 @ 2 bpm 130 psi, 3 bpm 180 psi. Pump#2 @ 2 bpm 130 psi, 3 bpm 180 psi. Pump a Hi-Vis sweep every 3-400'. 02/17/2015 Drilled 8 1/2"hole to 5100' MD(Core point)-Circ 3 X btms up-Flow ck(static)POOH-LD BHA-RU&Test BOPE Time Logs i 411 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:30 6.50 4,810 5,100 PROD1 DRILL DDRL P Drilled 8 1/2" hole w/RSS f 4810'to 5100' MD 5056'TVD ADT-5.64 hrs. Footage-290' ECD- 10.92 ppg WOB 5 k RPM 120 GPM 654 @ 1810 psi String wt. PU 195 SO 140 ROT 160 Torque on/off btm.-9/8.5 k ft/lbs SPR's@5100' #1 2 bbls/min @ 130 psi 3 bbls/min @ 170 psi #2 2 bbls/min @ 130 psi 3 bbls/min @ 170 psi 06:30 08:30 2.00 5,100 5,049 PROD1 CORING CIRC P Circ 3 X btms up @ 564 gpm @ 1833 psi w/120 rpm-PU wt 190 SO wt 140 ROT wt 155-Stood back 1 std DP to 5049'-Blow down TD-Flow ck 15 mins-Well static 08:30 12:00 3.50 5,049 2,413 PROD1 CORING TRIP P POOH on elevators f/5049'to 2413'- Observed 15 k over pull @ 4242', 4173'&4159'-Worked pipe thru each spot to clean up-Calc fill 23.4 bbls-Actual fill 25.6 bbls 12:00 14:00 2.00 2,413 810 PROD1 CORING TRIP P Continue POOH on elevators f/2413' to 810' (top of HWDP)flow ck 10 min. (well static) 14:00 16:00 2.00 810 0 PROD1 CORING BHAH P Stood back HWDP&Jars-LD BHA -NM DC's 16:00 17:30 1.50 0 0 PROD1 WHDBO RURD P Pull wear bushing-Set test plug 17:30 19:00 1.50 0 0 PROD1 WHDBO RURD P RU to test BOPe-fill stack&choke manifold w/water 19:00 00:00 5.00 0 0 PROD1 WHDBO BOPE P Tested BOPE-Tested annular to 250&2500 psi-Tested upper& lower VBR to 250&3500 psi- Tested choke manifold valves, choke &kill line valves, Floor safety&dart valves, TD IBOP's-4" Demco valve on kill line,Tested blind rams to 250 &3500 psi-Performed accumulator recovery test-Beginning pressure 2900 psi-Functioned rams- 1700 psi-Turned on electric pump gained 200 psi in 33 secs. back to full charge in 145 secs. -N2 bottles Average pressure 1935 psi 32/18/2015 Cont. MU coring assembly RIH to 2485'Circ-Take on coring fliud-RIH to 5100'-Change over to coring fluid -Circ&add Deuterium to mud system Page 8 r` Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 PROD1 WHDBO RURD P Blow down TD, choke&kill lines- Pull test plug-Set wear bushing(9 7/8"ID 10 3/4"OD 3.16' long) LD 5" test jt.-clean up rig floor Cleaning pits 03:00 03:30 0.50 0 0 PROD1 CORING SFTY P PJSM w/rig crew&Baker core hands on making up coring assembly 03:30 07:00 3.50 0 929 PROD1 CORING BHAH P MU coring BHA-bit-6 outter barrels w/stabilzersl LDA,stab,top sub, float sub,XO, 3(6 1/4"DC's)-3 jts 5'HWDP-Jars-17 jts 5" HWDP to 928.92' Cleaning pits 07:00 09:00 2.00 929 2,485 PROD1 CORING TRIP P RIH w/coring BHA f/928.92'to 2485' -PUwt120 SOwt100 Cleaning pits 09:00 12:00 3.00 2,485 2,485 PROD1 CORING CIRC P Circ&condition mud @ 9 5/8"shoe @ 200 gpm @ 240 psi(finish cleaning pits to take on coring fluid) 12:00 16:00 4.00 2,485 5,100 PROD1 CORING TRIP P RIH f/2485'to 5100' -Washed down f/4979'to 5100'@ 288 gpm @ 476 psi 16:00 17:00 1.00 5,100 5,100 PROD1 CORING CIRC P Circ btms up @ 288 gpm @ 475 psi w/40 rpm @ 8. k torque-PU wt 195 SO wt 146 17:00 19:00 2.00 5,100 5,100 PROD1 CORING DISP P Displaced well f/9.6 ppg Kla-Shield mud to 9.6 ppg Low invasion coring fluid @ 209 gpm @ 647 psi w/40 rpm w/8.1 k torque-PU wt 197 SO wt 146 ROT wt 161 19:00 00:00 5.00 5,100 5,100 PROD1 CORING CIRC P Circ and add Deuterium tracer to coring fluid as per Weatherford-Circ 3 X mud volume(820 bbls)to blend tracer throughout system-Pumping @ 300 gpm @ 840 psi 32/19/2015 Finish circ to blend in Deuterium throughout mud system-Drop ball-pump down to seat-Obtain SPR's- Cutting core#1 f/5100'to 5171' 00:00 03:00 3.00 5,100 5,100 PROD1 CORING CIRC P Cont. Circ to blend tracer into mud system @ 300 gpm @ 833 psi w/40 rpm's w/7.7 k torque-PU wt 195 SO wt 145 ROT wt. 161 -Dropped ball&made connection-pumped ball down to seat Page 9 of 18 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 12:00 9.00 5,100 5,127 PROD1 CORING CORE P Cut core#1 f/5100'to 5127' MD ADT 9 hrs. Footage-27' WOB 20 k RPM 70 GPM 300 @ 1500 psi String wt-PU wt 200 SO wt 170 ROT wt 165 Torque 7 k SPR'@ 5100'@ 0300 hrs #1 2 bbls/min @ 480 psi 3 bbls/min @ 600 psi #2 2 bbls/min @ 470 psi 3 bbls/min @ 610 psi 12:00 00:00 12.00 5,127 5,171 PROD1 CORING CORE P Cut core#1 f/5127'to 5171' MD ADT-12 hrs Footage-44' WOB 25 k RPM 90 GPM 295 @ 1440 psi String wt-ROT wt 135 X2/20/2015 Cut core#1 f/5171'to 5174'(barrel jamed)POOH w/core# 1 following trip speed schedule-LD top 3 inner barrels-Ran GR on lower 3 inner bbls- Est. recovery 72'(to be confirmed) 00:00 03:00 3.00 5,171 5,174 PROD1 CORING CORE P Cut core#1 f/5171'to 5174' MD ADT-3 hrs. Footage 3' WOB 25 k RPM 90 GPM 295 @ 1340 psi Srting wt. ROT wt. 165 Torque-8 k 03:00 06:00 3.00 5,174 3,189 PROD1 CORING TRIP P POOH w/pump f/5174'to 5137'-LD 1 single DP f/5137'to 5105'-POOH on TT f/5105'to 4885'-Flow ck 10 mins-Well static-CONt. POOH on TT f/4885'to 3189'@ 6 mins/std- PU wt 190 SO wt 145 -Calc fill 11.7 bbls-Actual fill 13.1 bbls 06:00 07:30 1.50 3,189 2,437 PROD1 CORING TRIP P Cont POOH on TT f/3189'to 2437'- PUwt146 SOwt116 07:30 08:00 0.50 2,437 2,437 PROD1 CORING OWFF P Monitor well 30 mins. -Well static 08:00 11:30 3.50 2,437 929 PROD1 CORING TRIP P POOH on TT f/2437'to 2000'@ 6 mins/std-PU wt 123 SO wt 102- POOH on TT f/2000'to 929'@ 15 _mins/std-PUwt81 SOwt81 11:30 12:00 0.50 929 929 PROD1 CORING OWFF P Monitor well @ top of BHA-well static 12:00 17:30 5.50 929 286 PROD1 CORING TRIP P POOH f/929'to 286'@ 30 mins/std- Stan back HWDP&Jars 17:30 18:00 0.50 286 286 PROD1 CORING OWFF P Stop&wait 30 mins as per trip schedule-Monitor well-Static 18:00 18:30 0.50 286 195 PROD1 CORING TRIP P POOH&Std back DC's to 195'(top _of core bbls) 18:30 19:00 0.50 195 195 PROD1 CORING SFTY P PJSm on laying down core barrels 19:00 21:00 2.00 195 195 PROD1 CORING BHAH P Pull&lay down 3 top inner barrels w/ no core inside Page 10 of 18 Time Logs 110 4110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:30 2.50 195 195 PROD1 CORING BHAH P MU TIW valve below core bbls lift sub for well control-Ran tape down inner bbls to 20'to top of core-Est core in inner bbls 72'-RU&ran Gamma Trak II while pulling inner bbls up 90'- Lower inner bbls back into outter bbls-RD Gamma Trak-PU core shuttle and set in mouse hole 23:30 00:00 0.50 195 195 PROD1 CORING BHAH P PJSM on laying down inner bbls w/ core inside 02/21/2015 Finish LD core#1 -MU core assembly#2-RIH to 2485'-Service rig-RIH 5071'-Wash down f/5071'to 5174'-Circ btms up-Drop ball-Cut core#2 f/5174'to 5220' 00:00 02:00 2.00 195 0 PROD1 CORING BHAH P LD core#1 -3 inner bbls-Pulled& stood back 1 std outter core bbls- Pull 2nd stand of outter core bbls- Break bit 02:00 02:30 0.50 0 0 PROD1 CORING SFTY P PJSM on MU BHA#2 02:30 06:00 3.50 0 989 PROD1 CORING BHAH P MU core bit#2( BHC 506C)-RIH w/1st std outter bbls-RIH w/2nd std outter bbls f/derrick-PU two outter bbls f/pipe shed-PU &MU 8 -inner bbls-MU top sub&float sub to 240'-RIH w/1 std DC's,jars&20 jts 5" HWDP to 988.92'-PU wt 80 SO wt 78 Note: Began processing core#1 in pipe shed for transport to Anchorage after all inner bbls were picked up f/ pipe shed 06:00 07:30 1.50 989 2,434 PROD1 CORING TRIP P PU 1 single 5" DP f/shed-to 1020.42'-RIH w/core assembly#2 f/1020.42'w/5" DP f/derrick to 2434' -PU wt 115 SO wt 95 07:30 08:00 0.50 2,434 2,434 PROD1 CORING CIRC P Fill pipe&break circ-stage pump up to 200 gpm @ 455 psi-Blow down TD 08:00 08:30 0.50 2,434 2,434 PROD1 CORING SVRG P Service rig-TD, DW, Crown, &block 08:30 11:00 2.50 2,434 5,071 PROD1 CORING TRIP P RIH f/2434'to 5071'-Filled pipe @ 4317'-PU wt 170 Sowt130 11:00 11:30 0.50 5,071 5,165 PROD1 CORING WASH P Establish circ&stage pump up to 300 gpm @ 950 psi-Wash down f/ 5071'to 5165' 11:30 13:30 2.00 5,165 5,165 PROD1 CORING CIRC P Circ btms up @ 5165'@ 300 gpm @ 950 psi w/40 rpm's 8 k torque-PU wt 175 SO wt 140 ROT wt 155 Obtain SPR's @ 5165'w/9.7 ppg mud wt #1 2 bbl/min @ 690 psi 3 bbls/min @ 890 psi #2 2 bbls/min @ 680 psi 3 bbls/min @ 880 psi 13:30 14:00 0.50 5,165 5,174 PROD1 CORING WASH P Made connection-Dropped ball- Washed down f/5165 to 5174' Page 11 of 18 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 00:00 10.00 5,174 5,220 PROD1 CORING CORE P Cut core#2 f/5174'to 5220' MD ADT 10 hrs Footage-46' WOB 15 k RPM 70 GPM 300 @ 1600 psi String wt Rot 160 Torque 8 k 32/22/2015 Cut core#2 f/5220'to 5261'MD(barrel jammed)-POOH w/core#2 as pre trip schedule-Stand back HWDP , Jars&DC's-LD 5 inner bbls w/no core-Ran Gamma Trak III on remaining 3 inner bbls-LD top inner bbls w/core 00:00 13:30 13.50 5,220 5,261 PROD1 CORING•CORE P Cut core#2 f/5220'to 5261'MD ADT-13.5 hrs Footage-41' WOB 15 k RPM 70 GPM 300 @ 1490 psi String wt. PU 190 SO 150 ROT 160 Torque 7.5 k Barrel jammed @ 5261' 13:30 18:00 4.50 5,261 1,020 PROD1 CORING TRIP T POOH w/core#2 f/5261'to 1020'- as per trip schedule-monitor well @ 9 5/8"shoe(static)PU wt 119 SO wt 103 18:00 21:00 3.00 1,020 284 PROD1 CORING BHAH T POOH w/BHA stand back 5" HWDP,jars,&DC's to 284'-monitor well @!500'&284'-well static 21:00 00:00 3.00 284 284 PROD1 CORING BHAH T LD 5 inner core barrels w/no core- Pull btm 3 inner core barrels&ran Gamma Trak III-LD 1 inner core barrel w/core 32/23/2015 LD core#2-MU core assembly#3-RIH w/Coring assembly to 898'-Wait on weather-Cont. RIH to 2344' -Circ btms up-FLow ck(static)Slip&cut drill line-service rig-Set storm packer-RU&test BOPE-Pull storm packer-RIH w/core assembly#3 f/2344' 00:00 02:00 2.00 284 0 PROD1 CORING BHAH P Finsh LD core#2-LD 3 outter barrel to pipe shed-Pull&set 1 outter barrel in mouse hole-Pull 1 std outter barrels&inspect bit 02:00 04:30 2.50 0 898 PROD1 CORING BHAH P MU Coreing assembly#3-RIH w/std of outter barrels-PU bbl f/ mouse hole& 1 bbl f/pipe shed to 164'-PU&RI w/5 inner barrels- RIH w/DC's HWDP&jars to 898' 04:30 05:30 1.00 898 898 PROD1 CORING WAIT T Phase 3 weather called-monitor well on TT-Weather condition upgraded to Phase 2 05:30 06:30 1.00 898 2,344 PROD1 CORING TRIP P RIH w/coring assembly#3 f/898'to 930'(picked up 1 single 5" DP on top of HWDP)RIH f/930'w/DP f/ derrick to 2344'-PU wt 110 SO wt 95 06:30 08:00 1.50 2,344 2,344 PROD1 CORING CIRC P Circ btms up @ 210 gpm @ 335 psi -PUwt110 SOwt95-Blow down TD-Monitor well for 10 mins-static 08:00 09:30 1.50 2,344 2,344 PROD1 CORING SLPC P Slip&cut drill line 63'-Check& reset crown saver-Calibrate block height 09:30 10:00 0.50 2,344 2,344 PROD1 CORING SVRG P Service blocks, DW's, TD&crown Page 12 of 18 Time Logs i' • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 13:00 3.00 2,344 2,344 PROD1 CORING CIRC P Circ&cond. mud @ 210 gpm @ 335 psi-PUwt117 SOwt100 13:00 14:30 1.50 2,344 2,344 PROD1 CORING PACK P PU Baker 9 5/8"storm packer-RIH &set @!37.5'-test packer to 500 psi-LD setting tool-blow down kill line 14:30 16:00 1.50 2,344 2,344 PROD1 WHDBO RURD P Pull wear bushing-set test plug- RU test equipment-Fill stack& choke manifold w/water 16:00 20:00 4.00 2,344 2,344 PROD1 WHDBO BOPE P Tested BOPE w/5"test jt-Testede annular to 250&2500 psi-Tested upper&lower pipe rams, choke manifold valves, choke&kill line valves,TD IBOP's, floor safety&dart valves, Upper kill line valve,test spool valves to 250&3500 psi, Tested blind rams to 250&3500 psi, tested Super&manual chokes for pressure-Performed accumulator recovery testlnital pressure 2950 psi -functioned rams,annular, HRC's- pressure 1650 psi-turn on electric pump 200 psi in 33 secs. opened valve for air pumps back to full charge in 154 secs. -N@ 2100 psi - Witnessing of test waived by Bob Noble AOGCC 20:00 21:00 1.00 2,344 2,344 PROD1 WHDBO RURD P RD test equipment-Pull test plug set wearbushing-Blow down lines 21:00 22:00 1.00 2,344 2,344 PROD1 CORING MPSP P MU packer runing&retrieving tool- engage packer&release packe- Pull out&LD running tool&packer 22:00 00:00 2.00 2,344 3,855 PROD1 CORING TRIP P RIOH w/coring assembly#3 f/2344' to 3855-PU wt 168 SO wt. 125 02/24/2015 Cut core#3 to 5306'. POOH to 904'with core BHA. 00:00 01:00 1.00 3,855 5,075 PROD1 CORING TRIP P Continue to RIH with BHA#5. Up Wt= 175K Down Wt.= 145K. 01:00 02:30 1.50 5,075 5,261 PROD1 CORING REAM P Reamed from 5075'to 5261'@ 300 GPM @ 765 psi. RPM @ 40 W/8K torque Circulated bottoms up. @ 275 BPM @ 647 psi. Dropped ball. Pressure increase to 1000 psi @ 275 GPM. 02:30 06:00 3.50 5,261 5,277 PROD1 CORING CORE P Coring from 5261'to 5277'as per Baker. @ 275 GPM @ 1130 psi @ 60 RPM's W/7-8 K Torque W/10- 12 K WOB. MW=9.7#. 06:00 12:00 6.00 5,277 5,298 PROD1 CORING CORE P Continue coring ops. from 5277'to 5298'as per Baker. @ 275 GPM @ 1080 psi. @ 60 RPM's @ 7-8 K Torque.W/12-15 K WOB. 12:00 16:00 4.00 5,298 5,305 PROD1 CORING CORE P Continue coring operation 5298'to 5305'@ 271 GPM @ 1055 psi. RPM's @ 61 @ 7 K torque.WOB= 15K. Broke core. Page 13 of 18 Time Logs 410 S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 00:00 8.00 5,305 906 PROD1 CORING TRIP P TOOH with BHA#5 as per trip schedule. 5300 to 2500'@ 3 Min's per std. 2500 to1000 ft @ 15 per std. 02/25/2015 POOH with core assembly. RIH with drilling assembly. Began drilling rat hole to 5350 ft. 00:00 02:30 2.50 906 535 PROD1 CORING TRIP P Continue to POOH with BHA#5. 1000 ft to 500 ft @ 15 min's per std. 02:30 03:00 0.50 535 535 PROD1 CORING OWFF P Monitor well for 30 min's. 03:00 05:00 2.00 535 201 PROD1 CORING TRIP P Continue to POOH with BHA# @ 20 min's per std. 05:00 05:30 0.50 201 201 PROD1 CORING OWFF P Monitor well for flow. 05:30 09:30 4.00 201 0 PROD1 CORING BHAH P Laid down BHA&core 09:30 11:00 1.50 0 PROD1 CORING RURD P RD Coring equiipment and clear rig floor. 11:00 14:30 3.50 0 PROD1 CORING BHAH P Picked up BHA#6 Drilling assemblt 14:30 16:30 2.00 2,485 PROD1 CORING TRIP P Trip in hole to shoe. 16:30 17:30 1.00 2,458 2,485 PROD1 CORING CIRC P Circulate bottoms up to condition mud @ shoe 17:30 19:30 2.00 2,485 5,100 PROD1 CORING TRIP P Continue to RIH to 5100 ft 19:30 22:30 3.00 5,100 5,306 PROD1 CORING DLOG P Established circulation @ 506 GPM @ 1708 psi. logging from 5100 ft to 5306 ft. @ 60 RPM's @ 7-8 K torque. ECD @ bit 10.5#/Gal. ROP of 130 per hr. 22:30 00:00 1.50 5,306 5,350 PROD1 DRILL DRLG P Drillout rat hole as per Geo. @ ROP @ 60 ft per hr. RPM's of 65,WOB =10 K Torque @ 9-10 K.Pump rate @ 500 GPM @ 1670 psi. From 5306 ft to 5350 ft. 32/26/2015 Drilled to 5610 ft. MD. POOH with MWD BHA. RU E-line • 00:00 11:30 11.50 5,350 5,610 PROD1 DRILL DDRL P 'Continue to drill to TD. ROP @ 30.6 FPH.WOB=9.5 K. Circulation @ 500 GPM @ 1660 psi. RPM's @ 65. Torque @ 9-11 K. MWD ECD= 10.5 #/gal Up Wt=200 K Down wt 150K Rotaing wt= 170 K Bottom of the Moraine©5388 ft. worked bit wt to increase ROP with out success. Pump nut plug sweep to clear bit. Continue drilling. Drilled down to 5610 MD 5566'TVD. Circulated hole clean. 11:30 12:00 0.50 5,610 5,610 PROD1 DRILL OWFF P Flow check 30 min's 12:00 14:00 2.00 5,610 5,610 PROD1 DRILL TRIP P POOH to 4963 ft over pull of 10 K reamed back to TD 5610. Up wt= 193 K Dwn wt 145 K 14:00 15:00 1.00 5,610 5,610 PROD1 DRILL CIRC P Circulated bottoms up 15:00 17:00 2.00 5,610 2,327 PROD1 DRILL TRIP P 1POOH to shoe @ Up wt.=208K Dwn wt= 150K Page 14 of 18 , Time Logs 110 • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:00 17:30 0.50 2,327 2,327 PROD1 DRILL OWFF P Flow check 30 min's 17:30 19:00 1.50 2,327 181 PROD1 DRILL TRIP P Continue to POOH to BHA 19:00 22:30 3.50 181 0 PROD1 DRILL BHAH P Lay down BHA#6. Clear floor and pipe shed of tools 22:30 00:00 1.50 0 0 PROD1 EVALFN ELOG P PJSM Begin rigging up Halliburton E-line service 02/27/2015 Completed MIRL log And be gin RDT log. 00:00 00:00 24.00 PROD1 EVALFN ELOG P Continue to Rig up E-line. Conduct MRIL Log from 5542'to 4100' . Run RDT log. 02/28/2015 Continue to run RDT log 00:00 00:00 24.00 PROD1 EVALFN ELOG P Continue with RDT log. RDT pressure sample increased due to phase 3 weather. 03/01/2015 Continue to run RDT logs, RD Halliburton 00:00 21:00 21.00 PROD1 EVALFN FLOG P Continue to run RDT log while waiting on phase 3 weather conditions. 21:00 00:00 3.00 PROD1 EVALFN ELOG P RD HES Eline. and equipment. 03/02/2015 Ran RTS&FMI logs RD Schlumberger. Test BOPE 00:00 01:00 1.00 PROD1 EVALFN FLOG P Continue to RD Halliburton E-line& clear tools 01:00 04:30 3.50 PROD1 EVALFN ELOG P Spot&RU Schlumberger E-line 04:30 12:00 7.50 PROD1 EVALFN ELOG P RIH with RTScanner-LithoScanner/ ECS 12:00 18:30 6.50 PROD1 EVALFN ELOG P RIH with FMI Sonic log 18:30 20:30 2.00 PROD1 EVALFN FLOG P RD Schlumberger E-Line services 20:30 22:00 1.50 PROD1 WHDBO RURD P Pull Wear ring/install test plug. Drain stack and fill with fresh water. Shell'test BOPS 250/3500 psi. 22:00 00:00 2.00 PROD1 WHDBO BOPS P Test BOPS: Test waived by Jeff Jones 3/1/15 @ 8:50 pm Test BOPS to 250/3500 psi on chart. test#1) Blind rams, Kill line Man. Pass 33/03/2015 Test BOPS/RIHG with cement stinger assembly for abandonment 00:00 09:00 9.00 0 0 PROD1 WHDBO BOPS P Continue to test BOPE to 250/3500 psi. Test 2)Choke 1,2,3,16, Kill Demco HCR: pass 3)Choke 4,5,6, HCR kill: Pass 4)Choke 7,8,9, Man kill : Pass 09:00 11:00 2.00 0 0 PROD1 WHDBO RURD T R/D test equipment attempt to pull test plug lodged in stack, drain stack work test plug free,set wear ring. Cuttings on top of test plug. Page 15 of 18 Time Logs • Date From To Dur S. Depth=E. Depth Phase- Code Subcode T Comment 11:00 14:00 3.00 0 0 PROD1 PLUG OTHR T Remove Kelly hose thaw goose neck and hose, install on top drive and goose neck. 14:00 15:00 1.00 0 0 PROD1 PLUG RURD P Rig up GBR tubing euipment, P/U cross overs and mule shoe. 15:00 15:30 0.50 0 0 PROD1 PLUG SFTY P Pre Job Safety Meeting on running cement stinger 15:30 19:30 4.00 0 870 PROD1 PLUG PULD P RIH with 3.5"8rd 19:30 23:30 4.00 870 4,256 PROD1 PLUG TRIP P RIH with 5"DP 23:30 00:00 0.50 4,256 4,256 PROD1 PLUG CIRC P Condition mud to get well back in balance. 03/04/2015 Pump bottom hole plug from 5610 ft'to TTOC @ 3570 ft W/849 sxs og G cement. POOH laying down Excess drill pipe 00:00 00:30 0.50 4,256 4,256 PROD1 PLUG CIRC P Continue to condition mud 00:30 03:30 3.00 4,256 5,610 PROD1 PLUG TRIP P Continue to RIH with cement stringer assembly 03:30 06:00 2.50 5,610 5,010 PROD1 PLUG CIRC P Condition mud, POOH to 5010'. 06:00 10:00 4.00 5,610 5,610 PROD1 PLUG CMNT P Staged in 993 cuft3 abandonment plug from TD @ 5610 ft. pumped 3- 840 LN ft plugs 600 ft+40%excess. G cement @ 3-5 BPM TOP of plug tagged @ 3687 ft after 14.5 hrs wait 10:00 12:00 2.00 5,610 5,010 PROD1 PLUG CMNT P Set retainer @ 2362.0 ft PT to 1500 psi for 30 min's. Est injection rate @ 3 BPM @ 300 psi.21 BBLs total injection away. MIX&pumped 104 sxs of G cement Bull head away @ 3 BPM @ 100 psi. final injection pressure 100 psi. Pulled from retainer and dumped 3 bbls above. ICP @ 22:20 hrs 12:00 13:00 1.00 5,010 4,410 PROD1 PLUG TRIP P POOH from 5010'to 4410'/ PUW140K/SOW 115K 13:00 16:00 3.00 4,410 4,410 PROD1 PLUG CIRC P Circulate and clean out cement stinger and drop wiper ball, 3 bpm/ 375 psi. 16:00 16:30 0.50 PROD1 PLUG TRIP P POOH from 4410'to 3507', PUW 105K/SOW 95K. 16:30 20:00 3.50 4,410 3,507 PROD1 PLUG CMNT P Mix&pumped 254 Sxs pf AS-1 cement from 508"to surface.Topped of well after DP displacement. TOC @ 13.5 ft from starter flange. Measured with tape measure. 20:00 22:00 2.00 3,507 2,660 PROD1 PLUG TRIP P POOH from 3507'to 2660'/PUW 80K/SOW 75K. Hanging up on 9 5/8"casing shoe. Pull slowly until inside casing. 22:00 00:00 2.00 2,660 1,415 PROD1 PLUG PULD P POOH sideways from 2660'to 1415'. _ PUW 60K/SOW 50K. 33/05/2015 Continue to POOH laing down DP. RIH to 3414.0 ft wait on cmt. Tagged cmt plug @ 3687 ft.Wittiness By Chuck Scheve AOGCC. POOH. laid down 3.5*rd cmt stinger. RIH with 9 5/8"cmt retainer. set retainer @ 2362 ft. Pumped 15 BBIs of AS1 below reatiner @ 3BPM @ 100 psi. laid 3.5 bbls of cmt on top of retainer. & PT to 1500 psi for 30 min's Page 16 of 18 Time Logs 11, • Date FromTo Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 1,426 870 PROD1 PLUG PULD P Continue to lay down drill pipe 02:30 04:30 2.00 870 3,414 PROD1 PLUG TRIP P RIH with 5"drill pipe and stinger 04:30 06:00 1.50 3,414 3,414 PROD1 PLUG WOC P Wait on cement to cure 06:00 08:00 2.00 3,414 3,687 PROD1 PLUG OTHR P RIH tag cement @ 3687'.Tag wittinessed By Chuck Scheve AOGCC clear stinger of any cement. 08:00 12:30 4.50 3,687 870 PROD1 PLUG TRIP P POOH with 5"drill pipe to 3.5" stinger 12:30 13:00 0.50 870 870 PROD1 PLUG RURD P PJSM: RU GBR 13:00 14:30 1.50 870 0 PROD1 PLUG PULD P Lay down 28 jts of 3.5 EUE 8rd tubing 14:30 16:00 1.50 0 0 PROD1 PLUG RURD P RD GRB 16:00 19:00 3.00 0 2,362 PROD1 PLUG TRIP P RIH with 9 5/8"retainer on 5"DP set reatiner @ 2362.0 ft 19:00 19:30 0.50 2,362 2,362 PROD1 PLUG PRTS P PT retainer to 1500 psi for 30 min's. _ Good test. 19:30 22:30 3.00 2,362 2,362 PROD1 PLUG SQEZ P ESt Injection rate: 1/2 BPM @ 90 psi, 1 BPM @ 130, 1.5 BPM @ 175 psi,2 BPM @ 225 psi, 2.5 BPM @ 275 psi, 3 BPM @ 300 psi.Total of 21 BBLS away. PT lines&pump to 4000 psi. pump 5 BBLs fresh H2O ahead, MX&pump 18.5 BBLs of AS1 cement.displaced with 10 bbls fresh,28 bbls mud Cement in place @ 22:20 hrs. Pulled out of retainer dumped 3.5 BBLS of cement on top. 22:30 23:30 1.00 2,362 2,174 PROD1 PLUG CIRC P Pulled up to 2174 ft Circulated hole clean. 23:30 00:00 0.50 2,174 2,174 PROD1 PLUG PRTS P PT retainer to 1500 spi.for 30 min's 33/06/2015 Continue plugging operation. Placed AS 1 cement above CIBP @ 508'to surface. ND BOPE cleaned mud system 00:00 01:30 1.50 2,174 0 PROD1 PLUG TRIP P POOH with DP&retainer stinger. 01:30 02:30 1.00 0 510 PROD1 PLUG TRIP P Trip in hole with 9 5/8"CIBP 02:30 03:00 0.50 510 508 PROD1 PLUG MPSP P Set CIBP 03:00 04:00 1.00 508 0 PROD1 PLUG TRIP P POOH with DP&setting assembly 04:00 05:00 1.00 0 0 PROD1 PLUG PRTS P RU test line&PT CIBP to 1500 psi for 30 min's on chart. Good test. Bled off pressure. 05:00 06:30 1.50 0 506 PROD1 PLUG TRIP P RIH with DP open ended. 06:30 09:00 2.50 506 0 PROD1 PLUG CMNT P Pumped 34.5 bbls of AS1 cement to surface from CIBP @ 508 ft. Pooh to _ 63 ft top off well. 09:00 10:30 1.50 0 0 PROD1 PLUG WWWH P Flushed stack with Black water& fuction test rams to release any trapped cement. Page 17 of 18 11)Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 0 0 PROD1 PLUG RURD P Pulled master bushings Clean out under Rotary table clear/clean floor of all tools not required. 12:00 13:00 1.00 0 0 PROD1 PLUG PRTS P Tested cement plug to 1500 psi lost 600 spi in 30 min test. bled off pressure. 13:00 18:30 5.50 0 0 PROD1 PLUG PULD P PJSM laid down 99 jts of 5" DP. Mouse hole/tugger 18:30 22:00 3.50 0 PROD1 MOVE RURD P Pull&clean pits, sumps and tanks for move 22:00 00:00 2.00 PROD1 WHDBO NUND P ND BOPE stack. Measure TOC @ 13.5 ft down from the starting flange. 03/07/2015 N/U dry hole tree,continue cleaning pits, prep derrick to lay over, clean cuttings box, move camp and shops to 2V pad. Rig Released at 0000 Hrs, Clear pad haul equipment t/2V pad. 00:00 01:30 1.50 PROD1 WHDBO NUND P NU Dry hole tree 01:30 05:00 3.50 PROD1 MOVE DMOB P Prep office and shops to move. & continue to Clean&Demob rig 05:00 00:00 19.00 PROD1 MOVE DMOB P Continue to clean pits and De-Mob rig equipment. Rig released @ 00:00 hrs Page 18 of 18 5 E •, a � 4y OAix E ,. } ,, j f ` \ , - 0) =. "4,4,. 4, 3 •le !:' x. �. 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( r ..4. , , ..,. :•4-' , 4_ , . . , 4...4, , 44 , . -„,„.4., ,,..,.., ,. , , ,4-1 - .- - 54 oro ¢ ., , .. „„ a }' ;.e,�. 4 , i r • r t` ti x..4 , I'll�"3 P y... 1 — � ,:. ,LL -,,,,, co _ AI 03 n Y ,..,..„,,-:#0*,:-' :ti :Fli,t',.,,,.i.,„. w �„,if,„-.,,, a .,,,,. ,,11. :,.1-'', 0* § -.7:7-1c1--c°8 " + ,--,t,„,,,,,,„,., U � ;:f i.# 1. `& ' n,. Y 0 —.(z Ayt 7 + }.. T. ' 'tom ,.a � 'r '. _ fn i fD IC co ALA '� .a x, 3 ' . e � r R t d •O p N Y f `tawf. U N f. ' - x _ 0". .. v-it' 'ik ' s /,/fes'/r :i • yit, F3\:.„.•-.,),,c# {{ f Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, April 10, 2015 11:26 AM To: 'Piercey, Tiffany C' Cc: Przywojski, Dan L; Umlauf, Kelly K; Wilson, Gregory C; Lemke, Sandra D; Brunswick, Scott A; Doherty, Patrick D; Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: RE: Moraine-1: Cuttings Delivery to AOGCC Hi Tiffany, Thanks for the update. Not a problem, please keep me in the loop if any further delays occur. Regards, 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 From: Piercey,Tiffany C [mailto:Tiffany.C.Piercev@conocophillips.com] Sent: Friday, April 10, 2015 11:21 AM To: Guhl, Meredith D (DOA) Cc: Przywojski, Dan L; Umlauf, Kelly K; Wilson, Gregory C; Lemke, Sandra D; Brunswick, Scott A; Doherty, Patrick D Subject: Moraine-1: Cuttings Delivery to AOGCC Hi Meredith- As per our conversation,the cuttings from Moraine-1 are currently being reprocessed at Halliburton in order to have them adequately washed.As soon as this process is complete, Halliburton will hand deliver them over to your office. Apologies for the delay. Please let me know if you have any questions! Thank you! Tiffany Piercey Geological and Geophysical Operations ConocoPhillips Alaska Inc ATO 1440, 700 G Street, Anchorage, AK 99501 Office: 907-265-1495 Cell: 907-330-4778 tiffany.c.piercey(a�cop.com 1 111 0111-1q Guhl, Meredith D (DOA) From: Piercey, Tiffany C [Tiffany.C.Piercey@conocophillips.com] Sent: Friday, April 10, 2015 11:21 AM To: Guhl, Meredith D (DOA) Cc: Przywojski, Dan L; Umlauf, Kelly K; Wilson, Gregory C; Lemke, Sandra D; Brunswick, Scott A; Doherty, Patrick D Subject: Moraine-1: Cuttings Delivery to AOGCC Hi Meredith- As per our conversation,the cuttings from Moraine-1 are currently being reprocessed at Halliburton in order to have them adequately washed.As soon as this process is complete, Halliburton will hand deliver them over to your office. Apologies for the delay. Please let me know if you have any questions! Thank you! Tiffany Piercey Geological and Geophysical Operations ConocoPhillips Alaska Inc ATO 1440, 700 G Street, Anchorage, AK 99501 Office: 907-265-1495 Cell: 907-330-4778 tiffany.c.piercey(a�cop.com 1 • AkAra ( Pm at rt?o Regg, James B (DOA) From: Hill,Johnnie W (DOA) Sent: Tuesday, March 31, 2015 1:34 PM To: Regg,James B (DOA) Subject: Re: Moraine #1 P&A Jim (.CPP� Bob and I didn't go out to witness the P&A We asked Randy to send pictures of the job. Also he was going to send in a report to you on it. - Johnnie Hill 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 Johnnie Hill at 907-659- 2714 or johnnie.hill@alaska.gov On Mar 31, 2015, at 12:29 PM, Regg,James B (DOA)<iim.regg@alaska.gov>wrote: Report? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907-793-1236 or iim.regg@alaska.gov. From: Hill, Johnnie W (DOA) Sent: Sunday, March 29, 2015 8:51 PM To: Regg, James B (DOA); Noble, Robert C (DOA) Subject: Moraine #1 P&A Johnnie Hill Petroleum Inspector AOGCC 907-659-2714 907-715-7574 1 • • Surface Abandonment—Moraine#1 (CPAI) PTD 2141980 Photos courtesy of CPAI March 10-12, 2015 or . , ,.. . ,.0 . ,,,. .,... ..., .r. ,_,, , ,,,,,,„ _ .. „„ ,,, , ,,„ . . .,.... ,: ,.. .,...., , ... .. . „„s„,,,, .. . , %alb 41 ..,... '..,,'-. *, ,,,,,,4 :,,d,,,orff.'''...',,s .,' . .yam Jt 4 • Fes”"- N � .,. y .. 1111 , ,''S�"4 .. � .eta• ••"a Atilt•T f! L • �Y '' . • .a „. 4 * f Rkt tr ,;L . M� t* _� � ~ 4:4!"..r�a�> fr r . r i4. i 1j t i ',:::V:*". 4 f j Alieru * /Art,' i t � aW .a * ':‘ 2015-0312_Surface_Abandon_Moraine-1.docx Page 1 of 4 • • } •4 ws.R W,4 Ar. Y fyj `R.7 L ,ir/': -[ 1! '` fw'' 4 • iii ami. S" . . 7J l 1•.. lac" W. 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'��. r, ri - cam' ',«r ° "k i ti ,, ' . * +.,mow ocx 2015-0312 Surface Abandon Moraine-1.d Page 3 of 4 • • ..4, ., `fin, • 4"• r •• K ¢ y� `4 . ,„ . ,. ,:,,,,,;:t, ,:,_,.-,,:...".0„,......„'3...1..,„1.0...iii, !..4,•'.,,t;::,,,,,,,,',,::' k-w x�a e ..'� 3 It n M# 13 M" s . k ' c i •. ,. , , • . t`.. e ra, .06....,..,,,, " , :_i_,;,,,„ ... :......, � ,•,• � .$ '-,r � , t, 4,:,,, � is.. 0 a' 014 4 WA40 y� �,p.�i ,gyp li" H ft,i,":„..;, , ..o...,„,0,, , 2015-0312 Surface Abandon Moraine-1.docx Page 4 of 4 r • • 214198 25587 ConocoPhillips RECEIVED LOGGED TRANSMITTAL MAR252015 DAT 3A 015 K.BENDER AOGCC FROM: Sandra D. Lemke, AT01412 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: Moraine 1 DATE: 03/23/2015 Transmitted: Kuparuk River Unit, Alaska Moraine 1 1 hardcopy report and 1 CD Schlumberger Definitive Directional survey, Moraine 1 NAD27 and NAD83 reports in .PDF and load files in .txt Please promptly sign, scan and return electronically to Sandra.D.Lemke(dCOP.com CC: Morainel transmittal folder, production well files, eSearch Receipt: ii").ALL-0-47-01) 6e4t4t. T . s ,„;- GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 • 214198 25587 RECEIVED MAR 252015 AOCCC NADConversion North Alaska ASP4 Moraine Moraine Definitive Survey Report a , NAD 27 20 March, 2015 • Schlumberger Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57(42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 0 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Project North Alaska ASP4 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 Moraine 1 Well position +N/-S 0.00 usft Northing; 5,997,105.08 usft Latitude; 70°24'11.299 N +E/-W 0.00 usft Easting: 468,098.69 usft Longitude: 150°15'34.812 W 1 Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 14.00 usft Wellbore Moraine 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (`1 (nT) BGGM2014 2/5/2015 18.79 80.92 57,566 I Design Moraine 1 Audit Notes: 1 Version: 1.0 Phase: ACTUAL Tie On Depth: 28.57 1 Vertical Section: Depth From(TVD) +N/-S +E/Vit Direction (usft) (usft) (usft) (°) I 28.57 0.00 0.00 29.17 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 50.15 232.43 MWD Svy1 lnc+Trend(Moraine 1) INC+TREND Inclinometer+known azi trend 3/13/2015 11:54: 328.18 2,423.89 MWD Svy2 MWD+DMag(Moraine 1) MWD+SCC MWD+Short Collar correction 3/13/2015 11:59: 2,536:29 5,545.22 MWD$vy3 MWD(Moraine 1) MWD MWD-Standard 3/13/2015 12:14 Survey Map Map Vertical MD Inc Axl TVD TVDSS +N/-S +E/-W Northing Easfing DLS Section (Ustt) (°) (°) (Usti (usit) (Usft) (usft) (ft) (it) MOO, (ft) Survey Tool Name 28.57 0.00 0.00 28.57 -14.00 0.00 0.00 5,997,105.06 468,098.69 0.00 0.00 UNDEFINED 50.15 0.07 15.81 50.15 7.58 0.01 0.00 5,997,105.07 468,098.69 0.32 0.01 1NC+TREND(1) 108.20 0.12 55.48 108.20 85.63 0.08 0.06 5,997,105.14 488,098.75 0.14 0.10 INC+TREND(1) Li; .,.. 18"x 42" 143.12 0.16 85.13 143.12 100.55 0.12 0.14 5,997,105.18 468,098.82 0.14 0.17 1NC+TREND(1) 232.43 0.60 236.09 232.43 189.86 -0.09 -0.14 5,997,104.97 468,098.55 0.85 -0.14 INC+TREND(1) 328.18 0.51 247.16 328.17 285.60 -0.53 -0.95 5,997,104.53 468,097.74 0.15 -0.93 MWD+SCC(2) 417.48 0.44 324.33 417.47 374.90 -0.41 -1.51 5,997,104.86 468,097.17 0.67 -1.09 MWD+SCC(2) 505.97 0.84 344.58 505.96 463.39 0.49 -1.88 5,997,105.56 468,096.81 0.51 -0.49 MWD+SCC(2) 599.49 1.86 8.96 599.45 556.88 2.65 -1.83 5,997,107.72 468,096.87 1.23 1.43 MIND+SCC(2) 687.75 4.25 21.88 687.58 645.01 7.10 -0.39 5,997,112.16 468,098.33 2.80 6.01 MWD+SCC(2) 779.88 4.66 25.03 779.43 736.86 13.66 2.47 5,997,118.71 468,101.21 0.52 13.13 MWD+SCC(2) 3/20/2015 2:05:26PM Page 2 COMPASS 5000.1 Build 65 Schlumberger • Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1:14+28.57 0 42.57usft(Nabors 9ES) Well; Moraine 1 North Reference: True Wefbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEOMP2 Survey Map Map Vertical MD inc Azi TVD TVDSS +NlS +El-W Northing Easting OLS Section (usft) (') e (usft) (usft) (usft) (usft) (ft) (ft) ("1100, (ft) Survey Tool Name 878.30 7.03 31.61 877.33 834.76 22.42 7.32 5,997,127.44 468,106.10 2.50 23.14 MWD+SCC(2) 972.19 8.42 32.85 970.37 927.80 33.08 14.96 5,997,138.08 468,112.88 1.49 35.74 MWD+SCC(2) 1,065.74 10.98 30.60 1,062.57 1,020.00 46.51 22.31 5,997,151.47 468,121.19 2.77 51.48 MWD+SCC(2) 1,159.68 12.72 30.02 1.154.49 1,111.92 63.16 32.04 5.997.168.08 468,130.99 1.66 70.77 MWD+60D(2) 1,254.76 14.89 31.12 1246.84 1,204.27 82.89 43.59 5,997.187.55 468,142.63 2.30 93.45 MWD+6C0(2) 1,348.98 1659 31.82 1,337.52 1,294.95 104.48 5694 5,997,209.29 468,156.07 1.82 118.99 MW13+8CC(2) 1,443.23 18.60 32.79 1,427.36 1,384.79 128.56 72.18 5,997,233.29 468,171.40 2.16 147.43 MWD+SCC(2) 1,541.36 18.08 32.64 1,520.50 1,477.93 154.53 88.85 5,997,259.20 468,188.20 0.53 178.25 MWD+SCC(2) 1532.47 17.53 33.08 1,607.25 1564.68 177.84 103.98 5,687,282.53 468,203.41 0.62 206.05 MWD+SCC(2) 1,726.28 16.85 33.77 1,696.87 1,654.30 201.08 118.25 5,887,305.60 468,218.78 0.76 233.70 MWD46CC(2) 1,819.99 1526 28.04 1,786.92 1,744.35 223.26 132.60 5,997,327.72 468,232.22 2.39 259.57 MWD+SCC(2) 1,914.34 15.08 28.54 1,877.99 1,835.42 244.98 144.29 5,997,349.40 488,244.01 0.25 284.24 MWD+SCC(2) 2,007.85 11.95 25.83 1,968.90 1,926.33 264.37 154.31 5,997,368.74 468,254.11 3.39 306.06 MWD+SCC(2) 2,102.27 11.06 27.45 2,061.43 2,018.86 281.21 162.75 5,997,385.54 468,262.62 1.00 324.87 MWD+SCr'(2) 2,19645 9.62 2724 2,154.08 2,111.51 296.22 170.52 5,997,400.52 468,27045 1.53 341.77 MWD+SCC(2) 2,291.25 6.91 27.86 2,247.88 2,205.31 308.31 176.81 5,997,412.58 468,276.79 2.86 355.39 MWD+SCC(2) 2,384.85 3.77 32.87 2,341.06 2,298.49 315.87 181.11 5,997,420.12 468,281.13 3.39 364.09 MWD+SCC(2) 2,423.89 1.83 52.14 2,380.06 2,337.49 317.34 182.30 5,997,421.58 468,282.32 5.46 365.94 MWD+SCC(2) 2,486.80 0.89 58.47 2,442,95 2,400.38 318.21 183.51 5,997,422.45 468,283.53 1.52 367.29 11AWD(3) ' ,... * 9.518"x 12-114" 2,536.29 0.22 104.60 2,492.44 2,449.87 318.38 183.92 5,997,422.62 468,283.95 1.52 367.65 MWD(3) 2,631.39 0.06 60.09 2,587.54 2,544.97 318.36 184.14 5,997,422.60 468,284.17 0.19 367.74 MWD(3) 2.72523 0:09 23:91 2,661:38 2,638,81 318:45 18422 5.997,422,69 468,284.24 0.06 367:85 MWD(3) 2,819.77 0.06 156.10 2,775.92 2,733.35 318.48 184.27 5,997,422.71 468,284.29 0.15 367.90 MWD(3) 2,913.81 0.09 313.33 2,869.96 2,827.39 318.48 184.23 5,997,422.72 468,284.26 0.16 367.89 MWD(3) 3,007.68 0.09 251.92 2,963.83 2,921.26 318.51 184.11 5,997,422.75 468,284.14 0.10 367.85 MWD(3) 3,101.93 0.08 325.19 3,058.08 3,015.51 318.53 184.01 5,997,422.78 488,284.04 0.10 387.8" MWD(3) 3,196.88 0.11 103.19 3,151.83 3,109.26 318.55 184.07 5,997,422.78 468,284.10 0.17 367.86 MWD(3) 3,289.79 0.06 96.32 3,245.94 3,203.37 318.52 184.21 5,997,422.76 468,284.23 0.05 367.91 MWD(3) 3,384.25 0.08 39.98 3,340.39 3,297.82 318.55 184.29 5,997,422.79 468,284.31 0.06 367.98 MWD(3) 3,572.50 0.06 311.74 3,528.64 3,486.07 318.69 184.28 5,997,422.93 468,284.31 0.04 368.09 MWD(3) 3,759.61 0.09 137.59 3,715.75 3,673.18 318.65 184.30 5,997,422.89 468,284.33 0.08 368.07 MWD(3) 3,85381 0.09 58.52 3,809.95 3,76728 318.83 184.42 5,997,422.87 488,284.44 0.12 368.11 MWD(3) 3,948.84 0.09 1922 3,904.78 3,862.21 318.74 184.51 5,897,422.98 468,284.53 0.06 388.25 MWD(3) 4,042.70 0.09 63.71 3,998.84 3.95627 318.85 184.60 5.997,423.E 468284.62 0,07 368.36 MWD(3) 4,137.28 0.06 93.38 4,093.42 4,050.85 318.88 184.71 5.997,423.11 468,284.74 0,05 368.46 MWD(3) 4,232.51 0.09 295.36 4,188.65 4,146.08 318.91 184.69 55.997423.14 468,284.72 0.15 368.48 MWD(3) 4,326.94 0.09 71.16 4,283.08 4.240.51 318.96 184.70 5.997.423.20 468284.73 0.18 368.53 MWD(3) 4,421.03 0.09 216.54 4,377.17 4,334.60 318.93 184.72 5,997,423.16 468,284.75 0.18 368.51 MWD(3) 4,515.67 0.06 17.18 4,471.81 4,429.24 318.91 184.69 5,997,423.15 468,284.72 0.16 368.49 MWD(3) 3/20/2015 2:05:26PM Page 3 COMPASS 5000.1 Build 65 • Schlumberger Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reference: Moraine 1: 14+28.57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference: True Wei!bore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +Ef-W Northing Easting DLS Section Nat) (`) (`) (usft) (usft) (usft) (usft) (ft) (ft) MOO') (ft) Survey Toot Name 4,610.28 0.09 332.90 4,566.42 4,523.85 319.03 184.67 5,997,423.26 468,284.70 0.07 368.58 MWD(3) 4,704.10 0.09 151.28 4,660.24 4,617.67 319.03 184.68 5,997,423.26 468,284,70 0.19 368.58 MWD(3) 4,797.74 0.06 261.05 4,753.88 4,711.31 318.96 184.66 5,997,423.19 468,284.69 0.13 368.51 MWD(3) 4,891.66 0.06 325.28 4,847.80 4,805.23 318.99 184,59 5,997,423.22 488284.81 0.07 368.50 MWD(3) 5,038.29 0.12 333.74 4,994.43 4,951.86 319.19 184.47 5,997,423.42 468,284.50 0.04 368.62 MWD(3) 5,087.78 0.04 141.71 5,043.92 5,001.35 319.22 184.46 5,997,423.46 468,284.49 0.32 368.64 MWD(3) 5,181.59 0.09 50.16 5,137.73 5,095.16 319.24 184.54 5,997,423.48 468,284.57 0.11 368.70 MWD(3) 5,278.18 0.04 84.51 5,234.32 5,191.75 319.30 184.63 5,997,423.53 468,284.66 0.06 368.79 MWD(3) 5,371.42 0.09 90.77 5,327.56 5,284.99 319.30 184.74 5,997,423.53 488,284.77 0.05 368.84 MWD(3) 5,466.45 0.12 334.35 5,422.59 5,380.02 319.39 184.77 5,997,423.62 468,284.80 0.19 368.94 MWD(3) 5,545.22 0.09 68.95 5,501.36 5,458.79 319.48 184.79 5,997,423.72 468,284.82 0.20 369.03 MWD(3) 5,610.00 0.09 68.95 5,566.14 5,523.57 319.52 184.89 5,997,423.75 468,284.92 0.00 369.11 PROJECTED to TO NOT an Actual Servs) 3720/2015 2:05:26PM Page 4 COMPASS 5000.1 Build 65 • • C) cn' z X CD -0 p rnCo SD N W a) m <' P. — n z. e al 0EElc E o c woof, a� .... -Ti vh I 0 4t ca Z 0D 7� �m 5 a Q —14 !y 0V$— ° oma m V\ (I1 Q 03 a0 Q. 0 ansa 3 2 Z (0 V) n. c a_ 0 C NR`g rn _ = b CD �'si C sh. 3 N $dob Al z. $ ca o ca ,r. o o 0 to .r. Q CD C cD FL CD 0 0 6 • • 1 .1, 4198 25587 ConocoPhillips (Alaska) Inc. -Expl North Alaska ASP4 Moraine Moraine 1 Definitive Survey Report NAD 83 20 March, 2015 • Schlumberger41110 Definitive Survey Report Company: ConocoPhithps(Alaska)Inc.-Exp! Local Coordinate Reference: Well Moraine 1 Project: North Alaska ASP4 ND Reference: Moraine 1:14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Reform= Moraine 1:14+28,57 @ 42.57usft(Nabors 9ES) Well: Moraine 1 North Reference; True WeUUDor8: Moraine 1 Survey Caicu M on Method: Minimum Curvature Design: Moraine 1 Database: OAKEDMP2 Poled North Alaska ASP4 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 4 Using geodetic scale factor I Well Moraine 1 I Well Position +N/-S 0.00 usft Northing: 5,996,855.38 unit L.SIRude: 70'24'10.203 N +EIW 0.00 usit Easting: 1,608,130.73 usft Longitude: 150°15'46.110 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 14.00 usft Wellbore Moraine 1 Magnetics Model Name Sample Date Declination Dip Angie Reid Strength r) r) On BGGM2914 2/5/2015 18.79 80,92 57,566 Design Moraine 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.57 Vertical Section: Depth From(ND) +14114 +El W Direction (usf) ( ) ( ) P) 28.57 0.00 0.00 29.17 t Survey Program Date 3/20/2015 From To (usft) (ustt) Surrey(Wellbore) Tool Name Description Survey Date 50.15 232.43 MWD Svyl inc+Trend(Moraine 1) 1NC+TREND inclinometer+known azi trend 3/13/2015 11:54: 328.18 2,423.89 MWD Svy2 MWD+DMag(Moraine 1) MWD+SCC MWD+Short Collar correction 3/13/2015 11:59: 2,535.29 5,545,22 MWD Svy3 MWD(Moraine 1) MWD MWD-Standard 3/13/L415 12:14 1 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NlS +E/-W Northing Easting DLS Section (usft) (+) () (usft) (ustt) (usfq (ustt) ( (S) mum (S) Survey Tool Nan* 28.57 0.00 0.00 28.57 -14.00 0.00 0.00 5,996,855.38 1,608,130.73 0.00 0.00 UNDEFINED 50.15 0.07 15.81 50.15 7.58 0.01 0.00 5,996,855.39 1,608,130.73 0.32 0.01 INC+TREND(1) 108.20 0.12 65.46 108.20 65.63 0.08 0.06 5,996,855.46 1,608,130.79 0.14 0.10 INC+TREND(1) .0» 16"x4r 143.12 0.16 65.13 143.12 100.55 0.12 0.14 5,998,855.50 1,608,130.87 0.14 0.17 INC+TREND(1) 232.43 0.60 236.09 232.43 169.88 -0.09 -0.14 5,998,855.29 1,608,130.59 0.85 -0.14 INC*TREND(1) 328.18 0.51 247.16 328.17 285.60 -0.53 -0.95 5,996,854.85 1,606,129.78 0.15 -0.93 MWD+SCC(2) 417,48 0.44 324,33 417,47 374,90 -0,41 -1,51 5,996.854,96 1.605,12922 0,67 -1:09 MWlD 60C(2) 505.97 0.84 344.58 505.96 463.39 0.49 -1.88 5,996,855.88 1,608,128.85 0.51 -0.49 MWD+SCC(2) 599.49 1.88 8.96 599.45 556.88 2.85 -1.83 5,998,858.04 1,608,128.91 1.23 1.43 MWD+SCC(2) 687.75 4.25 21.88 68758 645.01 7.10 -0.39 5,996,862.49 1.508,130.37 2.80 6.01 MWD+SCC(2) 779.88 4.66 25.03 779.43 736.86 13.66 2.47 5,596.869.031 1508,133.26 0.52 13.13 MWD+SCC(2) 320/201510:50:31AM Page 2 COMPASS 5000.1 Build 65 ' • Schlumberger • Definitive Survey Report Company; ConocoPhillips(Alaska)inc.-Ezpi Local Co-ordinate Reference: iNr8 Moraine 1 Project: North Alaska ASP4 TVI)Reference: Moraine 1.14+28.57 @ 42.57usft(Nabors 9ES) Site: Moraine MD Referanaz Moraine 1:14+28.57 0 42.57usft(Nabors 9ES) Wall: Moraine 1 North Reference; True Wellbore: Moraine 1 Survey Calculation Method: Mini1m n Curvature Design: Moraine 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD WDSS +191-S +fJ-W Northing &warm DLS Section (usury t'1 (°) (usA) (usit) (rift) ( ) (it) (fti ruioo,) fig Survey Toot Name 878:30 7.03 31,61 877:33 634:76 2242 7:32 5,996,677:75 1,508,138:14 2:50 23.14 MWD"SQC(2) 972:19 6.42 32.85 970,37 927:80 33,08 14.06 5,996,888,40 1,608,144..93 1.49 35,74 MWD+SCC(2) 1,065.74 10.98 30.60 1,062.57 1,020.00 46.51 22.31 5,996,901.79 1,608,15324 2.77 51.48 MWD+SCC(2) 1,159.66 12.72 30.02 1,154.49 1,111.92 63.16 32.04 5,996,918.40 1,608,163.04 1.86 70.77 MWD+SCC(2) 1,264.76 14.89 31.12 1,246.84 1,204.27 82.69 43.59 5,996,937.87 1,608,174.67 2.30 93.45 MWD+SCC(2) 1,348.98 16.59 31.82 1,337.52 1,294.95 104.48 56.94 5,996.959.61 1,808,188.12 1.82 118.98 MWD+SCC(2) 1,44323 18.60 32.79 1,427.36 1,384.79 128.56 72.18 5,996,963.61 1,608,203.45 2.16 147.43 MWD+SCC(2) 1,54136 18.08 32.64 1,52050 1,477.93 154.53 88.86 5,997,009.51 1.08,220.25 053 17825 MWD+SCC(2) 1,632.47 17.53 33.06 1,607.25 1,564.68 177.94 103.96 5,997,032,85 1,608,235.47 0.62 206.05 MWD+SCC(2) 1,72628 16.85 33.77 1,996.87 1,654.30 201.08 119.25 5,997,055.92 1,608250.83 0.76 233.70 MWD+SCC(2) 1,819.99 15.26 28.04 1,786.92 1,744.35 223.26 132.60 5,997,078.04 1608,264.28 2.39 259.57 MWD+SCC(2) 1,914.34 15.06 28.54 1,877.89 1,835.42 244.98 144.29 5,997,099.71 1,608,278.06 0.25 28424 MWD+SCC(2) 2,007.85 11.95 25.83 1,968.90 1.926.33 264.37 154.31 5,997,119.06 1606,286.17 3.39 306.06 MWD+SCC(2) 2,10227 11.06 27.45 2,061.43 2,018.86 281.21 162.76 5,997,136.86 1,608,294.68 1.00 324.87 MW0+6CC(2) 2,19645 9.82 27.24 2,154.08 2,111.51 29622 170.52 5,997,150.83 1,08,342.51 1.53 341.77 MWD+SCC(2) 2,29125 6.91 27.86 2,247.88 2,205.31 308.31 176.81 5,997,162.89 1,608,308.85 2.86 355.39 MWD+SCC(2) 2,384.85 3.77 32.87 2,341.E 2,298.49 315.87 181.11 5,997,170.44 1608,313.18 3.39 364.09 MWD+SCC(2) 2,423.89 1.83 52.14 2,30.06 2,337.49 317.34 182.30 5,997,171.88 1,60,314.38 5.46 365.94 MWD+SCC(2) 2,486.80 0,89 58.47 2,442.95 2,400.38 318.21 183.51 5,997,172.76 1608,315.59 1.52 367.29 MWD(3) 9-518"z 12-114" 2,536.29 022 104.60 2,492.44 2,449.87 318.38 183.92 5,997,172.93 1,608,316.01 1.52 367.65 MWD(3) 2,631.39 0.06 60.09 2,587.54 2,544.97 318.36 184.14 5.997.172.91 1.608.316.23 0.19 367.74 MWD(3) 2,72523 0.09 23.91 2,661.38 2,638.81 318.45 18422 5.997,173.00 1,608,316.30 0.06 367.85 MWD(3) 2,818.77 0.06 156.10 2,775.92 2,733.35 318.48 18427 5,997,173.02 1,608,316.35 0.15 367.90 MWD(3) 2,913.81 0.09 313.33 2,869.96 2,827.39 318.48 18423 5,997,173.03 1,608,316.32 0.16 367.89 MWD(3) 3,007.68 0.09 251.92 2,963.83 2,921.26 318.51 184.11 5,997,173.06 1,608,316.20 0.10 367.85 MWD(3) 3,101.93 0.06 325.19 3,058.08 3,015.51 318.53 184.01 6,887,173.08 1,608,316.10 0.10 367.82 MWD(3) 3,185.68 0.11 103.19 3,151.83 3,109.26 318.55 184.07 5,997,173.10 1,608,316.16 0.17 367.86 MWD(3) 3,289.79 0.06 96.32 3,245.94 3,203.37 318.52 184.21 5,997,173.07 1,806,31629 0.05 367.91 MWD(3) 3,384.25 0.06 39.98 3,340.39 3.297.82 318.55 184.29 5,997.173.10 1,608,316.37 0.08 367.98 MWD(3) 3,572,50 0:06 311,74 3,528.64 3,486:07 318:69 18426 5.997,173,24 1.06,316:37 0:04 368,08 9AIxP(3) 3,759,61 0,09 137,59 3,715,75 3,673,16 316,65 184,30 5,997,173,20 1,608,316,39 0,06 368,07 MWD(3) 3,853.81 0.09 58.52 3,809.95 3,767.38 318.63 184.42 5,997,173.18 1,608,316.50 0.12 368.11 MWD(3) 3,948.64 0.09 19.22 3,904.78 3,86221 318.74 184.51 5,997,173.29 1,608,316.59 0.06 36825 MWD(3) 4,042.70 0.09 63.71 3,998.84 3,95627 318.86 184.60 5,997,173.39 1,608,316.68 0.07 368.38 MWD(3) 4,13728 0.06 93.38 4,093.42 4,050.86 318.88 184.71 5.997,173.42 1,608,316.80 005 368.46 MWD(3) 4,232.51 0.09 295.36 4,188.65 4,146.08 318.91 184.69 5,997,173.45 1,608,316.78 0.15 30.48 MWD(3) 4,326.94 0.09 71.16 4,283.08 4,240.51 318.96 184.70 5.997,173.51 1,608,316.79 0.18 368.53 MWD(3) 4,421,03 0:09 216.54 4,37717 4,334:60 318:83 184,72 5,997,173,47 1,618,316:81 0,16 368:51 M. (3) 4,515,67 0,06 17,18 4,471,61 4,429,24 316,91 164,69 5,997,173,46 1,608,316,78 0,16 366,49 MWD(3) 3/20/2015 10:50:31AM Page 3 COMPASS 5000.1 Build 65 iSchlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expi Local Coordinate Reference: Weil Moraine 1 Project: North Alaska ASP4 TVD Reference: Moraine 1:14+28.57 t§42.57usft(Nabors 9E5) Site: Moraine MD Reference: Moraine 1:14+28.57,t2 42,57usft(Nabors 9ES) Well: Moraine 1 North Reference; True Wellbore: Moraine 1 Survey Calculation Method: Minimum Curvature Design: Moraine 1 Database: OAKEDA4P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting OLS Section jusft) (1 (') (usft) (usft) (usft) just) (ft) (It) ("1100') (ft) Survey Tool Name 4,610.28 009 332.90 4,566,42 4,52365 319.03 184.67 5,997,173:57 1608,316.76 0.07 368.58 MWD(3) 4,704.10 0.99 15128 4,66024 4,617.67 319.03 184.68 5,997,173.58 1,608,316.76 0.19 368.58 MWD{3) 4,797.74 0.06 261.05 4,753.88 4,711.31 318.96 184,66 5,997,173.50 1,608,310.75 0.13 368.51 MWD(3) 4,891.66 0.06 325.28 4,847.80 4,805.23 318.99 18459 5,997,173.54 1,608,316_67 0.07 366.50 MIND(3) 6,038.29 0.12 333.74 4,694.43 4,051.86 310.19 184.47 5,907,173.74 1,608,316.56 0.04 366.62 MWD(3) 5,087.78 0.04 141.71 5,043.92 5,001.35 319.22 184.46 5,997,173.77 1,808,316.55 0,32 368,64 MWD(3) 5,181.59 0.09 50.16 5,137.73 5,095.16 31924 184.54 5,997,173.79 1,608,316.63 0.11 368.70 MWD(3) 5,278.18 0.04 8451 5,234,32 5,191.75 31930 184.63 5997,173.84 1,608,318.72 0,06 368.79 MWD(3) 5,371 42 0.09 90.77 5,327,56 5,284.99 31930 184.74 5,997,173.84 1,608,316.83 0.05 368.84 MWD(3) 5,466,45 0,12 334,35 5,422,59 5,380,02 319,39 184,77 5,997,173;93 1,608,316.86 0,19 368,94 MWD(3) 5,545.22 0.09 68.95 5,501.36 5,458.79 319.48 184.79 5,997,174.03 1,608,316.88 0.20 369.03 MWD(3) 5,610.00 0.09 68.95 5,566.14 5,523.57 31952 184.89 5,997,174.07 1608,316.98 0.00 369.11 PROJECTED to TD NOT an Actual Survey 3/20/2015 10:50:31AM Page 4 COMPASS 5000.1 Build 65 0 • (-, if x CD a C-13 W m W v -t m <" tD — n s s CD ogn (D c < 21 o , 0 3 cD m C 54 O o _ 0 4, , n p t�D I f ...„ N. Hn Q. C7 � y 0 B. "i'km$ < 0 -I, 0 — zsc N `• 0 0 �%! to 4' CD AlSt'' N IF. C s a§ < St ca ro o er O` coib O. < as DI Q y 0 0 n 214198 ', 25 543 vr ConocoPhilhps RECEIVED TRANSMITTAL MAR 19 2015 CONFIDENTIAL-DATA 4 AOGCC pm ,OOD5D FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Moraine 1 DATE: 03/18/2015 Transmitted: Kuparuk River Unit, Alaska Moraine 1 1 CD and hardcopy print Halliburton-Surface data logging and End of Well report- mud logging data for Moraine 1; 02/27/2015; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore 1 color log print each: Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.LemkeCaJCOP.com CC: Moraine 1- transmittal folder, production well files, eSearch Receipiii2.44 v 6-eiteeittate: GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 • tiOF Tht �w\��� ����s� THE STATE Alaska Oil and Gas F,��,;,-�•��� A ofLASKA Conservation Commission -_-- =___- - fz_ 333 West Seventh Avenue O ,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 FALAS' ' Fax: 907.276.7542 www.aogcc.alaska.gov Graham Alvord AK Drilling Manager 0 I 1 — (R Q� ConocoPhillips Alaska, Inc. (� P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Undefined Torok Oil Pool,Moraine 1 Sundry Number: 315-117 Dear Mr. Alvord: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, /a7:7e-tC/L- Cathy P oerster Chair DATED thiso day of March, 2015 Encl. RECEIVED STATE OF ALASKA � �1 MAR O 2 � ALASKA OIL AND GAS CONSERVATION COMMISSION MS �S. J APPLICATION FOR SUNDRY APPROVALS AOGC 20 MC 25.280 1.Type of Request: Abandon ❑., Plug for Redril ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program 0 Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension 0 Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc. Exploratory ❑ Development ❑✓ . 214-198 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 50-103-20699-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Moraine#1 9.Property Designation(Lease Number): 10.Field/Pool(s): -To saK -41b ADL025528 Kuparuk River Field Undefined.Meraine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): v 5610 ' 5566 See Proposed Schematic N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 16" 79.6' 79.6' Surface 2459.26' 9.625" 2485.21' 2441' 5750 3090 Intermediate 5610' 5566' Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Cement retainer&CIBP in surface casing Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: )D Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development u Service ❑ 14.Estimated Date for 8-Mar-15 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Q Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Brunswick 263-4249 Email scott.a.brunswick(a�cop.com Printed Name Graham Alvord Title AK Drilling Manager Signature Phone 265-6120 Date Z l Z� /fie t A-C. ai, 1 l COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t5-iiI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance n Other: , Photo docvmz•v1fa ti I-7 of f1-iz ecw-Icht ¢-op o .Ff cfa iu1r et b1nc� pi- oto clDevyvtcvrie, t-ia !i1 of '',-.C.1dcl cc! - nr- wtav-kcr pl-rt-c J P 1'10 /o C/O C v h^ t-v► fa 7) a n of• S/ '1 {i-o vin fi<D Lie 6b t l'r) .5 1±-C Cl ra r�/Plc �p p re)v a Spacing Exception Required? Yes ❑ No lgl Subsequent Form Required: / Ltd-- APPROVED BY -�C Approved by: P (�,.— COMMISSIONEERR THE COMMISSION /�/ Date: 3 . / OpRvidGlIcNIA v -/1/1 /77/4 I-i�J Submit Form and Form 10-403(Revised 10/2012) id for 12 months from the date of approval. Attachments in Duplicate v�T� 3/4/1S-- RBDMSJ APR - 2 2015 • 4111 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 February 27, 2015 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 MAR 0 2 2015 Anchorage,Alaska 99501 ® {��± ^ Re: Application for Sundry to permanently Abandon Moraine#1 (PTD 214-198) AOGCC Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry to permanently abandon the onshore core&formation evaluation well Moraine#1 from an ice constructed drilling pad. The intended work commencement date for this is March 8th, 2015. Nabors 9ES is had drilled the well to TD&is currently performing open hole E-Line logging operations. Once the logging operations are completed,the rig will place cement plugs& P&A the well as detailed in the PTD 214-198 operations. This sundry is to perform the post rig operations for the permanent P&A. Moraine#1 is a S-shaped well drilled to a TD of 5610 feet MD. The Moraine formation has been cored with +/-70% recovery. The surface casing is set with cement returns to surface&is the only casing string set in Moraine#1. The PTD plan consists with three each +/-600 foot cement isolation plugs on bottom to bring cement at minimum 100 feet above all potential hydrocarbon bearing formations. The rig will then set a cement retainer+/- 100 feet inside the surface casing and squeeze+/-200 feet of cement below the retainer into open hole&leave+/-50 feet cement on top of the retainer. A bridge plug will be set+/-500 feet from the surface inside the 7-5/8"casing with cement laid on top of it back to surface before rigging down the BOP&installing a dry hole tree for post rig P&A work. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR Sundry to Abandon. 2. A proposed work program 3. Updated wellbore isolation schematic. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 or Chip Alvord at 265-6120. Sincerely 411/1/6. -no Scott Brunswick Drilling Engineer Attachments cc: Moraine#1 Well File/Sharon Allsup-Drake ATO 1530 Chip Alvord ATO 1570 Dan Bearden ATO 1558 • S Moraine #1 Permanent Abandonment ConocoPhillips .n Gen V Brunswick 2/27/15 16"Conductor: RKB 28 ft N9ES 16"62.6#H-40 Cement Laid on Top of Bridge Plug wl 11 ppg ALC to Surface 114' MD Cap must be a minimum of150ft Bridge Plug Set @-500' Build to 15.97°@ 29.22°drop back to 0°by surface casing point e ,bep0 Cement Laid on Top of Retainer w/15.8 Class G f/2,400'to 2,300' Cap above retainer must be @ least 50' Must be tested to 1500 psi minimum&24 hours notice to AOGCC Surface Casing: Cement Retainer Set @-2,400'(no less than 50'&no more than 9-5/8"40#L-80 HYD563 100'above casing shoe) 2,485.21'MD/2,441'TVD @ 0° Squeezed P&A Plug w/15.8 Class G f/2,600'to 2,400' Volume of cement must be able to fill @ least 100'below the casing shoe 620 P&A Plug#3 w/15.8 Class G f/4,410'to 3,810' K-3!Top Coyote 4128'MD!4084'SSTVD Top plug must be at minimum 100'above all hydrocarbon bearing formations,&tagged with AOGCC 24 hour notice to 77-3 witness K 3Iote C Hydrocarbon Possible K-3/Coyote Y Y P&A Plug#2 wl 15.8 Class G f/5,010'to 4,410' Moraine Top 5150'MD 5107'SSTVD P&A Plug#1 w/15.8 Class G f/TD @ 5,610'to 5,010' Moraine Predicted Pore Pressure:8.7 ppg Moraine Bottom 5387'MD 5302'SSTVD Total Depth 5.610'MD la 0° 8-W Open Hole • • Conochilhips Plug & Abandon Program 1. Plug& Abandon Procedure Post PTD 214-198 Notify AOGCC 24 Hours in advance of all well P&A operations. Hold pre job meeting with all personnel to discuss objectives, as well as safety and environmental issues. ii. Cut off wellhead and all casing strings at 3 feet below ground level. Verify cement is at surface in all strings. Send casing head with stub to Materials for repair/redressing. ph,71-0 doe tz11-1 PP-1 7' iii. Weld 1/4"thick cover plate (at least 16" in diameter) over all casing strings with the following information bead welded into the top. ph o tU do c � r� • ConocoPhillips Alaska, Inc. • Moraine#1 • PTD# 214-198 • API# 50-103-20699-00-00 Remove cellar. Back fill cellar with gravel as needed. Clear ice pad location and demob all materials/equipment. Call agencies for final inspection. p h a to d v c v ten_f Moraine#1 —Exploration Well Page 1 of 1 Drilling Program v1.1 (2/23/2015) • • B'ettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, March 04, 2015 12:03 PM To: Loepp, Victoria T (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: Moraine 1 (PTD 214-198) Plugs Attachments: Moraine_1_Log_Data3.pdf They didn't have the "Coyote" on the log they sent me earlier. From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, March 04, 2015 9:35 AM To: Grimaldi, Louis R(DOA) Cc: Bettis, Patricia K (DOA); Brunswick, Scott A Subject: [EXTERNAL]Moraine 1 (PTD 214-198) Plugs Importance: High Lou, AOGCC needs to see the logs to determine plug placement. Scott Brunswick is no longer the contact. So plugging operations are not delayed, please find out the G&G contact who can deliver the logs immediately to the AOGCC for review. Patricia Bettis will be reviewing the logs. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, March 04, 2015 11:49 AM To: Bettis, Patricia K (DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: Moraine-1 K-3 to base Moraine GR-RES_mudlog Patricia The short answer is that there were oil shows when looking at cuttings while drilling. We took the time to attempt to acquire samples with the E-Line RDT, but were unable to extract fluids. I heard it appeared to be tight when they tried for the samples. What I've done with the updated abandonment plan (sent schematic with the 10-403 last week), is I took the top the geologist called on the "Coyote" and planned our cement top of the third plug we are pumping shortly to be at 3898' MD. That would be about 230 ft above their top Coyote. This is assuming a gauge hole, and we planned 40%excess on all three plugs. We'll tag the top of the third plug to make double sure we are above that "Coyote". If needed, we'll pump more cement as needed and/or required. Thanks Scott Original Message From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, March 04, 2015 11:01 AM To: Brunswick, Scott A Subject: [EXTERNAL]FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Scott, Did ConocoPhillips see any hydrocarbons in the Nanushuk/"Coyote" interval? If so, please provide the gamma ray/resistivity curves for this interval. Thank you, Patricia Original Message From: Loepp,Victoria T(DOA) Sent: Wednesday, March 04, 2015 10:51 AM To: Bettis, Patricia K(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Original Message From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, March 04, 2015 10:49 AM 1 • To: Loepp,Victoria T(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Sent with Good (www.good.com) From: Akindipe,Tunde Sent: Wednesday, March 04, 2015 1:46:43 PM To: Brunswick, Scott A Cc: Mishra, Ashok K; Long, Ashley M; Seitz, Brian Subject: Moraine-1 K-3 to base Moraine GR-RES_mudlog Thanks Best Regards Tunde Akindipe ConocoPhillips Alaska Staff Petrophysicist Exploration Evaluation and Operations 700 G Street, ATO 1434,Anchorage, AK 99501 Cell: 9072679657 I Office: 9072634942 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, March 04, 2015 11:47 AM To: 'Brunswick, Scott A'; Akindipe, Tunde; Seitz, Brian; Long, Ashley M; Mishra, Ashok K Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: RE: Moraine-1 K-3 to base Moraine GR-RES_mudlog Scott, The AOGCC classifies the Moraine-1 well as a development well under 20 AAC 25.005(b). Permit to Drill 214-198 was approved on January 29, 2015 for the drilling of the Moraine-1 development well. Therefore,the geologic data and logs for the Moraine-1 well are not confidential. Thank you, Patricia Original Message From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, March 04, 2015 11:11 AM To: Akindipe,Tunde; Seitz, Brian; Long, Ashley M; Mishra, Ashok K Cc: Bettis, Patricia K (DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog G&G group Please provide Patricia with an answer to hydrocarbon bearing Coyote or not. Patricia,they would like to send you another log with confidential marker on it as they forgot to put that label on the first copy. Thanks Scott Original Message From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, March 04, 2015 11:01 AM To: Brunswick, Scott A Subject: [EXTERNAL]FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Scott, Did ConocoPhillips see any hydrocarbons in the Nanushuk/"Coyote" interval? If so, please provide the gamma ray/resistivity curves for this interval. Thank you, Patricia 1 • --Original Message From: Loepp, Victoria T(DOA) Sent: Wednesday, March 04, 2015 10:51 AM To: Bettis, Patricia K (DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Original Message From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, March 04, 2015 10:49 AM To: Loepp,Victoria T(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Sent with Good (www.good.com) From: Akindipe,Tunde Sent: Wednesday, March 04, 2015 1:46:43 PM To: Brunswick, Scott A Cc: Mishra, Ashok K; Long, Ashley M; Seitz, Brian Subject: Moraine-1 K-3 to base Moraine GR-RES_mudlog Thanks Best Regards Tunde Akindipe ConocoPhillips Alaska Staff Petrophysicist Exploration Evaluation and Operations 700 G Street, ATO 1434, Anchorage, AK 99501 Cell: 90726796571 Office: 9072634942 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, March 04, 2015 11:01 AM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Attachments: Moraine_1_Log_Data3.pdf Scott, Did ConocoPhillips see any hydrocarbons in the Nanushuk/"Coyote" interval? If so, please provide the gamma ray/resistivity curves for this interval. Thank you, Patricia Original Message From: Loepp,Victoria T(DOA) Sent: Wednesday, March 04, 2015 10:51 AM To: Bettis, Patricia K (DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Original Message From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, March 04, 2015 10:49 AM To: Loepp,Victoria T(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Sent with Good (www.good.com) From: Akindipe,Tunde Sent: Wednesday, March 04, 2015 1:46:43 PM To: Brunswick, Scott A Cc: Mishra, Ashok K; Long, Ashley M; Seitz, Brian Subject: Moraine-1 K-3 to base Moraine GR-RES_mudlog Thanks Best Regards Tunde Akindipe ConocoPhillips Alaska Staff Petrophysicist Exploration Evaluation and Operations 700 G Street, ATO 1434, Anchorage, AK 99501 Cell: 90726796571 Office: 9072634942 4 S Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, March 04, 2015 9:17 AM To: 'Brunswick, Scott A' Cc: Loepp, Victoria T (DOA) Subject: RE: Moraine 1 (PTD 214-198) Sundry Application Scott, In order to evaluate CPAI's Sundry Application for cement plug placement,the AOGCC needs to review the logs. Thank you, Patricia From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Tuesday, March 03, 2015 5:22 PM To: Bettis, Patricia K (DOA) Cc: Loepp, Victoria T(DOA) Subject: RE: Moraine 1 (PTD 214-198) Sundry Application Patricia I apologize for the delayed response, I'm in a course all this week. I passed the request to the G&G group,they mentioned they were going to deliver all logs in a package. As they're treating this well internally as exploration, I've relinquished control of formation evaluation to the G&G group. Is there a time frame that you need the "Coyote" section? Thanks Scott From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, March 02, 2015 3:29 PM To: Brunswick, Scott A Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]Moraine 1 (PTD 214-198) Sundry Application Good afternoon Scott, Can you email a pdf of the MWD gamma ray/resistivity curves and mud log from top K-3 "Coyote"to Base Moraine for review by the AOGCC. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist 1 • • Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Tuesday, March 03, 2015 5:22 PM To: Bettis, Patricia K (DOA) Cc: Loepp,Victoria T (DOA) Subject: RE: Moraine 1 (PTD 214-198) Sundry Application Patricia I apologize for the delayed response, I'm in a course all this week. I passed the request to the G&G group, they mentioned they were going to deliver all logs in a package. As they're treating this well internally as exploration, I've relinquished control of formation evaluation to the G&G group. Is there a time frame that you need the "Coyote" section? Thanks Scott From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, March 02, 2015 3:29 PM To: Brunswick, Scott A Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]Moraine 1 (PTD 214-198) Sundry Application Good afternoon Scott, Can you email a pdf of the MWD gamma ray/resistivity curves and mud log from top K-3 "Coyote"to Base Moraine for review by the AOGCC. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, March 02, 2015 3:28 PM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Cc: Loepp,Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: Moraine 1 (PTD 214-198) Sundry Application Good afternoon Scott, Can you email a pdf of the MWD gamma ray/resistivity curves and mud log from top K-3 "Coyote"to Base Moraine for review by the AOGCC. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e/A 3f zo/5 DATE: March 5, 2015 P.I. Supervisor SUBJECT: Plug &Abandonement FROM: Chuck Scheve Moraine#1 Petroleum Inspector CPAI Exploration PTD 214-198 - NON- CONFIDENTIAL Section: 12 Township: 12N Range: 7E - Meridian: UM Lease No.: ADL0025528 - Drilling Rig: Nabors 9ES Rig Elevation: Total Depth: 5610 ft MD/TVD Operator Rep.: Casing/Tubing Data: Casing Removal: Conductor: O.D. Shoe@ Casing Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2486 ft - Casing Cut@ N/A Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: O.D. Tail@ Casing Cut@ Feet Plugging Data: Type Plug Founded on Bottom Top of Cement Mud Weight Pressure (bottom up) of Cement Depth Verified? above plug Test Applied Open Hole Bottom 5610 ft 3687 ft Drillpipe Tag Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Casing Stub Retainer No The open hole cement plug had been spotted in 3 stages from TD 5610 ft to an estimated top of cement 3570 ft. Drilpipe was run in the hole and encountered green cement at 3620 ft. Cement was washed and worked down to 3687 ft where solid cement -- was was tagged several times with 15K drill pipe weight. :5/28/00 by L.R.G. 2015-0305_Abandon_Moraine#1_cs.xlsx 3/20/2015 • • Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, March 04, 2015 12:03 PM To: Loepp,Victoria T(DOA) Cc: Bettis, Patri:ia K(DOA) Subject: RE: Moraine 1 (PTD 214-198) Plugsa Attachments: Moraine_l_Log_Data3.pdf Follow Up Flag: Follow up Flag Status: Flagged They didn't have the "Coyote" on the log they sent me earlier. From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, March 04, 2015 9:35 AM To: Grimaldi, Louis R(DOA) Cc: Bettis, Patricia K(DOA); Brunswick, Scott A Subject: [EXTERNAL]Moraine 1 (PTD 214-198) Plugs Importance: High Lou, AOGCC needs to see the logs to determine plug placement. Scott Brunswick is no longer the contact. So plugging operations are not delayed, please find out the G&G contact who can deliver the logs immediately to the AOGCC for review. Patricia Bettis will be reviewing the logs. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepio alaska.gov 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 Victoria Loepp at(907)793-1247 or VictorialoerDppalaska,gov 1 • • Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, March 04, 2015 11:49 AM To: Bettis, Patricia K(DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: Moraine-1 K-3 to base Moraine GR-RES_mudloga Follow Up Flag: Follow up Flag Status: Flagged Patricia The short answer is that there were oil shows when looking at cuttings while drilling. We took the time to attempt to acquire samples with the E-Line RDT, but were unable to extract fluids. I heard it appeared to be tight when they tried for the samples. What I've done with the updated abandonment plan (sent schematic with the 10-403 last week), is I took the top the geologist called on the"Coyote" and planned our cement top of the third plug we are pumping shortly to be at 3898' MD. That would be about 230 ft above their top Coyote. This is assuming a gauge hole, and we planned 40%excess on all three plugs. We'll tag the top of the third plug to make double sure we are above that"Coyote". If needed, we'll pump more cement as needed and/or required. Thanks Scott Original Message From: Bettis, Patricia K (DOA) [mdiitc -atricia.bettis@aiasKa.go,] Sent:Wednesday, March 04, 2015 11:01 AM To: Brunswick,Scott A Subject: [EXTERNAL]FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Scott, Did ConocoPhillips see any hydrocarbons in the Nanushuk/"Coyote" interval? If so, please provide the gamma ray/resistivity curves for this interval. Thank you, Patricia Original Message From: Loepp,Victoria T(DOA) Sent:Wednesday, March 04, 2015 10:51 AM To: Bettis, Patricia K(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Original Message 2 • From: Brunswick,Scott A[mailto: cott.A.Brunswick@conoconhillips.com] Sent:Wednesday, March 04, 2015 10:49 AM To: Loepp,Victoria T(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Sent with Good (www.good.com) From: Akindipe,Tunde Sent:Wednesday, March 04, 2015 1:46:43 PM To: Brunswick,Scott A Cc: Mishra,Ashok K; Long,Ashley M; Seitz, Brian Subject: Moraine-1 K-3 to base Moraine GR-RES_mudlog Thanks Best Regards Tunde Akindipe ConocoPhillips Alaska Staff Petrophysicist Exploration Evaluation and Operations 700 G Street,ATO 1434,Anchorage,AK 99501 Cell: 9072679657(Office: 9072634942 3 • • Loepp, Victoria T (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, March 04, 2015 11:47 AM To: Brunswick, Scott A;Akindipe,Tunde; Seitz, Brian; Long, Ashley M; Mishra, Ashok K Cc: Loepp,Victoria T(DOA) Subject: RE: Moraine-1 K-3 to base Moraine GR-RES_mudlog Follow Up Flag: Follow up Flag Status: Flagged Scott, The AOGCC classifies the Moraine-1 well as a development well under 20 AAC 25.005(b). Permit to Drill 214-198 was approved on January 29, 2015 for the drilling of the Moraine-1 development well. Therefore,the geologic data and logs for the Moraine-1 well are not confidential. Thank you, Patricia Original Message From: Brunswick,Scott A [_ailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, March 04, 2015 11:11 AM To:Akindipe,Tunde; Seitz, Brian; Long,Ashley M; Mishra,Ashok K Cc: Bettis, Patricia K (DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog G&G group Please provide Patricia with an answer to hydrocarbon bearing Coyote or not. Patricia,they would like to send you another log with confidential marker on it as they forgot to put that label on the first copy. Thanks Scott Original Message From: Bettis, Patricia K(DOA) [ ailto:patricia.bettis@alaska.gov] Sent:Wednesday, March 04, 2015 11:01 AM To: Brunswick,Scott A Subject: [EXTERNAL]FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Scott, Did ConocoPhillips see any hydrocarbons in the Nanushuk/"Coyote" interval? If so, please provide the gamma ray/resistivity curves for this interval. 4 • • Thank you, Patricia Original Message From: Loepp,Victoria T(DOA) Sent: Wednesday, March 04, 2015 10:51 AM To: Bettis, Patricia K(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Original Message From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.cor Sent:Wednesday, March 04, 2015 10:49 AM To: Loepp,Victoria T(DOA) Subject: FW: Moraine-1 K-3 to base Moraine GR-RES_mudlog Sent with Good (www.good.com) From: Akindipe,Tunde Sent:Wednesday, March 04, 2015 1:46:43 PM To: Brunswick,Scott A Cc: Mishra,Ashok K; Long,Ashley M; Seitz, Brian Subject: Moraine-1 K-3 to base Moraine GR-RES_mudlog Thanks Best Regards Tunde Akindipe ConocoPhillips Alaska Staff Petrophysicist Exploration Evaluation and Operations 700 G Street,ATO 1434,Anchorage,AK 99501 Cell: 90726796571 Offi ce: 9072 634942 5 PTO 214-11s, Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, March 04, 2015 9:42 AM To: Loepp,Victoria T(DOA); Grimaldi, Louis R(DOA); Mishra,Ashok K; Long,Ashley M; Seitz, Brian Cc: Bettis, Patricia K(DOA) Subject: RE: Moraine 1 (PTD 214-198) Plugs Importance: High Follow Up Flag: Follow up Flag Status: Flagged Ashley&Ashok We need to get the AOGCC a copy of the Moraine#1 logs for them to confirm our planned cement plug placement for the current rig operations. Thanks Scott From: Loepp, Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent: Wednesday, March 04, 2015 9:35 AM To: Grimaldi, Louis R(DOA) Cc: Bettis, Patricia K(DOA); Brunswick, Scott A Subject: [EXTERNAL]Moraine 1 (PTD 214-198) Plugs Importance: High Lou, AOGCC needs to see the logs to determine plug placement. Scott Brunswick is no longer the contact. So plugging operations are not delayed, please find out the G&G contact who can deliver the logs immediately to the AOGCC for review. Patricia Bettis will be reviewing the logs. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaa laska.qov 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 Victoria Loepp at(907)793-1247 or Victoria.[oepp©alaska.gov 6 • i S i' Weatherford LABORATORIES 3209 Denali St. Anchorage,AK 99503 Office: (907)646-8605 File No.: HH-75558 Conoco-Phillips Moraine 1,North Slope, AK Date: 2/24/15 Material Shipping Record State of AK samples 5100-5171 Core 1 5174-5259 Core 2 5261-5295 Core 3 Weatherford Labs Contact: Dave Foster(307) 265-8800 (907) 646-8605 Ship From: Weatherford Lab 3209 Denali St. Anchorage, AK 99503 Ship To: Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 (907) 279-1433 •Fax (907) 276-7542 RECEIVED FEB 272015 Received by: Angela K. Singh. Date: AO CC Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Thursday, February 12, 2015 8:14 AM To: Loepp, Victoria T (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: Moraine#1 PTD 214-198 Surface Casing Follow Up Flag: Follow up Flag Status: Flagged Good morning We pumped our surface cement job last night with no issues,cement to surface, plugs bumped,floats held. Let me know if you need further information or to simply include in the end of well reports. Casing was landed on the hanger at the initial proposed depth 10 ft off bottom once we worked passed the ledge. Thanks Scott From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, February 11, 2015 11:39 AM To: Brunswick, Scott A Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]RE: Moraine #1 PTD 214-198 Surface Casing Scott, Approval is granted to cement the surface casing in place and move forward with planned LOT. Let us know if the surface cement job does not go as planned or if cement is not to surface. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(UZalaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov From: Brunswick, Scott A [ma: att.A.Brunswick@conocophillips.com] Sent: Wednesday, February 11, 2015 11:31 AM 1 O . Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, February 11, 2015 4:28 PM To: Loepp, Victoria T (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: Moraine#1 PTD 214-198 Surface Casing Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria Update: The rig didn't give up and while waiting on a 10' pup joint to arrive,they managed to work the last two joints of casing to bottom. We will proceed& pick up another joint of casing to clean the well up(in case we cannot move down we would have the option for emergency slips). If we have no further issue,we will pick up the landing joint, pump cement as per original plan, and land casing on the hanger with the shoe+/- 10'off bottom as planned before we encountered the obstruction. Thank you for you review& approval today. Scott From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, February 11, 2015 11:39 AM To: Brunswick, Scott A Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]RE: Moraine #1 PTD 214-198 Surface Casing Scott, Approval is granted to cement the surface casing in place and move forward with planned LOT. Let us know if the surface cement job does not go as planned or if cement is not to surface. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�.alaska.gov 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 1 • • 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 Victoria Loepp at(907)793-1247 or Victoria.LoeQo@alaska.gov From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, February 11, 2015 11:31 AM To: Loepp, Victoria T(DOA) Subject: RE: Moraine #1 PTD 214-198 Surface Casing Thanks. From: Loepp, Victoria T(DOA) [mailto::victoria.loepp@alaska.gov] Sent: Wednesday, February 11, 2015 11:24 AM To: Brunswick, Scott A Subject: [EXTERNAL]RE: Moraine #1 PTD 214-198 Surface Casing From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, February 11, 2015 10:39 AM To: Loepp, Victoria T(DOA) Cc: Bearden, J Daniel; Alvord, Chip Subject: Moraine #1 PTD 214-198 Surface Casing Victoria We TD'ed the Moraine#1 surface hole and ran the 9-5/8" surface casing throughout the day yesterday. At a shoe depth of 2392' MD /2349' RKB TVD/2307'SSTVD we encountered what appears to be a hard spot or ledge. We have worked on getting the casing further in the hole since last night @ 22:30 to no further progress, using rotation, circulation, and applying weight. If we were to set the surface casing here and cement in place,the shoe depth would be 2380.41' MD/^'2339'TVD/ 2297'SSTVD. TD of the hole section was 2495' MD/2451'TVD/2409' SSTVD. If we were able to get the casing to bottom, planned casing setting depth was 2484.85' MD/2440' RKBTVD/2398' SSTVD. I believe I will need approval from the AOGCC to approve the rig to move forward and cement the surface casing in place. Pulling the casing& performing a clean out run are not good options due to risk of leaving junk in hole (bow spring centralizers), and surface hole deteriorate over time reducing the chance that we could recover the hole requiring and plug back& re-drill. I have attached a TVD log for evaluation. 2 • • We would follow LOT/FIT procedures, and if any issues or below the 12.5 ppg EMW we would perform a squeeze on the shoe. We can supply further information to assist in the AOGCC decision upon request. Thanks Scott 907-227-8499 907-263-4249 3 • pTP 2l4—! .7 ( Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Friday,January 30, 2015 11:26 AM To: 'Brunswick, Scott A' Cc: Regg, James B (DOA) Subject: RE: Moraine#1 PTD 214-198 Scott, You are correct; weekly BOPE testing is required for Moraine#1. Thanx, Victoria From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Friday, January 30, 2015 11:15 AM To: Loepp, Victoria T(DOA) Subject: Moraine #1 PTD 214-198 Victoria Received the Moraine#1 PTD 214-198 this morning. Thank you. I had a question though, it doesn't state on the PTD at the bottom of the 10-401 form to test the BOPE weekly. I have it written in my program to test weekly, I just wanted to make sure that weekly test is required as opposed to bi-weekly as I believe the regulations state when on an ice pad. Am I correct? Thanks Scott yOF Ty 411 \� I//je sv THE STATE Alaska Oil and Gas o fConservation Commission ALAcKA _I= 333 West Seventh Avenue " o F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rti Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Graham(Chip) Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Torok Undefined Oil Pool, Moraine#1 Development Well ConocoPhillips Alaska, Inc. Permit No: 214-198 Surface Location: 4620.3' FNL, 4367.6' FEL, SEC. 12, T12N, R7E, UM Bottomhole Location: 4620.3' FNL, 4367.6' FEL, SEC. 12, T12N, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Conservation Order No. 713 was issued January 26, 2015. All dry ditch sample sets submitted to the AOGCC 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. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Mud log will be required from base of conductor to total depth. H2S analysis of hydrocarbon is required as a condition of the permit to drill application. 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 AOGCC 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 AOGCC's internal use. • S Permit No:214-198 Page 2 of 2 Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this Ay of January, 2015. RECEIVED STATE OF ALASKA *KA OIL AND GAS CONSERVATION COMOION DEC 0 1 2014 PERMIT TO DRILL "" Z1).1/24)_,20 AAC 25.005 r1 a.Type of Work: 1 b. Proposed Well Class: Development-Oil Service- Winj ❑ Single Zone ❑✓ • 1 c.Specify if well is proposed for: Drill 0Lateral ❑ Stratigraphic Test 0 Development-Gas E] Service-Supply ❑ Multiple Zone Li Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: ''-,;3 5. Bond: Blanket D. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc. ' Bond No. 59-52-180 • Moraine#1 3.Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 5698' TVD: 5655' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Undefined Mae-Oil Pool Surface: 4620.3'FNL,4367.6'FEL,Sec12,T12N,R7E,UM ADL025528 - TOi°ic- fa Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4296.4'FNL,4186.3'FEL,Sec12,T12N, R7E,UM ADL2639 1/10/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4296.4'FNL,4186.3'FEL,Sec12,T12N, R7E,UM ' 2560 659' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL:3877- 55 feet -`" 15.Distance to Nearest Well Open Surface: x-468098.36' y-5997105.08 Zone-4 GL Elevation above MSL:1.8?'9,7• feet to Same Pool: 3198'to 3S-19 16.Deviated wells: Kickoff depth: 400 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 15.97 degrees Downhole: 2646 Surface: 1638 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 65.5# H-40 Welded -80' Surf Surf 114' 114' Driven/to Surface 12-1/4" 9-5/8" 40# L-80 BTCM -2514' Surf Surf 2548' 2500' 179 sx LiteCrete 1038 sx A LiteCRETE 8-1/2" N/A N/A N/A N/A N/A N/A N/A 5698' 5655' Plug#1,2,&3 283 sx Class G sx Class G,Squeeze&top Retainer 104 sx Class G,Surf 95 sx 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 TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Ell Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 12/1/2014 22. I hereby certify that the foregoing is true and correct. Scott Brunswick 263-4249 Contact scott.a.brunswick(c@cop.com Email Printed Name Graham(Chip)Alvord Title ConocoPhillips Alaska Drilling Manager Signature „46, ed` Phone 265-6120 Date 12/1/2014 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: Q 1 W- 11. ? 50- 03- (ZD Vic/ -oo -00 Date: I y�Jq \. requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbe ethane,gas hydrates,or gas contained in shales: V Other: 8 D p f-_cS f to 3 5-0 O p 5 r Samples req'd: Yes No❑ Mud log req'd:Yes No❑ AKJvcv1av pr-rve l.fr 1--,-5f o 25-6)0 p5 -12S S measures: Yes ❑ No[Z1Directional svy req'd:Yes No❑ . Spacing exception req'd: Y s No❑ Inclination-only svy req'd:Yes❑ No 2" (-0 7/3 l'sst ,VI a(a jI. APPROVED BY / Approved by. /A .2, ,,`� COMMISSIONER THE COMMISSION Date:/_2?-115- PTC. ?/S !/Tc 26 /5- I I*lis AA. -.29-'s Submit Form and Form 10-401(-evised 10/2012) This permit is valid for 24 months o t)e d,t�e-ooff approval(20 AAC 25.005(g)) Attachments in Duplicate �l9/�✓ • ConocoPhillips Alaska, Inc.• Post Office Box 100360 Anchorage,Alaska 99510-0360 RECEIVED ConocoPhillips Telephone 907-276-1215 DEC 012014 December 1, 2014 Alaska Oil and Gas Conservation Commission AOG C m- 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Moraine#1 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore core&formation evaluation well Moraine#1 from an ice constructed drilling pad. The intended spud date for this well is January 10th,2015 using Nabors Rig 9ES. Moraine#1 is planned to be a S-shaped well taking cores of the Moraine formation. A roughly 2 mile ice road&pad will be constructed with a 16"conductor set before the rig arrives on location. The surface hole will be drilled as a 12-1/4" hole with 9- 5/8"surface casing run&cemented to surface. The surface casing will be the only casing string set in Moraine#1. The production or coring interval will be drilled with an 8-1/2"bit to+/-50 feet TVD above the Moraine formation. Once @ coring point two each +/- 180 foot 4"core samples will be taken of the Moraine formation and some of the overburden just above the Moraine. An extensive E-Line program will be undertaken once enough rat hole is drilled after the cores have been taken. The well will be permanently plugged&abandoned once all data has been acquired. The plan is to pump three each +/-500 foot cement isolation plugs on bottom to bring cement at minimum 100 feet above all potential hydrocarbon bearing formations. The rig will then set a cement retainer+/- 100 feet inside the surface casing and squeeze+/-200 feet of cement below the retainer into open hole&leave+/-50 feet cement on top of the retainer. A bridge plug will be set+/-500 feet from the surface inside the 7-5/8"casing with cement laid on top of it back to surface before rigging down the BOP&installing a dry hole tree for post rig P&A work. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005(a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer Attachments cc: Moraine#1 Well File/Sharon Allsup-Drake ATO 1530 Chip Alvord ATO 1570 Dan Bearden ATO 1558 ORIGINAL • Ap•on for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 Moraine #1 Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (fl) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 3 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC 25005 (c)(5)) 4 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 6 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 (Requirements of 20 AAC 25.005 (c)(14)) 8 Moraine#1 APD ORIGINAL Pagelofl6 ed: 1-Dec-14 • ApOon for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Well Schematic 8 Attachment 4 Cement Summary 8 Attachments TD Curves 8 Attachment6 Proposed Ice Road&Pad route 8 Moraine#1 APD QRIGINALPrintedg1-Decf14 • App•on for Permit to Drill,Well Moraine Saved: 1-Dec-14#11 1. Well Name (Requirements of 20 AAC 25.005(/)) The well for which this application is submitted will be designated as Moraine#1. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a Moraine core&formation evaluation well. Please note that pad elevation will be updated once ice pad construction has completed,this will affe ct RKB elevation. Location at Surface 4620.3' FNL, 4367.6'FEL, Sec 12, T12N,R7E,UM NAD 1927 RKB Elevation 55'AMSL Northings: 5,997,105.08' Eastings: 468,098.36' Pad Elevation 27'AMSL Location at top of Moraine productive 4296.4'FNL,4186.3'FEL,Sec 12,T12N,R7E,UM horizon Nad 1927 Measured Depth, RKB: 5,247.94' Northings: 5,997,428.17' Eastings:468,280.87' Total Vertical Depth, RKB: 5,205.00' Total Vertical Depth, SS: 5,150.00' Location at Total Depth 4296.4'FNL,4186.3'FEL, Sec 12,T12N,R7E,UM Nad 1927 Measured Depth, RKB: 5,697.94' Northings: 5,997,428.17' Eastings:468,280.87' Total Vertical Depth, RKB: 5,655.00' Total Vertical Depth, SS: 5,600.00' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Csg Setting Fracture Pore Casing Depth Gradient pressure ASP Size MD/TVD(ft) (lbs./ (psi) Drilling (in) gal) (psi) 16 114/ 114 10.9 52 53 9-5/8 2505/2505 14.5 1133 883 N/A 5655/5655 12.5 2646** ' 1638 • NOTE:The Nabors 9ES 5000 psi BOP equipment is adequate.Test BOP to 3500 psi. • ** NOTE: Pore Pressure is estimated reservoir pressure -/ PROCEDURE FOR CALCULATING ANTIC)PATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: Moraine#1 APD OR GINAL Printed:g1-Dec-14 • Appeon for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 1) ASP=[(FG x 0.052)-0.1]D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP—(0.1 x D) Where; FPP=Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP=[(FG x 0.052)—0.1]D =[(10.9 x 0.052)—0.1]x 114=53 psi OR ASP=FPP—(0.1 x D) =(.052*2505*8.7)—(0.1 x 2505')=883 psi 2. Drilling below surface casing(9-5/8") ASP=[(FG x 0.052)—0.1] D =[(14.5 x 0.052)—0.1]x 2505= 1638 psi OR ASP=FPP—(0.1 x D) =(.052*5655*9.0)—(0.1 x 5655')=2081 psi (B)data on potential gas zones; Please see Attachment 2-Drilling Hazards Summary (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out casing shoes and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. O R I G I N A L Moraine#1 APD Page 4 of 16 Printed: 1-Dec-14 Apreon for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 6. Casing and Cementing Program (Requirements of 20AAC25.005(c)(6)) Morain#1 casing and cementing program: Casing and Cementin Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 24 65.5 H-40 Welded 114' Surf 114'/114' Cemented to Surface with 9-5/8" i�4„ 40 L-80 BTCM 2505' Surf 250572505' 291 ft3 12 ppg LiteCRETE Tail&2003 ft3 Arctic LiteCRETE 11 ppg Lead Cement Abandoned N/A 8-1/2" N/A N/A N/A 5655' Surf 5655'/5655' See Attachment 4 Cement Summary 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Nabors 9ES. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using mud systems having the following properties: A WBM Spud mud will be used to drill the 12-1/4"surface hole section. A standard high viscosity fresh water gel spud mud is planned for drilling the surface interval. Flow line viscosity will be kept at+/-300 sec/qt while drilling the gravels. Viscosity to cementing will be reduced to+/- 80-100 sec/qt. Mud weight @ spud will be 8.7 ppg and weighted up to 9.6-9.8 ppg as drilling progresses. The mud system may be weighted up to 10 ppg for trip out of hole and casing run. Using cold make up water will assist in keeping the flow line temperature as low as possible. LSND Mud 114'—2548' Density(ppg) 8.7—9.8 1 Yield Point(cP) 60-80 Plastic Viscosity(cP) 20—60 Funnel Viscosity 75—250 Initial Gels 10—35 10 minute gels </=20 API filtrate NC- 10 cc/30 min An inhibitive WBM mud system will be used to drill the 8-1/2"hole&coring section. An inhibited fresh water mud system is to be used for the production/coring section in order to increase hole stability&decrease mud invasion of the core samples.Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists. Mud weight will be maintained in the 9.4-9.6 ppg range to minimize losses,and lost circulation material will be introduced to the system if necessary.Good filter cake quality,hole cleaning and maintenance of low drill solids(by diluting as required)will all be beneficial in maintaining wellbore stability. MW may be increased if formation pressure dictates. Kla-Shield Mud 2548'—5698' Density(ppg) 9.4—9.6 Moraine#1 APD On i}•(� Printed: 1-Dec-14 • Apillon for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 Yield Point(cP) 13 -22 Plastic Viscosity(cP) 10- 16 Initial Gels 8- 10 10 minute gels <1=20 API filtrate <8 cc/30 min Diagram of Nabors 9ES 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)) There are no predicted abnormally geo-pressured strata. Further information may be supplied upon request. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) See attachment 1—Moraine Core#1 TD Curves,further information may be supplied upon request. At this time no abnormally geo-pressured zones are expected while drilling the Moraine#1 well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. d 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) 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)) The proposed drilling program is listed below. Please refer to Well Schematics. 1. Move & Rig up Nabors 9ES rig onto ice pad location where a 16" conductor has been installed. Well name Moraine#1. 2. N/U&function test the diverter system&prepare 9.6 ppg fresh water spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. P/U 5 drillpipe needed to drill surface hole. 5. Drill 12-1/4"hole to the surface casing point as per the directional plan. (Directional/MWD/GWD/GR/RES) 6. Run and cement the 9-5/8"surface casing. 7. Lay down all 5"drill pipe. 8. Nipple up BOPE. 9. Perform full BOPE test to 250/3500 psi(250/2500 psi on the annular)using 4"test joint. 10. Pick up and rack back all 4"drillpipe needed to drill the production/coring hole section. 11. Make up the directional BHA to include RSS,MWD,GR/RES/PWD/NEUT/DENS. 12. TIH with BHA. 13. Once cement is tagged,close the top pipe rams and test the casing to 3,000 psi for 30 minutes. 14. Chart and send in the pressure test. ORIGINAL Moraine#1 APD Page 6 of 16 Printed: 1-Dec-14 • Aprl!Ion for Permit to Drill, Mr Saved:Well o 1-Dec-14aine#11 15. Drill out shoe track and 20 ft.new formation. 16. Circulate and condition mud until even in and out. 17. Perform a leak off test, stopping if reaching 16 ppg EMW. 18. Monitor well for flow for 30 minutes. 19. Begin drilling hole section as per directional plan. Displace well from surface hole spud mud to 9.4 ppg Kla- Shield mud system while drilling ahead. 20. Drill the 8-1/2"hole to 50 ft TVD above the Moraine formation. 21. CBU X3. 22. POOH with directional BHA, download data,and lay down same. 23. Pick up coring BHA#1 consisting of 180 foot core barrel. 24. Trip core BHA in hole. 25. Stop near bottom&swap mud over to Kla-Shield coring fluid. 26. Drill first core section,targeting 180 ft,leave option open to take-50 feet core of overburden above Moraine formation&POOH. 27. Pull core out of hole&prepare @ surface for shipping. 28. Pick up coring BHA#2 consisting of 180 foot core barrel. 29. Trip in hole&condition mud near bottom. 30. Drill final 180 foot core section. 31. Pull core out of hole&prepare @ surface for shipping. 32. Pick up clean out BHA&trip in hole,BHA to include RSS,MWD,GR/RES/PWD/NEUT/DENS. 33. Circulate above first coring point conditioning mud. 34. Ream BHA down through core section addressing any tight spots. 35. Drill rat hole to+/-5698' MD to accommodate subsequent E-Line logging runs. 36. Once @ TD circulate 3 BU&POOH addressing any tight spots. 37. R/U E-Line&Perform logging runs. 38. R/D E-Line&Perform clean out run prior to cement abandonment of well. 39. L/D clean out BHA&pick up 30 joints of 3-1/2"tubing for cement stinger. 40. Trip in hole with cement stinger to prepare for cement abandonment. 41. Circulate&condition mud before cement abandonment. 42. Pump first&bottom cement plug on bottom w/15.8 ppg Class G cement 600 ft in length(42 bbl). 43. Pull up above plug&circulate string clean. 44. Pump second cement plug on top of first w/15.8 ppg Class G cement 600 ft in length(42 bbl). 45. Pull up above plug&circulate string clean. 46. Pump third cement plug on top of first w/15.8 ppg Class G cement 600 ft in length(42 bbl). 47. Pull up above plug&circulate string clean. 48. POOH with cement stinger. , Q J /"O n p I vcf„j 11° h �y /�O�Z G 49. Pick up and RIH with Cement retainer. fj ( -/ fp7 r 5 5 50. Set retainer inside surface casing at 2,400 ft MD/TVD. Moraine#1 APD ORIGINALPage 7 of 16 Printed: 1-Dec-14 . Ail!Ion for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 51. Perform injectivity test. 52. Sting out&pump 15.8 ppg class G cement. 53. Sting back in once cement nearing retainer. 54. Attempt to squeeze—15 bbls below cement retainer(--200 ft in open hole). 55. Sting out&lay in—3.5 bbl on top of cement retainer(—50 ft inside surface casing). 56. Pick up above cement&circulate pipe clean. 57. POOH&lay down stinger. 58. Rig up&test cement&retainer to 1500 psi for 30 minutes,chart&record. •✓ 59. Pick up&RIH to set bridge plug @—500 ft MD/TVD. 60. Set bridge plug,trip out. 61. Pump final cement P&A plug from bridge plug @ 500 ft to surface(-38 bbl). 62. P/U wash tool&wash BOP stack. 63. Ensure barriers are in place&tested. 64. ND BOPE. 65. N/U dry hole tree&test. 66. L/D all tubulars. 67. Rig down Nabors 9ES. 68. Permanent abandonment of Moraine#1 will be done after the rig leaves location. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (659-7212). 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary Attachments TD Curves Attachment6 Proposed Ice Road&Pad route ALNMorainePage#18of 16 APD Printed: 1-Dec-14 • AppOon for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 Attachment 1— Directional Plan Moraine#1 APD ORIGINAL Page 9 of 16Printed: 1-Dec-14 I • CD .• "" U `. i 0 o C 0 7/1/ .0 a,o > C et Yi - g ___ [ v ''.----1 n ` =_ `Sa c,,,..h >w ill?' a \ )\''''. •0 E— /1/7 o :� .� RLt V ___rrr""""' NI _�:� S lli 1 G O y (01- /I/ wY0 X01. E i Urilel )1\0\ S.. E o; a) ,a 0 L 'tit U °,.2.0 ()\fly ' 40 o cn ---y,___,.._ .__________‘,/,,,,i7.___. __e_. i i'r- ..3r ,,,,, 0 0 o `` 31. cs8 o a ��ayIN r009 .....__„.X.ILTh .0001 1 0 5 z0 -J / m� hF- I tn 1 • • Ct. •Mill 40M1111, CL 0 X W • CZS c+a CU •sa E 3 E o cc Cl N .L L d O �, o 0 0 c c CIS 0 ak z0Z ORIGINAL • • . . 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Sect Target 1 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 Moraine 1 wp02 2 0 0.00 6.00 400.00 0.00 0.00 0.00 0.00 0.00 3 600.09 3.00 29.21 600.00 4.57 2.56 1.50 29.21 5.24 28.00 To 5697.95 4 901.89 9.04 29.21 900.00 32.16 17.99 2.00 0.00 36.87 5 1179.51 15.98 29.21 1170.86 84.63 47.32 2.50 0.01 96.96 6 1853.84-15.98 29.21 1819.14 - 246.64 137.91 0.00 - 0.00 - 282.58 7 2492.95 0.00 0.00 2450.00 323.92 181.12 2.50 180.00 371.12 8 2542.95 0.00 0.00 2500.00 323.92 181.12 0.00 0.00 371.12 Moraine-1 S-shape SB 24Nov14 9:28,November 24 2014 9 5697.95 0.00 0.00 5655.00 323.92 181.12 0.00 0.00 371.12 SURVEY PROGRAM ]epth From Dep.To Survey/PlanTool 500 20.00 50000 Moraine I wp02(Ran:M010IUY) 50000 2505.00 Moraine 1 wp02(Ran:MoraOSMp 500.00 2505.00 Moraine 1 wp02(Ran:MoraiWYwIFR-Ax-CA2.SC 5697.95 569795 Moraine 1 wp02(Ran:Mpai4lYp CASING DETAILS TVD MD Name Size 2505.00 2547.95 9-5/8"x12-1/4" 9-5/8 5655.00 5697.95 7"x 8-1/2" 7 0/360 -30/330 �- -280' _`\ 30 '' , --Ill 2.241-7: '-'''''T-'-----': :N. __ „.„_,.._ _._______ -60/300 /// a :,...,;_r_t_iiiii. 1_,2: +16 \\\\%\60 1/1/77 ,. -__ ,, , _- \\\\\*1\1\\\ /ff !hl P' � \\ !oti 1A III i tr,y it I !I ' I ,w ,11 �''4 'fit( �l' t; a") i, I I i r �te / ill ' 1 � 11sliiimi:.20„._ /\\\\:\ 00 /// i/ _ \Imo � % 'f 120 \ , 120/240 ..•�/ . / , . _ 1/ / .-:,' '-'---... --.. .._-- Mmol II° / :, .' ____Iiummia___----77-- 0 1". 111 e. '' ' 150/210 - .. 150 -180/180 ORIGINAL -e- 9.909.99.05"6 0305 -9 E -9 ]5-14 141 5 9.1006 -a- 99-17,98-112,1 302. -17002 09 ,3523.82304 Q 0546 P01021,P0U31 W. -3E 38093804950805 } 38 -3 .K361205-14 02 -a- 05149.158.1904 4- 36 -e- m 6n.98520,08.52u"n1204 0- 360438091,35002 Ws $ 35 090,0609000 ' 915,39-13.51504 -7t- 40a50.15341904 43". X $ 04100e19.02 -34- 90 -X- 9804 39091.39o00vo 009-1599-14 3.1402 -X- a 321,352104 $ ss W -6- 3500,3808 960909 $ 350,3508 390902 $ .6173617..1106 -8- 4500 092E 3522 01 $ 9829,0824 9.26 V9 • ! Moraine #1 wp02 Surface Location In CFA}:Coordinate Converter 3 it From: - — To: — ---- Datum: INAD27 Region: alaska . Datum: 1NAD27 . Region: lalaska Latitude/Longitude Degrees Minutes Seconds . C Latitude/Longitude Decimal Degrees UTM Zone:r--- ly South r UTM Zone:34_il _ E South • State Plane Zone:14 ...7.1 Units: us-ft , r State Plane Zone: !4 , Units: us-ft C' t rgal Desi:.; ?Oil(NJ €S27 orilid Legal Description(NAD27 only) Starting Coordinates: - ---------- Legal Legal Description ---'-'--'-- x' 1468098.36 Township: '- Ran e: i p ;012 N . 9 1007 E .--A. V: 15997105.08 Meridian: ,U Sectiorr.I12 IFNE . f 4620.3319 1FEL 14367.6468 r Transform j Quit . Help 1 Moraine #1 wp02 9-5/8" Casing Shoe CPA!Coordinate Converter ' i '--i I, ' From: To: Datum: 1NAD27 i Region alaska .qq ' Datum NAD271 Region: {alaska C LatitudelLongitude Degrees Minutes Seconds . T_. Latitude/Longitude Decimal Degrees .f C UTM Zone: 1 r South C UTM Zone: q F South 4' State Plane Zone: }4 - -M-] Units: us-ft 3 C State Plane Zone: 4_ .. Units: us-ft ti C Legal Description(N.611.7 only) ( Legal Description(NAD27 only) Starting Coordinates: - , Legal Description-- -_.~---- X: 1-4-6-8-28-0.87 Township . . IFEA Ranke: 007 E + Y: 997428.17 Meridian: U . Section:112 15:1-17-E 14296.4263 FEL • 14186.3129 ? Transform j Quit I Help ORIGINAL • • Moraine #1 wp02 Top of Moraine �� CPA Coordinate Converter t `� Cl I "' `F° '. From: --- --- To: Datum: ;NAD27 . Region: lalaska .. Datum: INAD27 .i Region: lalaska .' t" Latitude/Longitude [Degrees Minutes Seconds C Latitude/Longitude Decimal Degrees .] I rUTM Zone: E South r UTM Zone: _ (` South r , C State Plane Zone: — Units: us.ft . C State Plane Zone:1-4-7j, Units: us-ft C" Legal Dr.criptiori(NAD27 only) t:' Legal Description(NAD27 only) 1 Starting Coordinates: Legal Description — - — X: 1468280.87 Township: 1012 lil Range: 007 E . Y: 15997428.17 Meridian ItT-7.71 Section:112 _ IFNL •114296.4263 'FEL 1 4186.3129 Transform € Quit Help — — — f Moraine #1 wp02 TD CPA?Coordinate Converter ! = 1 l='' 1 •s From: _ To: Datum: NAD27 .] Region: alaska Datum: NAD27 .1 Region: alaska r- Latitude/Longitude !Degrees Minutes Seconds r Latitude/Longitude !Decimal Degrees ...d. i UTM Zone:1 _.. South C UTM Zone:i4 f South r: State Plane Zone:i' . Units: us-it C- State Plane Zone. 1 4_-- , Units: ut-ft C Legal Description RIAD '. r: Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 468280.87 Township: I012 N Range: 1007 E '1: 5997428.17 Section:1 Meridian )��� 12 0NL . 14296.4263 1-E-7:1 14186.3129 Transform j Quit i Help i f ORIGINAL • Appen for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 Attachment 2— Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8"Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval Well collision Low Utilize MWD surveys and travelling cylinder plots Gas Hydrates Low Monitor well at base of permafrost,increase mud weight,decrease mud viscosity,increase circulating times,control drilling rates and low mud temperatures Abnormal pressure in Low Increase mud weight surface formations>= 2000' TVD Lost circulation Low Reduce pump rates,thin mud rheology,pump LCM pills and use low density cement slurries 8-1/2" Hole / Coring Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills.Mud weight above 9.6 ppg.Flow Surface Formations checks during connections. Mud weight increase if >2000'TVD needed. Lost circulation Low Reduced pump rates and trip speeds.Real time equivalent circulating density(ECD)monitoring. Engineered mud rheology.Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties and increased mud weight for trips.Ensure proper hole fill.Pump out of hole if needed.Monitor real time equivalent circulating density(ECD).Use of weighted sweeps. Abnormal Reservoir Low Well control drills.Increase mud weight.No over Pressure pressured zones predicted. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,and standard well control practices.Employ mud scavengers. Gas cut mud Low Mud weight,flow checks,be prepared to weight up mud system accordingly. Stuck Pipe Medium Use of clean out runs,T&D monitoring,proper mud maintenance,proper drilling&tripping practices. Core Jamming Medium Proper coring techniques. Contingency for additional coring runs. Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the attachments. Moraine#1 wp02 passes major risk analysis with offset wells. Surface Hole Interval Moraine#1 APD AORIGIN Printed. 1-Dec-14 • App on for Permit to Drill, Mra Saved:Well o 1-Dec-14ine#11 The greatest risk in the surface hole interval is predicted to be tight hole& surface casing running. The near 3S/Palm pad has experienced tight hole&surface casing running difficulty in the past. This will be mitigated with good drilling practices, proper mud maintenance, & hole cleaning practices. Always watch for & address running sands while drilling & tripping through the permafrost interval. To avoid the surface hole degrading with time,drill&trip efficiently reducing exposure time between penetrating&casing the interval. Production/Coring Hole Interval The greatest geological risk with the production/coring hole section is hole stability as the hole will be open for an extended period of time due to coring,E-Line,&clean out runs. Mitigating this risk begins during the planning phase of the well, when the well path is optimized to reduce unnecessary steering and dog legs. To gauge the effectiveness of the drilling program, the rig crews are to monitor and record drilling parameters such as torque and drag, ECD, drilling losses, returns at the shaker, etc. If necessary, adjustments to the drilling strategy will be discussed with the drilling engineer / drilling superintendent and implemented as needed. The rig crew must have heightened awareness when penetrating the Moraine zone and be prepared for lost circulation mitigation measures. Reservoir Summary The Moraine #1 wellbore is expected to have virgin reservoir pressure as no injection has been undertaken and target location is far away from the only existing producer 3S-19. 3S-19 was shut in November 2014. Gas cut mud has been encountered at the 3S/Palm pad area; the rig will have enough weighting material onsite if gas cut mud is encountered. Formation SS TVD Predicted Predicted Comments (ft) Fracture Pore Gradient Pressure (EMW-ppg) (EMW- ppg) West Sak 1970 16 8.6 Normally pressured C-40 4040 14 8.6 / Normally pressured Moraine 5150 13.0 8.7 Normally pressured All formations will be drilled overbalanced to mitigate well control risks. Moraine#1 APD QRIGINALPage11of16 Printed: 1-Dec-14 • Ap. on for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 Attachment 3—Well Schematic Moraine #1 wpO2 Abandonment ConocoPhillips V 16"Conductor, RKB 28 ft N9E E-Jr s:r':1s 12.".e 16"62.6#H-40 114'MD a Cement Laid on Top of Bridge Plug w?11 ppg ALC to Surface Bridge Plug Set it-500' Build to 15.97' 29.22'drop ba•:k C'by surface casing point .,; 1\ e' Cement Laid on Top of Retainer wt 15.8 Class G f,2,400'to 2,350' Surface Casing: ---_ -- Cement Retainer Seta-2.400• 9-5;8"40#L-80 BTCM 2 T46 MD/2,500'TVD 0,0' 4 Squeezed P&A Plug wf 15.8 Class G f 2800'to 2,400' af` C-40 Top 4138'MD 4095'TVD P&A Plug#3 w!15.8 Class G f 4,496'to 3,698' C-40 Hydrocarbon : • Possible . P&A Plug#2*115 8 Class G fi 5,098'to 4.498' Moraine Top 5248'MD 5205'TVD P&A Plug#1 wt 15.8 Class G f1TD 1%5.698'to 5,098' • Moraine Predictedl' :: i' Pore Pressure:8.7 ppg :. Moraine Bottom 5387'MD 5345'TVD Total Depth 5,698'MD 5.655'TVD 0' 8-W Open Hole Moraine#1 APD o R G i A Printed:L Dec-14 • • Moraine #1 wp02 Abandonment ConocoPhillips Kiln Tarn(Zen V Brunswick 12/1/14 16"Conductor: RKB 28 ft N9ES 16"62.6#H-40 114' MD , , Cement Laid on Top of Bridge Plug w/11 ppg ALC to Surface Bridge Plug Set @-500' Build to 15.97°@ 29.22°drop back em° to 0°by surface casing point Sete°` g6pp Cement Laid on Top of Retainer w/15.8 Class G f/2,400'to 2,350' Surface Casing: — — Cement Retainer Set @-2,400' 9-5/8"40#L-80 BTCM 2,548' MD/2,500'TVD @ 0° . , Squeezed P&A Plug w/15.8 Class G f/2,600'to 2,400' a° e Q4M° 55'° 9 Q C-40 Top 4138'MD 4095'TVD P&A Plug#3 wf 15.8 Class G f/4,498'to 3,898' C-40 Hydrocarbon Possible P&A Plug#2 w/15.8 Class G f/5,098'to 4,498' Moraine Top 5248'MD 5205'TVD P&A Plug#1 w/15.8 Class G f/TD @ 5,698'to 5,098' Moraine Predicted .....:.:... Pore Pressure:8.7 ppg Moraine Bottom 5387'MD 5345'TVD Total Depth 5,698' MD 5,655'TVD @ 0° 6-1/ ) 1 e f, n Lio,� ORIGINAL 410 Ap*n for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 Attachment 4-Cement Summary 9-5/8"Casing Cement Job-12-1/4"hole Size Cement from 2548' MD/TVD to 2000' MD (548' of fill) with 12 ppg LiteCRETE, and from 2000' MD to surface with ASL @ 11 ppg Arctic LiteCRETE. Assume 250% excess in permafrost and 50% excess below permafrost (1700'MD/TVD bottom permafrost). Tail: (548)x 0.3129 ft3/ft x 1.50 (50%excess) = 257 ft3 in open hole 80' x 0.4253 ft3/ft= 34 ft3 shoe track volume Total volume Tail = 257 + 34 = 291 ft3 => 179 Sx @ 1.63 ft3/sk Lead: (2000' - 1,700') x 0.3129 ft3/ft x 1.50 (50% excess) = 141 ft3 in open hole 1700' x 0.3129 ft3/ft x 3.5 (250% excess) = 1862 ft3 in open hole Total volume Lead = 141 + 1862 = 2003 ft3 => 1038 Sx @ 1.93 ft3/sk System: 179 Sx 12 ppg LiteCRETE & 1038 Sx 11 ppg Arctic LiteCRETE 8-1/2"Production/Coring Section Abandonment Plugs Cement from TD laying in 600 foot abandonment plug using 15.8 ppg Class G cement = adds. Assume 40% excess annular volume. Tail: (5,698'-5,098')x 0.3937 ft3/ft x 1.40 (40% excess) = 331 ft3 in open hole Total volume = 331 ft3 => 283 Sx @ 1.17 ft3/sk System: 283 Sx Class G @ 15.8 PPG Cement from 5,098 laying in 600 foot abandonment plug using 15.8 ppg Class G cement = adds. Assume 40% excess annular volume. Tail: (5,098'-4,498') x 0.3937 ft3/ft x 1.40 (40% excess) = 331 ft3 in open hole Total volume= 331 ft3 => 283 Sx @ 1.17 ft3/sk System: 283 Sx Class G @ 15.8 PPG Cement from 4,498 laying in 600 foot abandonment plug using 15.8 ppg Class G cement = adds. Assume 40% excess annular volume. Tail: (4,498'-3,898')x 0.3937 ft3/ft x 1.40 (40% excess) = 331 ft3 in open hole Total volume = 331 ft3 => 283 Sx @ 1.17 ft3/sk System: 283 Sx Class G @ 15.8 PPG Squeeze "'200' Cement below retainer in 7-5/8" casing from 2,400' MD to 2,600' MD with Class G + Adds @ 15.8 PPG. Assume 40% excess in the annular volume. Lay in "'50' cement on top of retainer with class G + Adds @ 15.8 PPG. Tail: (2,500'-2,400')x 0.4253 ft3/ft x 1.00 (0% excess) =43 ft3 in 7-5/8" casing (2,600' -2,500')x 0.3937 ft3/ft x 1.40 (40% excess) = 56 ft3 in open hole (2,400' -2,350')x 0.4253 ft3/ft x 1.00 (0% excess) = 22 ft3 in 7-5/8" casing Total volume =43 ft3 + 56 ft3 + 22 ft3 = 121 ft3=> 104 Sx @ 1.17 ft3/sk System: 104 Sx Class G @ 15.8 PPG Moraine IGINAL 13 of 16 AD Page #1PD Printed: 1-Dec-14 + • ApK•on for Permit to Drill,Well Moraine#1 Saved: 1-Dec-14 Cement from bridge plug @ N500'to surface using 11 ppg Arctic LiteCRETE cement Tail: (500') x 0.4253 ft3/ft x 1.00 (0% excess) = 213 ft3 in open hole Total volume= 213 ft3 => 182 Sx @ 1.93 ft3/sk System: 95 Sx Class G @ 11 PPG Arctic LiteCRETE Attachment 5— Moraine Core #1 TD Curves L.Ya 1647ec1u0ils 10.0aktiots I}gIC04014 61by. .aw.....�. ITm Be(110 X61-0YMy ... •V••��• 3gts.•.•,•••. ._•..•. 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' GINAL Appon for Permit to Drill,Well Moraine#1 4 Saved: 1-Dec-14 Attachment 6— Proposed Ice Road &Pad Route "U 51385.95E I ICE . u. . apvT+ NAC 83 NA7 63 v. i CY. lCRIMNG (65119 MORAINE #1 '7, 3 2953718 1615735 ' w ! 2 5993621 1615246 ®.I[, 9 ,� 3 6994383 1616951 i i p e i< .:t �,I..y 4 5495593 1610846 't; .7._ ID E= saF " 5 3995172 1676.131 y 0 6.' c, s1. 6 5956322 161000C :71,0 1< 7 . 593,6797 162917` 8 6996574 1608620 PROPOSED 600' x 300' I:E PAD 0 .y ,. 039 6574 1608656 AREA=8.5 ACRES 1a 5926369 1628095 C_4 5 1'. 895,6333 1677889 „'.`, 12 5417138 1608442 13 5926555 1648132 PROPOSED 35' WIDE ICE ROAD "�" 1< 8933567 1613576 LENGTH=8 800' 15 5903578 1612485 ICE RD. 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''. . , 0 0 2 2 g '2 2 2 2 2 U r; QD 0 ci •t• to 03 0 vl .1 0 0 0 ,..", "...r. +. r 0 CI C-1 c/ V 0 N tO 4 . 0 7L-Cil .-• ....a • S Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday,January 28, 2015 12:28 PM To: Loepp, Victoria T(DOA) Subject: RE: KRU Moraine(PTD 214-198) Diverter Layout Attachments: Diverter lay out Moraine#1.pdf Would this work? This is N9ES as we planned to have it situated on the ice pad,they're doing the final official as-built of the pad out there today. From: Loepp, Victoria T(DOA) [mailto:victoria.loepo@alaska.gov] Sent: Wednesday, January 28, 2015 10:59 AM To: Brunswick, Scott A Subject: [EXTERNAL]KRU Moraine(PTD 214-198) Diverter Layout Importance: High Scott, Please provide a schematic of the diverter layout. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppO.a laska.q ov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov_ 1 0 . A r w I �3 �y r* az o0 m r)TI N.... 1000' 60v' 0 o _ z I i IA (=-31 c0 01. ,to m� v l A v o (� � Q to""t.�_– r.z o 4 M — 1P411171-2 QTi m o l Q z Q ,,` a �! c.,..,..2. U7 r- art,4 -p _ \ // 3. U0 o + L--- ,` �.. J 4iv-s-----D--, --/-,.___,) i C jJ L d 1 �• O/I =� D 7 J N CI IfD S Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Friday, January 23, 2015 8:58 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]Moraine-1: Permit to Drill Application Will do. Thank you for letting me know. We will have mud loggers on locations from rig up to TD. Sent with Good (www.good.com) From: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Sent: Saturday,January 24, 2015 2:05:21 AM To: Brunswick, Scott A Subject: [EXTERNAL]Moraine-1: Permit to Drill Application Good afternoon Scott, As the Moraine-1 well will be drilled from an ice pad,the AOGCC will require a mud log from base of conductor to total depth. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907) 793- 1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, January 23, 2015 5:05 PM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: Moraine-1: Permit to Drill Application Good afternoon Scott, As the Moraine-1 well will be drilled from an ice pad,the AOGCC will require a mud log from base of conductor to total depth. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Seitz, Brian <Brian.Seitz@conocophillips.com> Sent: Tuesday,January 13, 2015 1:08 PM To: Bettis, Patricia K (DOA) Subject: RE: Moraine 1: Spacing Exception Patricia- The primary reasons behind the request to drill the Moraine 1 well within the same governmental quarter section as 3S- 620 are: • The vertical distribution of oil within the Moraine interval (Torok Oil Pool) is not well understood by ConocoPhillips. A key objective of the Moraine 1 well is to delineate the oil pool by acquiring core, logs, and fluid samples. Positioning the well in close proximity to 3S-620 provides a basis to confidently compare between dynamic flow data from 3S-620 and the saturation profile obtained from the Moraine 1 data. • The Moraine 1 well location and proximity to 3S-620 improves the understanding of the Moraine pool by minimizing variables such as geology, reservoir properties and fluids that can rapidly change as the distance between wellbores increases. • Pending the success of the 3S-620 well and the delineation results from Moraine 1, a second horizontal well within the pattern area would be considered. This would provide an injector-producer pair, with the Moraine 1 delineation well situated half way between well 3S-620 and the potential second horizontal well. This positioning allows the use of core data within the pattern area to enhance the understanding of potential waterflood performance. • The Moraine 1 well is a near vertical well to be drilled from an ice pad. It will be P&A'd immediately upon completion of the data gathering objectives. There will be no production competition between the Moraine 1 well and 3S-620. ConocoPhillips believes the proposed location of the well provides a good opportunity to delineate the Torok pool in a location that eliminates uncertainly associated with the dynamic flow data obtained from well 3S-620 when compared with the geologic, petrophysical, and reservoir engineering data obtained from Moraine 1. In addition, Moraine 1 will not be produced, resulting in only one active Moraine formation well within a governmental quarter section. Please let me know if you have any additional questions. Regards, Brian 265-6961 (wk) 632-4367 (cell) From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, January 12, 2015 11:07 AM To: Seitz, Brian Subject: [EXTERNAL]Moraine 1: Spacing Exception Good morning Brian, Please submit a brief explanation for why ConocoPhillips has chosen to drill the Moraine 1 well at the specified location that does not conform to the statewide well spacing provisions of 20 AAC 25.055(a)(3). 1 • S Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 r S Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday,January 12, 2015 11:07 AM To: Seitz, Brian (Brian.Seitz@conocophillips.com) Subject: Moraine 1: Spacing Exception Good morning Brian, Please submit a brief explanation for why ConocoPhillips has chosen to drill the Moraine 1 well at the specified location that does not conform to the statewide well spacing provisions of 20 AAC 25.055(a)(3). Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • S P.0.Box 100360 ConocoPhillips PAnchorage,: 7-2 -696199510-0360 Phone: 907-265-6961 January 7, 2015 Commissioner Cathy Foerster, Chair RECEIVED Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100 JAN 0 7 2015 Anchorage, Alaska 99501 p� {; Re: Request for Permit to Drill Exploratory Well Moraine 1 AOGC"" Dear Commissioner: ConocoPhillips Alaska, Inc. (CPAI) is responding to the Alaska Oil and Gas Conservation Commission's (AOGCC) emails dated December 2, 2014 and December 29, 2014 in which the AOGCC respectively requested "justification to why the Moraine 1 well is classified as an exploratory when the bottom-hole location of the well is less than 1,000 feet from the well 3S-620 to be drilled to the same undefined Torok oil pool" and stated that the"KRU 3S- 19 began regular production from the undefined Torok Oil Pool (Moraine sandstone) in February 2013. That production establishes the Torok as a known productive pool. Any well drilled to a known productive pool is a development well per 20 AAC 25.990(18)". CPAI applied for a Permit to Drill for an onshore exploratory well Moraine 1 on December 1, 2014. Well Moraine 1 will be an S-shaped well drilled from an ice pad location using Nabors Rig 9ES. CPAI disagrees that the Moraine 1 well should be classified as a development well and believes that it should be classified as an exploratory well. The classification of Moraine 1 as an exploratory well is consistent with the definition of "exploratory well" in 20 AAC 25.990(25) because the purpose of the well is to delineate a pool and explore for a new, shallower pool. The following information supports an exploratory well classification: 1. The primary objective of well Moraine 1 is to delineate the Moraine oil pool, and explore the potential of shallower hydrocarbon reservoirs by acquiring core (conventional full-bore and rotary sidewall), logs and fluid samples. The well will then be P&A'd. No testing will be performed and the well will not be capable of being either an oil production or injection well. 2. CPAI has identified and is targeting an additional exploration target above the undefined Torok oil pool in the Moraine 1 exploration well. No production has been established in this potential shallower pool. If encountered and prospective, the Moraine 1 exploration well plan includes extensive data gathering (logging suites, rotary sidewall cores and potentially formation pressures and downhole fluid sample acquisition) to guide future plans to further delineate this shallower reservoir. We would be pleased to meet with you at a confidential meeting to address the geology in more detail. 3. The data acquired from Moraine 1 will be critical in characterizing the undefined Moraine oil pool and its development potential. ConocoPhillips has very limited data to define and delineate the Moraine oil pool. Basic reservoir information such as net pay and the distribution of water within the interval are poorly understood. PVT quality oil samples have never been obtained from this oil pool. The goal of this well is to obtain key geological, petrophysical and reservoir engineering data. 4. CPAI has one producer, well 3S-19 in the undefined Moraine oil pool. It was recompleted from a Kuparuk C sand single completion well to a Kuparuk C sand and Moraine selective completion well to test the Moraine oil pool in 1Q 2013. However; the recompletion operations did not provide an opportunity to acquire 0RIG1NALgeological, petrophysical and reservoir engineering data to delineate the Moraine oil I pool. Additionally, well 3S-19 is completed in only the upper half of the formation, so no data on the performance of the lower section is available. The lower Moraine sand has not been delineated by 3S-19 and the Moraine 1 will delineate the complete interval of the Moraine pool. 5. The primary objective of the drilling grass roots rotary well 3S-620 will be to test the performance of the Moraine oil pool in a horizontal well. However; in well 3S-620, key geologic, petrophysical and reservoir engineering data will not be obtained and the horizontal lateral will be drilled within a narrow window of the stratigraphic column: hence similar to the 3S-19 well, 3S-620 will not delineate the hydrocarbon potential of the full Moraine oil pool. The geological, petrophysical and reservoir engineering data from exploratory well Moraine 1 in combination with extended flow test data to be obtained from well 3S-620 will be utilized to delineate the Moraine reservoir for future development planning evaluations. 6. CPAI has reviewed some historical drilling permit applications for exploratory wells with similar delineation objectives. The request to classify Moraine 1 as an exploratory well is consistent with other permit applications for delineation and exploration wells. In each of the following examples, CPAI applied for a permit to drill an exploratory well to delineate the pool and/or to discover a pool. The AOGCC classified the wells as exploratory wells: a. Shark Tooth 1: In 2012, CPAI applied fora permit to delineate the Kuparuk Pool from an ice pad location. b. 1H-North, 1H-South and 1R-East: In 2006, CPAI applied for and was issued permits to drill exploratory wells from a single ice pad located NE of Kuparuk's 1H pad to delineate the West Sak pool. c. 1Q-101 and 3J-101: In 2005, CPAI applied for and was issued permits to drill exploratory wells to delineate the West Sak pool from 1Q and 3J pads. d. Palm 1: In 2001, CPAI applied for and was issued a permit to drill an exploratory well to explore for Kuparuk oil sands and extend the productive limits of the Kuparuk pool. Based on the existing regulations and the AGOCC's application of the regulations to date, the Moraine 1 well should be treated as a delineation well and classified as an exploratory well. The planned spud date for Moraine 1 is January 23, 2015. There are no shallow hazards expected at Moraine 1. The nearest offset wells indicate no overpressured intervals or lost circulation zones. The prediction is based on an evaluation of the 3S pad wells. If you have any questions or require any additional information, please call me at 265-6961. Sincerely, Brian Seitz Development Supervisor CPF 1&3 Attachments: Permit to Drill (PTD) for wells Shark Tooth 1, 1 H-North, 1 H-South, 1R-East, 1Q-101, 3J-101 and Palm 1. I 110 1TZ4VIIDE [W SEAN PARNELL,GOVERNOR ALASKA.OIL AND GAS 333 W.701AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. L. Alvord Drilling Manager ConocoPhillips Alaska,Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, Shark Tooth#1 ConocoPhillips Alaska, Inc. Permit No: 211-16.5 Surface Location: 1792' FNL, 1025' FEL, SEC. 20,T1ON, R8E, UM Bottomhole Location: 1792' FNL, 1025' FEL, SEC. 20, T1ON, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Mud log required from base of conductor to total depth of the well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been.issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, / Daniel T. Seamount, Jr. Chair DATED this d day of January, 2012. cc: Department of Fish&Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) IS r ', STATE.OF ALASKA. ijE ._ au ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL .... ,... ... A1> hu DiI R,k3as eons...ommission 20 AAC 25.005 ?a'ictiorsatm la.Type of Work: 16.Proposed Well Class: Development,on ❑ Service-Win) ❑ Single Zone 0 1c.Specify if well Is proposed for: Drill Q Re-drill 0 Slrallgraphlc Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zonal] Coalbed Gas ❑ Gas Hydrates 0 Re-entry ❑ Exploratory El Service-WAG 0 Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: ❑ Blanket ❑Single Well 11.Wolf Name and Number: ConocoPhllllps Alaska,Inc. Bond No, 59-52-180 Shark Tooth#1 3.Address: 6.Proposed Depth: 12.FleidlPool(s): P.O.BoX 100360-.Anchorage,AK 99510-0360 __ MD:6686' TVD: 6686' Ku eruk_River Field ___ _ 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:1792'FNL,1025'EEL,Sec.20,T10N,R8E,UM ADL 25603 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Dale: 1792'FNL,1025'EEL,Sec.20,T10N,R8E, UM 2677 1/15/2012 Total Depth: 9.Acres In Property: 14.Distance to 1792 FNL,-1025'FEL,Soc.20,.710N,R8E,UM.- -- 2560_._. ___._-- Nearest Property__-1025 4b.Location of Well(Stale Base Plane Coordinates-MAD 27): 10.KB Elevation above MSL: 147.9 feet 15.Distance to Nearest Well Open Surface:x- 481546 . y- 5925974 Zone- 4 GL Elevation above MSL: 117,9 feet to Same Pool: 2K-19AL1 11098 ft, 16.Deviated wells: Kickofldepih: 0 ft. 17,Maximum Anticipated Pressures in prig(see 20 AAC 25.035) 280p r 5;- Maxlmum Hole Angle: 0° deg Cownhole:3500 psig Surface',..§.47.7-pgg /z,L3,q 10.Casing Program: Specifications Top - Setting Depth -Boltom Cement Quantity,c.L or sacks Hole Casing Weight Grade Coupling Length MD r TVD MD TVD (Including stage data) 24'• 16" 62.5# 1-40 Welded 80 Surf Surf 80' 80' Pre-Installed. 15.5" 10.75" 45.5# L-80 BTC 2688' Surf Surf 2688' 2688' 1030 ski keno L(eCRETE,220 sfsoeepcRErE 9.875" .7.625" 29.7# L-80 BTCM 6243 Surf Surf 6243' 6243' 480 sks Class G .7C" - _ (e24g 6.4$, ' cs . eeittow 19 PRESENT WELL CONDITION SUMMARY (To be compieled for Redrlll and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(R): Effective Depth TVD(R): Junk(measured) • Perforation Depth MD(ft): . Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ ROP Sketch ❑ Drilling Program❑✓ Time v.Depth Plot❑ Shallow Hazard Analysts I_j Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program❑ 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date; -DR. 22. I hereby certify that the foregoing Is true end correct. Contact Dave Reimer @ 263-4347 Printed Name G L Alvord - Title Drilling Manager ' Signature Xe..(1/(--- Phone:265-6120 Date (a{ ( Commission Use Only , Permit to Drill ------ 1 API Number: . Permit Appraval See cover letter- - - Number: 2-i I 1(om;C_] 50•f o3 2 L/7- �, C - Dale: { fto for other requirements Conditions of approval: If box Is checked, ell rna�be used to explore for,lest,or produce oalaed methane;gas hydrates,or gas contained In shales: av . 3 SO /D p -' for 1‘2.&71‘2.&71--S ' Samples req'd: Yes El [Mud log req'd: Yes No 0 Other: e S ny L�ry H2S measures: Yes o ❑ Directional svy req'd: Yes Er-No 0 . G J 41 ./ • ,./.' APPROVED BY THE COMMISSION DATE: Pe ✓, ! 1 ,COMMISSIONER Form//V/ vise 12009) This permit is valid fo ro 'hs o /3A O p'rove!(20 AAC 25.005(g)) Submit In Duplicate 1 • S RECENED - DEC 1 nil conocoPhillips AiNita &Gas Cons.COrA g 0 Anchorage,Alaska 99510-0360 December 15, 201.1 - Commissioner Alaska Oil and Gas Conservation Commission • 333 West 7m Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill: Shark Tooth#1 Dear Commissioners: ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore exploratory well Shark Tooth#1. This vertical delineation well will be drilled off an ice road/pad originating from 2K Pad using Doyon Rig 141. The objective of this well is to confirm the presence of the Kuparuk A sand, penetrate it,and then conduct an evaluation program. A Geopressure and Shallow Hazards analysis was undertaken in preparation for drilling this well. As indicate in the attachments,the drilling program calls for drilling 13-1/2"surface hole to approx.2688'MD/TVD, followed by an 9-7/8" intermediate hole section to approx. 6243'MD/ TVD and finally a 6-3/4"production hole section through the zone of interest, Kuparuk A-sand,to a well TD of approx 6686'MD/TVD. • The evaluation program in production hole section of Shark Tooth#1 will consist of cutting a 120' core of the Kuparuk A-sand,obtaining an RDT fluid sample,followed by a wireline logging program. The well will then be P&A'd. No testing will be performed. The planned spud date for Shark Tooth#1 Is January 15, 2012. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Dave Reimer at(907) 263-4347. Sincerely, • j/d Cot_ Chip Alvord Drilling Manager • a , • ..... 205-209 S E F h_t1 EA\ 1 /1FRANKH.MURKOWSKI,00vERNOR ALASKA OIL AND GAS 339 W.T"AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501.3539 PHONE (907)279-1433 FAX (907)276-7542 Randy Thomas GKA Drilling Team Leader Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: 1H-North- Conoco Phillips Alaska, Inc. Permit No: 205-209 Surface Location: 2276'FNL, 946'FEL, Sec. 15, T12N, R1OE Bottomhole Location: 1357'FNL, 336'FEL, Sec. 15, T12N, R1OE Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves-the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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. 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any • 205-209 • required test. Contact the Commission's petroleum field inspector at (907) 659- .. 3607 (pager). Sincer- • n K. ► orm. Cha' an DATED this'Wday of December, 2005 cc: Department of Fish & Game, Habitat-Section w/o ericl: Department of Environmental Conservation w/o encl. • • hilhips ' aska... Post Office Box 100360 Anchorage,Alaska 99510-0360 • Randy Thomas Phone(907)265-6830 Email: Randy.l_.Thomas@conocophillips.com December 22,2005 Alaska Oil and Gas Conservation Commission 2 Q f15 333 West 7th Avenue Suite 100 f•4l�ak�Oil�S Goalaatia,Cymmi�ai0n 04 Anchorage,Alaska 99501 Ana hrli Re: Applications for Permit to Drill, West Sak Exploration Well 11-1-North Dear Commissioners: ConocoPhillips Alaska,Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands.This well will be designated 1H-North.As shown in the attached documents,three West Sak wells will be drilled from the same ice pad located NE of Kuparuk's 1H Pad.The three wells will be P&A'd after drilling and logging. Please find attached for the review of the Commission forms 10-401,and the information required by 20 ACC 25.005 for this well. The expected spud date of 1H-North is February 1,2006. If you have any questions or require any further information, please contact me at 265-6377 or Randy Thomas at 265-6830. Sincerely, Tom Brassfield Senior Drilling Engineer ORGftML • • _ . STATE OF ALASKA RECEIVED ALAI OIL AND GAS CONSERVATION GOMIS! ^I- • '13/ DEC 2 2 2005 PERMIT TO DRILL f" 20 AAC 25.005 Alaska Oil&Gas Cons.Commission " 18:Type-of Work: ' ' "- '" Drill 0 Real! n- -- lb,-C(ikrelit Well-Class:-Expldratory I] - Development Oil Anoiple Zone- . Re-entry El Stratigraphic Test D Service D Development Gas 0 Single Zone 111 2.Operator Name: 5. Bond: Blanket E Single Well 0 11.Well Name and Number: Conoco Phillips Alaska,Inc. Bond No. 59-52-180 ' 1H-North 3.Address: 6.Proposed Depth: 12.Field/Pool(s): PO Box 100360,Anchorage,AK,99510-0360 MD: 4,645' • TVD: 4,463' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation: West Sak Oil Pool-Exploration Surface: 2276FNL,946'FEL,Sec 15,T12N,R1OE 1 ADL 025636• . Top of Productive Horizon: -- -- --- - 8.Land Use Permit: ...-= 13.Approximate Spud Date: 1385'FNL,355'FEL,Sec 15,T12N,R1OE LE 931811 . 1-Feb-06 Total Depth: 9.Acres in Property: 14.Distance to Nearest 1357'FNL,336'FEL,Sec 15,T12N,R1OE -- 2560 Property: 336' 4b.Location of Well(State Base Plane Coordinates): 10.KB Elevation • 15.Distance to Nearest Well Surface:x- 554555 '' y- 5,994,301 ' Zone- 4 (Height above GL): 30 feet Within Pool:None 16.Deviated wells: -Kickoff depth: 1000 feet• - 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 19.5 degrees Downhole: 1965 Surface: 1485 - 18.Casing Program: Setting Depth Quantity of Cement • Specifications Size Top Bottom c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD _ (including stage data) 24" 16" 63 B Welded 80' 30' -30' 110' , 110' . 200 sx AS1 12-1/4" 9-5/8" 40 L-80 BIC 2715' 30' 30' 2745 • 2672' - 460 sx ASLite+ • 160 sx DeepCRETE ... , . ' ' . , •• ' "' . ' • • 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 TVD(ft): Junk(measured): .. Casing Length Size Cement Volume MD TVD Structural Conductor . Surface Intermediate • Production Liner Perforation Depth MD(ft): Perforation Depth IVO(ft): 20.Attachments: Filing Fee kJ BOP Sketch 1_1 Drilling Program 1.2._/1 The v.Depth Plot 11 Shallow Hazard Analysis IA Property Plat El Diverter Sketch 0 Seabed Report f=1 Drilling Fluid Program D 20 MC 25.050 requirements Li 21.Verbal Approval: Commission Representative: Date • 12/22/2005 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. . Contact Tom Brassfield@265-6377 Printed Name Randy Thomas Title GKA Drilling Team Leader SignaturejAjaaAL,„ ...61.17F• 4. 13o_.7 ILL,Lar Phone 265-6830 Date 12/22/2005 Commission Use Only Permit to Drill API Number: 'Permit Apr .., ( 5. See cover letter for other Number: 7-05"-2 ER 50- 6 29-2-3 2_9 47/- Date: e-2)N,i- t..., , )1 requirements. Conditions of approval: Sam'es requ'ed Yes Xr No D Mud log required Yes Yr No 0 Hy,ro.r--s ide measur Yes 0 No g Directional survey required Yes V No 0 Other: 443 ‘,1 , \ cat, y Cos- . . APPROVED BY Approv.7 I b : oft THE COMMISSION Date: ieppl•-A r 'In"- • . • Form 10-401 a-.vis z. 06/2004r n rt. ' Submit inDuplicate rsImi A I . 'V. '-A • 0 ... - • 0 . rfkiL- L \ !J -k\L; \1 .... .. FRANK H.MURKOWSKJ, GOVERNOR- . ALAsra OIL AND GAS 333 W.TTM AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Randy Thomas FAX (907)276-7542 GKA Drilling Team Leader Conoco-Phillips Alaska, Inc. — P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River, 1H-South. . Conoco Phillips Alaska, Inc. Permit No: 205-212 Surface Location: 2269'FNL, 927'FEL, Sec. 15, T12N, R1OE Bottomhole Location: 918' FNL, 1905' FEL, Sec. 23, T12N, R1OE Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). 0 er ifig01/11, " nK. ► •r ‘. . f .' an DATED this�7day of January, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end. • - •-. I ConocoPhillips Alaska Post Office Box 100360 Anchorage,Alaska 99510-0360 Randy Thomas Phone(907)265-6830 Email: Randy.L.Thomas©conocophiliips.com December 28,2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Re: Applications for Permit to Drill,West Sak Exploration Well 1H-South Dear Commissioners: ConocoPhillips Alaska,Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands.This well will be designated 1H-South.As shown in the attached documents,three West Sak wells will be drilled from the same ice pad located NE of Kuparuk's 1H Pad.The three wells will be P&A'd after drilling and logging. Please find attached for the review of the Commission forms 10-401, and the information required by 20 ACC 25.005 for this well. The expected spud date of 1H-South is March 1,2006. If you have any questions or require any further information, please contact me at 265-6377 or Randy Thomas at 265-6830. Sincerely, ItC& �• D Tom Brassuield A's'skFC2 � Senior Drilling E gineer a�!�&Gas '26105 Qficho a"t/s. E °misg;Qn 0 11111_STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISSION A PERMIT TO DRILL )--ck 20 MC 25.005 -- - 1a.Type of Work: Drill-0'Redrill Q-- '- 1b.-Current Well Class:- Exploratory 1 ..Development'Oil --.0 'Multiple Zone-Ill''- -' Re-entry 0 Stratigraphlc Test D Service f J Development Gas 0 Single Zone 0 2.Operator Name: 5- Bond: Blanket Q Single Well Q 11.Well Name and Number: Conoco Phillips Alaska,Inc. Bond No. .59-52-180 11-1-South 3.Address: 6.Proposed Depth: 12.Field/Pool(s): PO Box 100360,Anchorage,AK,99510-0360 MD: 7,751',' TVD: 4,455' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Properly Designation: West Sak Oil Pool-Exploration ' Surface: 2269'FNL,927'FEL,Sec 15,T12N,R1OE ' ADL 02563d&025637 Top of Productive Horizon:-- - ._ .._ 8.Land Use Permit: --- ---- - 13.Approximate Spud Date: 486'FNL,2377'FEL,Sec 23,T12N,R1OE ' LE 931811&931812 1-Mar-OS Total Depth: 9.Acres in Property: 14.Distance to Nearest 918'FNL,1905'FEL,Sec 23,T12N,R1OE- 2560 Property: 3375' 4b.Location of Well(State Base Plane Coordinates): 10.KB Elevation15.Distance to Nearest Well Surface:x- 554574 ' y- 5,994,308 Zone- 4 (Height above GL): 30 feet Within Pool:None 16.-Deviated wells: --- Kickoff depth:----- 300 feet ' 17:Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 64 degrees ' Downhole: 1861 Surface: 1406 ' 18.Casing Program: Setting Depth Quantity of Cement Size Specifications Top . Bottom c.f.or sacks Hole - Casing Weight Grade Coupling ' Length MD TVD MD TVD (including stage data) 24" 16" 63 B Welded 80' 30' 30' 110' • 110' .• 200 exAS1 12-1/4" 9-5/8" 40 L-80 BTC 4180' 30' 30' 4210' ` 2698' ' 640 sx ASLIte+ . 160 sx DeepCRETE • 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 TVD(ft): Junk(measured): ii) Casing Length Size Cement Volume - C11/ TVD D Structural Ec it Conductor ��a _ Surface $q p- Q Intermediate _ - A ''46'Co • Production give rn Sign Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Filing Fee [J BOP Sketch U Drilling Program U Time v.Depth Plot U Shallow Hazard Analysis U Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: . Date 12/22/2005 22. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact Tom Brassfield@265-6377 Printed Namdill.4 Randy Thomas /� - Title GKA Drilling Team Leader Signature w; �lC� c r t i. . Phone 265-6830 Date 12/28/2005 ' Commission Use Only • Permit to Drill API Number: Permit Approval See cover letter far other Number: p'1OS' a t - 50- O - n*00-cR Date: 1 )7-nto requirements. Conditions of approval: . Se pies ref wired Yes ❑ No Er Mud log required Yes [l No Er dro.- .ulfide measures Yes 0 No ' Directional survey required Yes El. No LI Other: plit ad ►7;G . c),-11--c,.5.7 P`Ghc APPROVED BY Approved.'WV THE COMMISSION Date: / /_/ a�r� Form 10-401 Revised 0612004 ' ORIGINAL Submit inDuplicate 4 311 rj frig Al\ sELA • �I L [F3 .. (RANK P1. MURKOWSKI, GOVERNOR � 7 ALASKA.OIL AND GAS 333 W.7' AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Randy Thomas FAx (907)276-7542 GKA Drilling Team Leader Conoco_Phillips Alaska,Inc.- - - --- P.O. Box 100360 Anchorage, AK 99510-0360 Re: West Sak Exploration 1R-East Conoco Phillips Alaska, Inc. Permit No: 205-211 Surface Location: 2283'FNL, 964'FEL, Sec. 15, T12N, R1OE Bottomhole Location: 1241'FNL, 1979'FEL, Sec. 16, T12N, R1OE, Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. -.. . . 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petrole - field inspector at (907) 659- 3607 (pager). .11 - Jo . Norma Chairman DATED this day of January, 2006 cc: Department of Fish&Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • _111_._. ._. ConocIhillips Alaska Post Office Box 100360 Anchorage,Alaska 99510-0360 Randy Thomas Phone(907)265-6830 1 Email: Randy.L.Thomas@conocophillips.com December 28,2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Re: Applications for Permit to Drill, West Sak Exploration Well 1R-East Dear Commissioners: ConocoPhillips Alaska,Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands.This well will be designated 1R-East.As shown in the attached documents,three West Sak wells will be drilled from the same ice pad located NE of Kuparuk's 1H Pad.The three wells will be P&A'd after drilling and logging. Please find attached for the review of the Commission forms 10-401,and the information required by 20 ACC 25.005 for this well. The expected spud date of 1R-East is February 15, 2006. If you have any questions or require any further information, please contact me at 265-6377 or Randy Thomas at 265-6830. Sincerely, Tom Brassfield 2005 Senior Drilling Engineer A�aakig 0,1& C Des fp s Anchprage coin Inisriorl • . STATE OF ALASKA ii lON AL . OIL AND GAS CONSERVATION COLS . PERMIT TO DRILL 20 AAC 25.005 1 a:Type of Work . '-. Drill ✓ Redrill .- 1b:Current Well Class:. Ex lorato .. -Develn ment Oil .. MultiOle Zone • - ❑ ❑ P rY � P ❑ P ❑ Re-entry ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Single Zone LI - 2.Operator Name: . 5. Bond: Blanket Single Well❑ 11.Well Name and Number: • Conoco Phillips Alaska,Inc. Bond No, 59-52-180' IR-East 3.Address: 6.Proposed Depth: 12.Field/Pool(s): PO Box 100360,Anchorage,AK,99510-0360 MD: 8 178' - TVD: 4,332' ./ Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation: West Sak Oil Pool.-Exploration Surface: 2283'FNL,964'FEL,Sec 15,T12N,R1 OE' ADL 025636 Top of Productive Horizon: __- -8.Land Use Permit: 13.Approximate Spud Date: 1352'FNL,1307'FEL,Sec 16312N,R10E ' LE 931811 15-Feb-06 Total Depth: 9.Acres in Property: 14.Distance to Nearest 1241'FNL,1979'FEL,Sec 16,T12N,R1OE ' 2560 Property: 3301 4b.Location of Well(State Base Plane Coordinates): 10.KB Elevation 15.Distance to Nearest Well Surface:x- 554537 ' y- 5,994,294-Zone- 4 (Height above GL): 30 feet Within Pool:None 16.-Deviated wells: Kickoff depth: 250 feet - 17.Maximum Anticipated Pressures in psig(see 20 AAO 25.035) Maximum Hole Angle: 68 degrees Downhole: 1796 ' Surface: 1357 18.Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 63 B Welded 80' 30' 30' 110' - 110' -" 200 sx AS1 12-1/4" 9.518" 40 L-80 BTC 4337' 30' 30' 4367' • 2602' -- 660sxASLite+ 160 sx DeepCRETE 19. PRESENT WELL CONDITION SUMMARY(To be completed for RedrIll and Re-Entry Operations) Total Depth MD(ft): r- Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): - Effect.Depth TVD(ft): Junk(measured): - Casing Length • — Size Cement Volume MD^ ND • Structural �/�h► � v . Conductor El 2 8 2005�� Surface D . .. Intermediate Production �[ ak+ lir �i baaOgna.. Liner A ✓� C�df0 e3jQq Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: Filing Fee Ll • BOP Sketch ❑ Drilling Program IA Time v.Depth Plot U Shallow Hazard Analysis LI" Property Plat ❑ Diverter Sketch U Seabed Report [] Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date 12/22/2005 22. I hereby certify that(he foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield@265-6377 I Printed Name Randy Thomas Title GKA Drilling Team Leader • Signature 1`� „ , le.../ -g1,..1. Phone 265-6830 Date 12/28/2005 VVVVVV ) Commission Use Only Permit to Drill /// API Number: Permit Approval See cover letter for other . Number: .3C "'". -A,‘ 50-03-5 `a%a SS'o6 Date: (')i requirements. Conditions of approval: Sa' r es required Yes ❑ • No ©' Mud log required Yes U No • •gen sulfide measures Yes [] No V Directional survey required Yes [f No ❑ Other: ••4 ' -t.•• s co,0,41 // /� C APPROVED BY Approve. . �� THE COMMISSION , Date: /Y3 w Form 10-'0 '-vised 08120 - ORIGINAL RBDMS BFL JAN 0 4 -inDuplicate ,, , All) .y , • •SIfirr\iar OEF ALASIEA -- •--FRANK H.MURKOWSKI,GOVERNOR ALASKA OIL AND GAS 333 W.7"'AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1933 Randy Thomas FAx (907)276-7542 GKA Drilling Team Leader Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: KRU West Sak 1Q-101 Conoco Phillips Alaska,Inc. I Permit No: 205-156 Surface Location: 1574'FNL, 1160' FEL,Sec. 26,T12N, R9E BotttomhoIe Location: 787'FSL,489'FWL, Sec. 24, T12N, R9E Dear Mr.Thomas: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's-activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at(907)659-3607(pager). Sincerely, f/II`• e/, /, ,,rman Chairman DATED this#day of October,2005 cc: Department of Fish&Game,Habitat Section w/o end. Department of Environmental Conservation w/o encl. • -• .o-' RoEcri ConocoPhiIIiis Alaska , � � Post Office Box 100360 ����,.. Anchorage,Alaska 99510-0360 � Randy Thomas .la5ka Oil Phone(907)265-6830 �8$ 0 ;:. : .;,. .. Email: Randy.L.Thomas@conocophillips.com Aflchar3g@ " 'S101i October 18, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Re: Applications for Permit to Drill,West Sak Exploration Well 1Q-101 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands. The this well will be designated 1Q-101 ' Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. The expected spud date of 1Q-101 is November 10th, 2005. If you have any questions or require any further information, please contact Tom 8rassfield at 265-6377. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader I 0 STATE OF ALASKA RECEIVED . ASKA OIL AND GAS CONSERVATION WAMIS_SIO_ N PERMIT TO DRILL OCT 1 9 2005 20 AAC 25.005 . , - - 1a:Type of Work: - "- Drill ❑❑ Redrill lb:Current Well Class:' Exploratory" r❑ Develo.. piyas{tat611 8171a 4A�i l*PNbIr - - Re-entry ❑ Stratigraphlc Test ❑ Service ❑ Development Gas adtatageone D 2,Operator N�ame: ry/a� 5. Bond: Blanket 0 Single Well 0 11.Well Name and Number: Con9aoPhi rps Alaska,'lnc. Bond No. 59-52-180 ' 1Q-101 3.Address: 6.Proposed Depth: 12.Fieid/Pool(s): PO Box 100360,Anchorage,AK,99510-0360 MD; 4,955' ' ND: 3,675' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation: West Sak Oil Pool-Exploration Surface: 1574'FNL,1160'FEL,Sec 26,T12N,R9E / ADL 25641&25634/ Top of Productive Horizon: 8.Land Use Permit: - 13.-Approximate Spud Date: 270'FSL,129'FWL,Sec24,T12N,R9E / LE 931814&931809 10-Nov-05 Total Depth: 9.Acres in Property: 14.Distance to Nearest 787`FSL,489'FWL,Sec 24,T12N,R9E / 2560 Property: sage,- `r Z- 4., 4b.Location of Well(State Base Plane Coordinates): / 10.KB Elevation 15.Distance to Nearest Wel[/, Surface:x- 528465 "" y- 5,984,299 Zone- 4 (Height above GL): 30 feet Within Pool None """16.Deviated wells: -- -----Kickoff depth: 350 feet , 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 56 degrees Downhole: 1400 Surface: 1152 18.Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 94 K-55 Welded 80' 30' 30' 110' ' 110' s 260 cf ArctIcCRETE 13-112" 10-314" 45.5 L-B0 .1BTC 1859' 30' 30' 1889' / 1784' '' 480 sx ASLite+ 55 ax DeepCRETE 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): ' Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Structural Conductor r Surface Intermediate Production - Liner • Perforation Depth MD(ft): Perforation Depth TVD(ft): 20,Attachments: Filing Fee U BOP Sketch U Drilling Program U Time v.Depth Plot U Shallow Hazard Analysts U Property Plat [] Diverter Sketch Q Seabed Report l Drilling Fluid Program 0 20 AAC 25.050 requirements 111 21.Verbal Approval: Commission Representative: . Date 10/18/2005 22. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact Tom Brassfield@285-6377 Printed Name ��Ra�ndy Thomas Title GKA Drilling Team Leader � " Signature "----� Phone 265-6830 Date 1011812005 ( Commission Use Only Permit to Drill _ / API Number. Permit Approval See cover letter for other Number: ?��-5 45ifp 50- 02,1-Z37 Z—X Date: in •0210• n sl requirements. Conditions of approval: ii,VAR Gornc•ccpc-aAtadN t'3a30ps• -S3c,Vp Ices), 0.c._cs_Ob\e 30lin .C-3-S,035(h>(.1) Sample equired Yes [] No 0 Mud log required Yes ❑ No Er p Hyd•r- ulfide` measures Yes No 0. Directionalsurveyrequired Yes " No ❑ Other: ri CJt., .1,h. / .r E\e, ..KA . Q�r�D�e_v1�s Cr4C G.J-t�r-i ZC�h` ��� APPROVED BY Approved by.� THE COMMISSION Date: /Sri) 111, Form 8-401 Re' -•06/2004 ORIGINAL Submit in Duplicate 1111 g\ -- siairiE 0 .- FRANK H.MURKOWSKI, GOVERNOR . • ALASKA OIL AND GAS 333 W.71"AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501.3539 PHONE (907)279-1433 Randy Thomas Fax (907)276-7542 GKA Drilling Team Leader Conoco Phillips Alaska,Inc. - P.O.Box 100360 Anchorage,AK 99510-0360 Re: KRU West Sak 3J-101 Conoco Phillips Alaska,Inc: Permit No: 205-157 Surface Location: 1205'FSL, 565' FWL, Sec.3,T12N,R9E Bottomhole Location: 890' FSL,565'FEL, Sec. 3,T12N,R9E Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31M5 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, Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at(907)659-3607(pager). Si• - -1y, ; . Orman hai DATED this day of October,2005 cc: Department of Fish&Game,Habitat Section w/o encl. Department of Environmental Conservation w/o end. Conoco/ hillips Alaska Post Office Box 100360 Anchorage,Alaska 99510-0360 Randy Thomas RECEIVED Phone(907)265-6830 Email: Randy.L.Thomas@conocophillips.com OCT 2 o 2005 Alaska Oil&Gas Com Commission October-19, 2005 Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Re: Applications for Permit to Drill, West Sak Exploration Weil 33-101 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill an onshore exploration well thru the West Sak sands. This well will be designated 33-101. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. The expected spud date of 33-101 is November 25th, 2005. If you have any questions or require any further information, please contact Tom Brassfield at 265-6377. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader • STATE OF ALASKA ALAWOIL AND GAS CONSERVATION fVI COMION RECEI " • PERMIT TO DRILL OCT.2 0 2005 '0I � 20 AAC 25.005 r�,�, la:Type of Work: Drill Q Redrill [� - 1b.Current Well Class: •Exploratory [J]• Deveid�il� lb Zt�ta'iftiget0S - Re-entry 2 Stratigraphic Test 0 Service D Development Gas [, 1lone 2 2.Oprator Name:!U• 5. Bond: Blanket 9 Single Well 9 11.Well Name and Number: Sys :-�(•u� Congo Phil>ps Alaska,Inc. Bond No. M-52-180/ 3J-101 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): , PO Box 100360,Anchorage,AK,99510-0360 MD: 6,209' '' TVD: 3,787' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation: West Sak Oil Pool-Exploration Surface: 1205'FSL,565'FWL,Sec 3,T12N,R9E ' ADL 25630' - Top of Productive Horizon: --_= 8.-Land Use Permit: - - 13.Approximate Spud Date:-- - - 989'FSL,3079'FWL,Sec 3,712N,R9E LE 931805 25-Nov-05 Total Depth: 9.Acres In Property: 14.Distance to Nearest 890'FSL,565'FEL,Sec 3,T12N,R9E' 2560 Property: r„ge5' 3 4b.Location of Well(State Base Plane Coordinates): 10.KB Elevation 15.Distance to Nearest Wellp• 6 Surface:x- 519544 ' y- 6,002,888 /Zone- 4 (Height above GL): 30 feet Within Pool:None 16.Deviated wells:—--- Kickoff depth:- --- 500 feet I. 17 Maximum Anticipated Pressures in psig(see 20 AAG 25.035) Maximum Hole Angie: 86 degrees Downhole: 1570 Surface: 1186 r 18.Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f.or sacks Hole Casing Weight — Grade Coupling Length ' MD ' TVD MD ND (including stage data) 40" 20" 94 K-55 Welded 80' 30' 30' 110' ' 110' • 260 cf ArcticCRETE - - 13-1/2" 10-3/4" 45.5 L-80 BTC 2259' 30' 30' 2289' ' 2058' ' 520 sx ASLite+ 110 sx DeepCRETE 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrlll 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 TVA Structural Conductor .Surface _ Intermediate Production - - - J Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Filing Fee LI BOP Sketch L Drilling Program U Time v.Depth Plot Lf Shallow Hazard Analysis U Property Plat 9 Diverter Sketch 9 Seabed Report ❑ Drilling Fluid Program 9 20 AAC 25.050 requirements 2 21.Verbal Approval: Commission Representative: Date 10/19/2005 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfiefd@265-6377 • Printed Name Randy Thomas Title GKA Drilling Team Leader Signature l _ Phone 265-6830 Date 10/19/2005 Commission Use Only ' Permit to Drill API Number. Permit Approval ___,, See cover letter for other Number: L()S/S-7 50- OZ—/— Zi�s 3 2Date:1D•p' requirements. Conditions of approval: "W,...3opc�l� tSi9 m Ntt[x„•� . 0040$g, C#61? s'r eICC kt}t9\re_.-..f3-0 kit Si3 Sc/I `../ Sample equired Yes 9 No Mud log required - Yes 9 No Hyd•.- sulfide measures Yes 9 No E Directional survey require Yes ' No E Other: l . :4ip 1,. r`'^ ( .`, 0 I r- c t V SSAc—C Civ � - 1"���. Approved b . � • THE COMMISSION Date: `�f Form 10-401 Revised 06/2004ORIGINAL Submit InDuplicate I _ 411 � a ELL TONY KNOWLES,GOVERNOR ALASKA OIL AND GAS 333 W.7"AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279.1433 Paul Mazzolini, FAX (907)278-7542 Exploration/Cook Inlet Team Leader Phillips Alaska,Inc. P O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Unit Palm#1 Exploratory Phillips Alaska,Inc. Permit No: 201-005 Sur.Loc. 2573'FNL,1297'FEL,Sec. 18,T12N,R8E,UM Btmhole Loc, 2420'FNL, 1064'FWL,Sec. 18,T12N,R8E,UM Dear Mr.Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies,and does not authorize conducting drilling operations until all other required permitting determinations are made. 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. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records,FIT data,subsequent LOT data following setting production casing,and any CQLs must be submitted to the Commission on form 10-403 prior to the approval of disposal operations. All dry ditchsample 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. Blowout prevention equipment(BOPE)must be tested in accordance with 20 AAC 25.035. Sufficient notice(approximately 24 hours)of the HOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, • Atha, A4. Wt cv ►' Julie M.Heusser Commissioner BY ORDER OF T COMMISSION DATED this 2-014-1- day of January,2001 dlf/Enclosures (2 ) cc: Department.of Fish&Game,Habitat Section w/o encl. Department of Environrnental Conservation w/o end. • i PHILLIPS PHILLIPS Alaska, Inc. ssA Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,Alaska 99510-0360 Tom Brassfield Phone(907)265-6377 Fax: (907) 265-6229 Email: tbrass@ppco.com January 5,2001 Daniel T.Seamount,Jr.,Chairman Alaska Oil and Gas Conservation Commission 333 West 711]Avenue Suite 100 Anchorage,Alaska 99501 (907)279-1433 Re: Application for Permit to Drill Phillips Palm#1 Surface Location: 2573'FNL,1297'FEL,Sec.18,T12N,R8E,UM or ASP4,NAD 27 coordinates of X=475954&V=5993843 Target:2459'FNL, 1697'FWL,Sec.18,T12N, R8E,UM BHL:2420`FNL,1064`FWL,Sec.18,T12N,R8E, UM CONFIDENTIAL Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well,the Palm#1,located approximately 4 miles west of the Kuparuk River Units 3G Pad. This well will be accessed via ice road originating near 3G Pad,drilled using Nabors 19E,possibly sidetracked on a success case,tested and permanently abandoned prior to spring breakup. If this well is deemed to be commercial,a request could be made to the AOGCC to designate as a"keeper"well.A Sundry would be filed to suspend the wellbore until development plans are in place or a decision is made to P&A. Attached is the information required by 20 ACC 25.005(c)for your review.There are no shallow hazards expected at Palm#1 (see attached graphs). The nearest offset wells indicate no overpressured intervals or lost circulation zones. There will be no reserve pit for this well.Waste drilling mud will be hauled to a KRU Class II disposal well. If a production casing string is set in this well Phillips requests that Palm#1 be permitted for annular disposal of fluids occurring as a result of drilling operations,per regulation 20 AAC 25.080.As in the past Phillips would submit a 10-403 Form to the Commission with the appropriate technical information.All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. If this well is tested,the produced fluids will either be hauled to Kuparuk for recycling or injection into an appropriate disposal well or the produced fluids will be reinjected into the Palm#1 wellbore. Please note that Phillips does not anticipate the presence of H2S in the formations to be encountered in this well. However,there will be H2S monitoring equipment operating,as is the usual case while drilling wells-in-and near-the Kuparuk River-Field. —If you have any questions or require any further information,please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely RECEIVED Paul Mazzolini JAN 0 5 ZOD1 Exploration/Cook inlet Team Leader Alaska Oil&Gas Cons.Commission Anchorage ! S STATE OF ALASKA I A it ei ALASKA OIL AND GAS CONSERVATION COMMISSION _.. PERMIT TO DRILL 20 MC 25.005 1a.Type of work NU U Reddll ❑ lb.Type of well. Exploratory ISI StratigraphicTest Li Development Oil U Re-entry ❑Deepen ❑ Service D Development Gas ❑ Single Zone 0 Multiple Zone❑J, 2.Name of Operator 5.Datum elevation(OF or KB) 10.Field and Pool - Phillips Alaska,Inc. CONFIDENTIAL RKB 28 feet Kuparuk River Feld/Pool 3.Address 6.Property Designation Exploration P.O.Box 100360 Anchorage,AK 99510-0360 ADL 380107 ALK 4624 Moralne/Kuparuk/J-4 4.Location of well al surface 7.Unit or property Name 11.Type Bond(see 20 AAC 25.02511 2573'FNL,1297'FEL,Seo.18,T12N,RBE,UM Kuparuk River Unit Statewide Al top of productive interval 8.Well number Number 2459'FNL,1697'FWL,Sec.18,T12N,RBE,UM Palm#1 #59.52-160 At total depth 9.Approximate spud date Amount 2420'FNL,1064'FWL,Sec.18,T12N,RBE,UM January 20,2001 $200,000 12.Distance to nearest property line 13.Distance to nearest well 14.Number of acres In property 15.Proposed depth(MD and Dio) 1064 @ TD feet Colville#12.7 ml 43 surface feet 2448 7440'MD/6670'TVD 16,To be completed for deviated wells 17.Anticipated pressure(see 20 AAC 26.035(0)1211 Kickoff depth: 2780 MD Maximum hole angle 36.9 Maximum surface)24'�pslg At total depth(TVD)3399 psig " 18.Casing program Setting Depth arota5 ihriiely size Specicattons Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling_ Length MD TVD MD TVD (include stage data) 24' 16' 62.5# H-40 Weld 80 28 28 108' 108' 9 oy High Early 1225 9,626' 36# J-55 BTC 2632 28 28 2660' 2660' 590 ex AS III L 8 350 ax Class Q 8.5' 7.0' 28# J-55 BTC Mod 7412 28 28 7440' 6670' , sx Class G L'ik c) PiSy, p A.-N *�V ovn1. 19.To be completed for Redrill,Re-entry,and Deepen Operations. 6f��t,�jl Present well condition summary Total Depth: measured feet Plugs(measured) true vertical feet ElfectNeDepth: measured feet Junk(measured) true vertical feet Casing Lenigth Size Cemented Measured depth True Vertical depth Conductor Surface r nte RECEIVED Production JAN 0 5 2001 Perforation depth: measured Alaska Oil&Gas Cons.Conirnission true vertical Anchorage 20.Attachments Filing fee 0 Property Plat 0 BOP Sketch cil Dlverter Sketch Drilling program El Drilling fluid program Q Time vs depth plot ❑Retraction analysis Q Seabed report ❑ 20 AAC 25.050 requirements Q 21.I hereby cenity that thethforegoing is true COuee and correct to the best of my knowledge Questions?CTom 13rassfield 285.837 Signed �'7i 7( TItie:ExpferatfeaCoek Inlet Teem Leader Date °I/6 4 la, Paul ufazmIW VV 1l Prepared 1w Tom Rranstlelc Commission Use Onll PI number Approval date See coverletter Permit Number lr0�� A50y�3 -26336 J-O iidS''0 J for other requirements Conditions o1 approval Samples required ® Yes ❑ No Mud idg required ® Yes ❑ No Hydrogen sulfide measures ® Yes 0 No X7I Directional survey required I 1 Yes 0 No Required working pressure for BODE ❑2M; 0 3M; yr SM; 0 iOM;❑ ❑ Other. { i,�P � � AAee �` by order of f 1 Approved by G�t.X�K� 14 '`� Commissioner the commission Date I+ /d t Form 10-401 Rev.1211185• {-\ i'i,,\a-k L 6 i ` Submit In triplicate Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, December 30, 2014 5:16 PM To: 'Seitz, Brian' Subject: RE: [EXTERNAL]Moraine#1: Permit to Drill Application Brian, Thank you. Please submit ConocoPhillips' response as a letter addressed to Commission Chair, Cathy Foerster. Patricia From: Seitz, Brian [mailto:Brian.Seitz@conocophillips.com] Sent: Tuesday, December 30, 2014 4:32 PM To: Bettis, Patricia K (DOA) Cc: Brunswick, Scott A; Ince, Don; Rodgers, James T Subject: RE: [EXTERNAL]Moraine #1: Permit to Drill Application Patricia, I was forwarded a copy of your email dated December 29, 2014 addressed to Scott Brunswick. ConocoPhillips disagrees with your decision to classify the Moraine#1 well as a development well and believe that it should be classified as an exploratory well. The Moraine #1 well has a shallow exploration target unrelated to the Torok and we are reviewing the historical permit applications and the AOGCC's classification decisions for other delineation wells. We will be discussing the Moraine#1 well classification decision internally as soon as possible. We will respond to this decision in more detail soon. Sincerely, Brian Seitz GKA CPF-1&3 DPE Supervisor 907-265-6961 From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent: Monday, December 29, 2014 7:32:58 PM To: Brunswick, Scott A Subject: [EXTERNAL]Moraine #1: Permit to Drill Application Good afternoon Scott, KRU 3S-19 began regular production from the undefined Torok Oil Pool (Moraine sandstone) in February 2013. That production establishes the Torok as a known productive pool. Any well drilled to a known productive pool is a development well per 20 AAC 25.990(18). Therefore, the proposed Moraine#1 well is considered a development well. Thank you, 1 Patricia • Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 4 • • Bettis, Patricia K (DOA) From: Seitz, Brian <Brian.Seitz@conocophillips.com> Sent: Tuesday, December 30, 2014 4:32 PM To: Bettis, Patricia K (DOA) Cc: Brunswick, Scott A;Ince, Don; Rodgers, James T Subject: RE: [EXTERNAL]Moraine #1: Permit to Drill Application Patricia, I was forwarded a copy of your email dated December 29, 2014 addressed to Scott Brunswick. ConocoPhillips disagrees with your decision to classify the Moraine #1 well as a development well and believe that it should be classified as an exploratory well. The Moraine #1 well has a shallow exploration target unrelated to the Torok and we are reviewing the historical permit applications and the AOGCC's classification decisions for other delineation wells. We will be discussing the Moraine#1 well classification decision internally as soon as possible. We will respond to this decision in more detail soon. Sincerely, Brian Seitz GKA CPF-1&3 DPE Supervisor 907-265-6961 From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent: Monday, December 29, 2014 7:32:58 PM To: Brunswick, Scott A Subject: [EXTERNAL]Moraine#1: Permit to Drill Application Good afternoon Scott, KRU 3S-19 began regular production from the undefined Torok Oil Pool (Moraine sandstone) in February 2013. That production establishes the Torok as a known productive pool. Any well drilled to a known productive pool is a development well per 20 AAC 25.990(18). Therefore, the proposed Moraine#1 well is considered a development well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 CONFIDENTIALITY NOTICE:This e-mail message, includingattachments, contains information from the Alaska Oil and Gas any 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 Patricia Bettis at(907) 793-1238 or patricia.bettis@alaska.gov. 2 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, December 29, 2014 4:33 PM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: Moraine#1: Permit to Drill Application Good afternoon Scott, KRU 3S-19 began regular production from the undefined Torok Oil Pool (Moraine sandstone) in February 2013. That production establishes the Torok as a known productive pool. Any well drilled to a known productive pool is a development well per 20 AAC 25.990(18). Therefore,the proposed Moraine#1 well is considered a development well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Friday, December 12, 2014 7:10 AM To: Bettis, Patricia K (DOA) Cc: Seitz, Brian; Mishra, Ashok K; Bearden, J Daniel;Alvord, Chip Subject: RE: Moraine #1: Permit to Drill Application Patricia, The primary objective of well Moraine 1 is to delineate the Moraine oil pool by acquiring core (conventional full-bore and potentially rotary sidewall), logs and fluid samples. Well Moraine 1 will be an S-shaped well drilled from an ice pad location and will be plugged and abandoned after completion of the delineation objectives. In response to your question regarding justification to why the Moraine 1 well is classified as exploratory when the bottom-hole location of the well is less than 1,000 feet from the well 3S-620 to be drilled to the same undefined Moraine oil pool, the reasons for this classification are as follows: 1. ConocoPhillips has very limited data to define the Moraine oil pool. Basic reservoir information such as net pay and the distribution of water within the interval are poorly understood. PVT quality oil samples have never been obtained from this oil pool. Key geological, petrophysical and reservoir engineering data is not available from any source. 2. ConocoPhillips has identified and is targeting an additional shallow exploration target in the Moraine 1 exploration well. If encountered, the Moraine 1 exploration well plan includes extensive data gathering (logging suites, rotary sidewall cores and potentially formation pressures and downhole sample acquisition). These exploration data would be used to guide future plans to further delineate these shallow reservoirs. 3. ConocoPhillips has one producer, well 3S-19, in the undefined Moraine oil pool. It was recompleted from a Kuparuk C sand single completion well to a Kuparuk C sand and Moraine selective completion well to test the Moraine oil pool in 1Q 2013. However; the recompletion operations did not provide an opportunity to acquire geological, petrophysical and reservoir engineering data to delineate the Moraine oil pool. Well 3S-19 is completed in only the upper half of the formation, so no data on the performance of the lower section is available. 4. The primary objective of the grass roots rotary well 3S-620 is to test the performance of the Moraine oil pool in a horizontal well. In well 3S-620, key geologic, petrophysical and reservoir engineering data will not be obtained. The horizontal lateral will be drilled within a narrow window of the stratigraphic column, so similar to the 3S-19 well, 3S-620 does not delineate the hydrocarbon potential of the full Moraine oil pool. 5. The geological, petrophysical and reservoir engineering data from exploratory well Moraine 1 in combination with extended flow test data from well 3S-620 will be utilized to delineate the Moraine reservoir for future development planning evaluations. The well Moraine 1 has significantly different objectives in comparison to well 3S-620. The well Moraine 1 objective is to delineate the Moraine oil pool and explore potential of shallower hydrocarbon reservoirs. The well 3S-620 objective is to test the performance of the Moraine oil pool in a horizontal well. The data acquired from Moraine 1 will be critical in characterizing the Moraine oil pool and its development potential. Please let me or Brian Seitz know if you have any additional questions. Thanks & Regards, Scott Brunswick 1 4 ► • • From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, December 02, 2014 2:36 PM To: Brunswick, Scott A Subject: [EXTERNAL]Moraine #1: Permit to Drill Application Good afternoon Scott: Please provide justification to why the AOGCC should consider the Moraine#1 an exploratory well when the bottom- hole location of the well is less than 1,000 feet from a development well to be drilled to the same undefined Torok oil pool. The reservoir objective for the proposed Moraine#1 is not located within a defined pool;therefore, 20 AAC 25.055(a)(3), Drilling Units and Well Spacing, applies. "If oil has been discovered,the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool." ConocoPhillips needs to submit a request under 20 AAC 25.055(d) for an exception to the provisions of the statewide drilling units and well spacing regulations. This process will require public notice and the opportunity for a public hearing under 20 AAC 25.540. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, December 02, 2014 2:36 PM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: Moraine #1: Permit to Drill Application Good afternoon Scott: Please provide justification to why the AOGCC should consider the Moraine#1 an exploratory well when the bottom- hole location of the well is less than 1,000 feet from a development well to be drilled to the same undefined Torok oil pool. The reservoir objective for the proposed Moraine#1 is not located within a defined pool; therefore, 20 AAC 25.055(a)(3), Drilling Units and Well Spacing, applies. "If oil has been discovered,the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool." ConocoPhillips needs to submit a request under 20 AAC 25.055(d) for an exception to the provisions of the statewide drilling units and well spacing regulations. This process will require public notice and the opportunity for a public hearing under 20 AAC 25.540. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907) 793-1238 or patricia.bettis@alaska.gov. 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: /<Iki, / moa- , - PTD: /7 — /g I VDeveiopment Service Exploratory Straiigraphic Test Non-Conventional FIELD: xpurvIL ?it/ POOL: KLyzic,A41/4K RiuE,trt a(0/4U 'OJ O/ Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER I MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 24-AAC-25.115..5,. A•. e . . _ . :: . - - is contingent"- upon Issuance of a Spacing Exception co• - - . : :i; -: , .. • _ -• -• • . • !r-ai' ,.me) Op lie . • . . • • - • - I. _ -- -• tlaa CxwISA.Ju on ©fJ 4r-!ta, 713 7isst J All dry ditch sample sets submitted to the AOGCC must be in no greate ;2L IS Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are ✓ Logging Well Lo in also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, / composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. / fYl l /c Wii( IL r . .r` 1 Cr1 0F. 4144 CJ /, P� S,5 z circ c�4-4c1 ,s ( A tJ c s a. 4,,,„ a f P . 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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 info mation. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Nabors 9ES Date: February 27, 2015 Surface Data Logging End of Well Report Moraine 1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Show Reports 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska, Inc. Rig: Nabors 9ES Well: Moraine #1 Field: Kuparuk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20699-00-00 Sperry Job Number: AK-AM-0902129759 Job Start Date: 06 February 2015 Spud Date: 07 February 2015 Total Depth: 5610’ MD, 5161’ TVD North Reference: True Declination: 18.81° Dip Angle: 80.92° Total Field Strength: 57567 nT Date Of Magnetic Data: 28 January 2015 Wellhead Coordinates N: North 70° 24’ 13.389” Wellhead Coordinates W: West 150° 15’ 40.812“ Drill Floor Elevation 42’ Ground Elevation: 14’ Permanent Datum: Mean Sea Level SDL Engineers: Hilary Garney, Jake Hansen, Travis Howe, Todd Wilson SDL Sample Catchers: Kruz Kleewein, Kyle Blazian, Brian Winn, Roy Brendible, Jacob Floyd Company Geologist: Barry Wright, Jeff MacBeth Company Representatives: Josh Riley, Randy Dolcater, Dom Mickey, John Haynes, Alan Romero SSDS Unit Number: 121 DAILY SUMMARY 02/06/2015 SDL crew arrived on location and began to rig up the unit per company man. During this time, the rig went through a pre-spud checklist then the diverter was rigged up. The pits began to take on spud mud and drill pipe along with the dumb iron bottom hole assembly to accommodate the drilling bottom hole assembly was picked up. Gas: No gas was detected. Fluids: 0 bbls gained/lost downhole. 02/07/2015 SDL unit rigged up and service began. The well spudded and began drilling to a depth of 282’ MD with a mud motor to allow for the bottom hole assembly to be put together. Gas: No gas was detected. Fluids: 0 bbls gained/lost downhole. Geology: Samples collected contained light to medium brown, black, clear, translucent to transparent, hard, coarse to very coarse grained, sub-angular to sub-rounded conglomerate with some coal and mica along with medium to dark gray-brown, soft and amorphous clay. 02/08/2015 Drilled ahead while assembling the bottom hole assembly then continued to drill ahead in the surface section. Gas: Maximum gas was 33 units at 1833’ MD and the average gas was 11 units. Fluids: 0 bbls lost downhole. Geology: Samples consisted of light to medium to dark gray, opaque, clear, translucent to transparent, black and white, hard, medium to very fine grained, sub-angular to sub-rounded sand that was moderately sorted with trace glauconite, mica and pyrite. 02/09/2015 Drilled ahead in the surface section to TD section at 2494’ MD then proceeded to circulate 2 bottoms up to clean out the hole then began to back ream out of the hole. After 10 stands came out, the hole unloaded which caused some losses over the shakers. After back reaming the rest of the way out of the hole to the heavy weight drill pipe, the well was flow checked and was static. The bottom hole assembly began to be laid down. Gas: Maximum gas was 84 units at 2392’ MD and the average gas was 15 units. Fluids: 0 bbls lost downhole. Geology: Medium to dark gray/brown, soft, amorphous, plastic texture, well compacted clay with trace galuconite that was slightly silty. 02/10/2015 Rigged up and began to run into the hole with 9-5/8” casing to 596’ MD from which the well was circulated with the cement lines. Then continued to run into the hole with casing to 2390’ MD while working through any tight spots that were encountered, mostly in areas where directional slides occurred. Gas: Maximum gas was 5 units and the average gas was 2 units. Fluids: 3 bbls lost downhole. 02/11/2015 Continued to run into the hole with 9-5/8” casing then encountered a tight spot between 2392’ MD and 2394’ MD and began to circulate to help loosen the tight spot. Laid down casing joint 62 then continued to run into the hole to 2475’ MD. Circulated and conditioned the mud and prepared for the surface cement job. Gas: Maximum gas was 19 units and the average gas was 4 units. Fluids: 0 bbls lost downhole. 02/12/2015 Performed the surface cement job then rigged down the cement unit, then began to nipple down the diverter and nipple up the well head for the intermediate and production sections. Gas: No gas was collected. Fluids: 0 bbls lost downhole. 02/13/2015 Continued to nipple up the well head then tested the blowout preventers with the witness from the Alaska Oil and Gas Conservation Commission. Gas: No gas was collected. Fluids: 0 bbls lost downhole. 02/14/2015 Finished testing the blowout preventers with the Alaska Oil and Gas Conservation Commission present then began to pick up the remaining 5’ drill pipe for the intermediate section. Ran into the hole to 2000’ MD from which they slipped and cut the drill line, than racked back the drill pipe in the derrick. From there the bottom hole assembly for the intermediate section was made up, picked up and ran into the hole. The MWD tools underwent a shallow hole test and passed so they continued to run into the hole and tagged up on the cement. Gas: No gas was collected. Fluids: 0 bbls lost downhole. 02/15/2015 Drilled out of the cement then circulated a bottoms up to clear the hole and performed a formation integrity test to 16.0 equivalent mud weight then displaced the well from spud mud to 9.4 pounds per gallon Kla-shield to drill the intermediate section than began to drill ahead in the intermediate section. Gas: Max gas was 58 units at 2763’ MD and the average gas is 8 units. Fluids: 0 bbls lost downhole. Geology: Samples have consisted of light gray to light brown, moderately soft to firm, consolidated siltstone with interbedded clay. 02/16/2015 Drilled ahead in the intermediate section, pumping high viscosity sweeps as necessary to clean up the hole. Gas: Max gas was 291 units at 4134’ MD and the average gas is 40 units. Fluids: 0 bbls lost downhole. Geology: Samples have consisted of light to medium gray to light brown, moderately soft to soft, slightly unconsolidated, blocky, amorphous siltstone with traces of clay. 02/17/2015 Continued to drill ahead to TD of 5100’ MD per Geologist to the core point from which the hole was circulated clean with 3 bottoms up then began to pull out of the hole and laid down bottom hole assembly #3. The rig floor was cleared and the weekly required Blowout preventers test was performed early so the coring operations were not affected. Gas: Max gas was 71 units at 4946’ MD and the average gas was 11 units. Fluids: 60 bbls lost downhole. Geology: Samples have consisted of light to medium gray to light brown, moderately soft to soft, slightly unconsolidated, blocky, amorphous siltstone with traces of clay. 02/18/2015 Finished testing the blowout preventers then began to pick up coring bottom hole assembly and run into the hole to 5100’ MD. The mud system was displaced from Kla-shield to low invasion coring fluid and circulated and conditioned. Afterwards, tracer fluid was added and circulated into the mud system per Baker representatives. Gas: Max gas was 72 units and the average gas was 5 units. Fluids: 0 bbls lost downhole. 02/19/2015 Finished circulating and conditioning the low invasion coring fluid with deuterium then began coring operations per Baker representatives. Gas: Max gas was 27 units at 5170’ MD and the average gas was 6 units. Fluids: 3 bbls lost downhole. Geology: Clear, translucent to transparent, light to dark grey, black sub-angular to sub- rounded, hard, well sorted, very fine to fine grained sand with clay and traces of siltstone. Oil shows have consisted of 90% bright yellow fluorescence with immediate yellow/white cut fluorescence and a light brown residual ring. 02/20/2015 Continued to core until the bit became stuck and per Baker representative the coring assembly was pulled out of the hole to lay down 74 feet of core. Gas: Max gas was 32 units at 5171’ MD and the average gas was 26 units. Fluids: 0 bbls lost downhole. Geology: light to medium gray, soft, swelled, amorphous, clay with clear, translucent to transparent, light to dark gray, black, hard very fine to fine grained, well sorted, slightly unconsolidated sub-angular to sub-rounded sand stone that had a show woth 90% light yellow fluorescence with immediate yellow/white cut fluorescence and a light brown residual ring and a strong odor. 02/21/2015 Finished laying down 74 feet of core, then began to pick up 8 core barrels and run back into the hole to 5175’ MD. The mud was circulated and conditioned with a ball dropped then coring operations continued. Gas: Max gas was 46 units at 5175’ MD and the average gas was 11 units. Fluids: 0 bbls lost downhole. Geology: Light to medium gray, soft, amorphous clay with a strong odor, 70% yellow/orange fluorescence, immediate light blue blooming cut fluorescence with a light amber residual ring. 02/22/2015 Cored ahead to 5262’ MD then began to pull out of the hole and lay down 85’ of core. Gas: Max gas was 33 units at 5240’ MD and the average gas was 12 units. Fluids: 0 bbls lost downhole. Geology: medium to dark gray, blocky, fissile, interbedded laminations of shale with sand and clay that is 20% dull orange fluorescence, strong blue/green blooming cut fluorescence and a light straw colored residual ring. 02/23/2015 Finished laying down core #2 then began to pick up coring assembly #3 and ran into the hole to 2488’ MD where the drill line was slipped and cut and a storm packer was set so that the weekly blowout preventers test could be performed. Once completed, the storm packer was taken out and running into the hole continued to 5261’ MD. Gas: Max gas was 42 units and the average gas was 2 units. Fluids: 0 bbls lost downhole. 02/24/2015 Finished running into the hole to 5261’ MD, circulated bottoms up while dropping the ball per Baker representative then began to core to 5307’ MD then began to pull out of the hole per tripping schedule. Gas: Max gas was 149 units and the average gas was 30 units. Fluids: 18 bbls lost downhole. Geology: medium to dark gray, soft, plastic amorphous clay with siltstone, shale and sandstone present. Shows consisted of 90% bright yellow/orange fluorescence and an immediate light blue cut fluorescence that left a light amber residual ring. 02/25/2015 Finished laying down the coring BHA then picked up new drilling BHA and tripped into the hole to 5080' MD. Reamed and logged to TD at 5306' MD. Begin drilling ahead to 5355' MD. Gas: Max gas was 109 units and the average gas was 76 units. Fluids: 0 bbls lost downhole. Geology: medium to dark gray, soft, plastic amorphous clay with siltstone, shale and sandstone present. 02/26/2015 Continued to drill ahead from 5355’ MD to TD of 5610’ MD where two bottoms up were circulated and then tripping out of the hole began. SDL personnel was released from location and began to rig down equipment. Gas: Max gas was 284 units and the average gas was 43 units. Fluids: 0 bbls lost downhole. Geology: medium to dark gray, soft, plastic amorphous clay with trace amounts of sandstone and siltstone present. 0 1000 2000 3000 4000 5000 6000 0 5 10 15 20 25 30 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: Moraine 1 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Nabors 9ES SPERRY JOB: AK-XX-0902129759 Days vs. Depth 06 February 2015 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 7-Feb-2015 TD: 26-Feb-2015 WELL NAME: Moraine 1 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Nabors 9ES SPERRY JOB: AK-XX-0902129759 LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 7-Feb-2015 TD: 26-Feb-2015 Commenced 12.25" Surface Hole Section On Bot: 12:5807 Feb 2015 TD Surface Hole Section 2494' MD, 2494' TVD Off Bot: 09:14 09 Feb 2015 Landed 9.625" Casing 2494' MD, 2494' TVD 11 Feb 2015 Commenced 8.5" Production Hole Section On Bot: 02:47 15 Feb 2015 TD Production Hole Section 5610' MD, 5161' TVD Off Bot: 09:43 26 Feb 2015 Reached Coring Point 5100’ MD, 4996’ TVD Off Bot: 06:31 17 Feb 2015 POOH to L/D Core #2 Off Bot: 12:20 22 Feb 2015 POOH to L/D Core #1 Off Bot: 01:32 20 Feb 2015 POOH to L/D Core #3 Off Bot: 14:55 24 Feb 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Nabors 9ES HOLE SECTION:Surface EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 AK-AM-0902129759 Alaska Moraine 1 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough Hilary Garney 14-Feb-2015 What went as, or better than, planned: Even with the issues associated with the IRIS computer and the chromatograph, everything went smoothly and when these issues did arise, the proper people were notified promptly so that a solution could be reached as soon as possible. Difficulties experienced: The IRIS computer froze up on us several times resulting in lost data. The chromatograph wasn't reading gas properly so a quick calibration during a connection had to be done which resulted in some calibration gas being left cycling through due to a leak somewhere. The ROC was called and notified of this and annotations were left on the logs explaining what happened. The gas trap got clogged up due to clay build up in the possum belly, but with some shovling and cleaning out of the possum belly by the pit watcher helped keep this issue to a minimum. Recommendations: The ROC recommends that the workstation and IRIS computer be switched since the workstation has not had any problems. We will install the CVE when the rest of the parts arrive on location. A technician will look at the THA and chromatograph to determine if replacements are needed. Innovations and/or cost savings: Installing the CVE will prevent loss of because unlike the gas trap, it is located in the flowline so will not become blocked by clay or gravel. Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Nabors 9ES HOLE SECTION: Coring Run EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Hilary Garney 19-Feb-2015 What went as, or better than, planned: This section went smoothly with the exception of difficulties outside of the SDL crew's control, with no major issues. Difficulties experienced: During drilling operations where 10ft samples were required, it was difficult to keep up with the fast drilling rates so some samples were missed and it was noted on sample manifests. Recommendations: Plan ahead with the geologist and call out for extra sample catchers when the sample program requires 10ft intervals or ask that the rig control drill so that all samples can be caught in a safe manner. Innovations and/or cost savings: N/A AK-XX-0902129759 Alaska Moraine 1 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Nabors 9ES HOLE SECTION:Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Hilary Garney 26-Feb-2015 What went as, or better than, planned: There were no issues with the gas gear, computers, data exchange, or other equipment. The section went smoothly. Difficulties experienced: There were no difficulties or major issues with equipment. Recommendations: N/A Innovations and/or cost savings: N/A AK-XX-0902129759 Alaska Moraine 1 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough Surface Data Logging After Action Review Well Name:Depth (MD)#to ft Location:(TVD)#to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons 378 124 254 1207 529 678 12 732 285 447 22 38000 11536 6000 5536 6 1807 834 973 8 4 4166 Gas Units 162 Mud Chlorides (mg/L) = 1079 285 794 22 547 64 483 2724 834 1890 8 1829 529 1300 13 4138 Gas Units 241 Mud Chlorides (mg/L) =38000 16631 6000 10631 6 628 124 504 3 Hydrocarbon Ratios 2057 529 1528 13 1219 285 934 25 18440 6000 12440 6 2990 834 2156 8 4136 Gas Units 279 Mud Chlorides (mg/L) =38000 2 667 124 543 1299 285 1014 24 3181 834 2347 8 2176 529 1647 13 19284 6000 13284 6 1 Hydrocarbon Ratios 4134 Gas Units 291 Mud Chlorides (mg/L) =38000 N/A Oil Show Rating Free Oil in Mud N/A Color blue Color Cut Color blue Intensity N/A Color light brown Intensity bright Color blue Residual Flourescence N/A Amount trace Distribution trace Intensity dull Color Stain Amount 5%Type slow Amount Cuttings Analysis: Odor moderate Fluorescence Cut Fluorescence Residual Cut Josh Riley 2/26/2015 Interpretation: Light to Medium gray to light brown, siltstone that is moderately soft to soft, slightly unconsolidated, blocky, slightly laminated with moderate amountds of clay and interbedded shale, sandstone and tuff. Show Report Report # 1 Moraine #1 4128 4166 Kuparuk 4084 4122 ConocoPhillips Alaska, Inc. Hilary Garney Coyote Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)#to ft Location:(TVD)#to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons 56 0 56 173 35 138 18 107 19 88 28 30000 2387 833 1554 8 262 65 197 11 4 5172 Gas Units 32 Mud Chlorides (mg/L) = 85 19 66 32 42 0 42 213 65 148 13 135 35 100 20 5165 Gas Units 24 Mud Chlorides (mg/L) =30000 2163 833 1330 9 31 0 31 3 Hydrocarbon Ratios 103 35 68 20 61 19 42 27 1658 833 825 8 167 65 102 12 5163 Gas Units 21 Mud Chlorides (mg/L) =30000 2 18 0 18 46 19 27 31 127 65 62 13 77 35 42 21 1391 833 558 9 1 Hydrocarbon Ratios 5161 Gas Units 16 Mud Chlorides (mg/L) =30000 N/A Oil Show Rating Free Oil in Mud N/A Color blue Color Cut Color yellow/orange Intensity light amber Color light brown Intensity bright Color blue Residual Flourescence trace Amount trace Distribution abundant Intensity dull Color Stain Amount 80 Type immediate Amount Cuttings Analysis: Odor moderate Fluorescence Cut Fluorescence Residual Cut Josh Riley 2/26/2015 Interpretation: Light to Medium gray clay that is sft, slightly swollen, amorphous and blocky with abundant sandstone and trace amounts of siltstone. Show Report Report # 2 Moraine #1 5150 5172 Kuparuk 5106 5128 ConocoPhillips Alaska, Inc. Hilary Garney Moraine Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Moraine 1 ConocoPhillips Alaska, Inc. MI Swaco Nabors 9ES AK-XX-0902129759 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 6-Feb 0 9.60 236 12 70 56/56/45 10.0 94/82/81/79/77/65 1/-2.0 1/97 -4.60 11.2 -3.60/6.50 2000 40 Rigging Up 7-Feb 282 9.60 241 13 68 59/57/55 10.0 94/81/75/66/56/53 6/-3.0 2/95 Tr 2.60 11.5 7.5 3.00/6.05 3600 40 P/U BHA 8-Feb 1635 9.70 61 12 45 52/50/50 9.8 69/57/53/47/47/46 3/-8.0 1/92 1.00 2.00 10.8 11.3 1.40/2.80 2000 40 Drilling Ahead 9-Feb 2495 9.60 -13 53 45/59/56 9.4 79/66/57/50/44/42 3/-8.0 1/92 1.00 2.05 11.0 10.0 1.45/3.65 2000 40 L/D BHA #2 10-Feb 2495 9.60 -12 51 43/54/52 9.7 75/63/55/49/42/40 3/-8.0 1/92 1.00 2.00 11.0 8.5 0.00/3.65 2500 40 RIH w/ 9-5/8" casing 11-Feb 2495 9.70 40 8 30 10/12/13 9.7 46/38/22/14/3/3 3/-8.5 1/91 1.00 0.05 8.5 10.0 0.10/1.00 2100 40 Cement surface section 12-Feb 2495 9.70 43 9 25 3/4/5 12.0 43/34/20/12/3/3 3/-8.5 1/91 1.00 0.05 8.5 10.0 0.10/1.00 2100 40 ND Diverter, NU Well head 13-Feb 2495 9.40 53 9 19 9/10/10 7.4 37/28/23/19/8/7 1/-5.5 -/95 -1.45 11.5 2.5 3.70/9.20 32000 320 Test BOP's 14-Feb 2495 9.40 53 9 19 9/10/10 7.4 37/28/23/19/8/7 1/-5.5 -/95 -1.45 11.5 2.5 3.70/9.20 32000 320 RIH w/ 5" DP and BHA #3 15-Feb 3413 9.50 53 8 30 9/10/-6.3 46/38/29/22/9/7 1/-7.0 1/93 Tr 3.80 10.0 5.0 3.40/6.60 36000 120 Drilling ahead in intermediate section 16-Feb 4692 9.70 53 14 27 10/15/17 6.3 55/41/34/27/10/8 1/-8.5 -/92 Tr 4.20 9.8 7.0 3.60/6.20 38000 120 Drilling ahead in intermediate section 17-Feb 5100 9.70 45 12 25 9/12/14 6.7 49/37/31/24/10/8 1/-8.0 /92 Tr 4.00 9.7 5.0 3.40/6.10 36000 120 BOP Test 18-Feb 5100 9.60 210 45 45 9/11/13 3.4 135/90/73/50/9/7 2/2 8.5 -/92 Tr 0.62 9.5 7.5 0.23/1.20 25000 120 Circulating Tracer Fluid 19-Feb 5158 9.60 130 41 33 10/11/14 3.3 115/74/58/37/9/7 2/-8.5 -/92 Tr 0.90 9.6 7.5 0.40/1.1 30000 60 Coring 20-Feb 5174 9.70 120 39 33 9/10/11 3.8 111/72/55/35/9/7 2/3 8.5 -/92 Tr 0.75 9.8 8.5 0.55/1.45 25500 60 L/D Core #1 21-Feb 5220 9.70 120 33 32 9/11/12 3.4 98/65/54/35/9/7 2/3 9.0 -/91 Tr 0.70 9.4 8.8 0.30/1.20 27000 60 Coring 22-Feb 5261 9.70 115 40 33 8/10/12 3.0 113/73/57/37/8/7 2/3 9.5 -/91 Tr 0.60 9.4 9.0 0.35/1.10 24000 60 L/D Core #2 23-Feb 5261 9.80 110 31 33 7/10/12 3.0 95/64/48/35/8/7 2/3 9.5 -/91 Tr 0.50 9.3 9.0 0.30/1.00 24000 60 RIH w/ Core #3 24-Feb 5306 9.80 111 33 21 7/9/12 3.2 87/54/46/27/8/6 2/3 9.5 -/91 Tr 0.90 9.7 9.0 0.50/1.30 24000 60 POOH w/ core #3 25-Feb 5306 9.70 120 32 20 7/8/10 3.4 84/52/41/25/7/6 2/3 9.0 -/91 Tr 0.40 9.4 9.0 0.30/1.10 22000 60 TD Production Section Casing Record Remarks 16" Conductor @ 114' MD, 114' TVD 9.625" Casing @ 2494' MD, 2494' TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:7-Feb-2015 SPERRY JOB:TD:26-Feb-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Comments 1 100 1 Smith XR+ Mill Tooth 12.25"114 282 168 4.00 0.994 42.0 14.5 63 240 350 To Accommodate the Drilling BHA 2 200 1RR Smith XR+ Mill Tooth 12.25"282 2494 2212 17.10 0.994 129.4 48.3 79 1430 580 TD Surface Section 3 300 2 Smith JK2201 PDC 8.5"2494 5100 2606 35.60 0.990 73.2 20.8 120 1800 590 Reached Coring Point 4 400 C1 Core 4"5100 5175 75 23.00 -3.3 107.5 87 1460 300 Core #1 5 500 C2 Core 4"5175 5263 88 23.00 -3.8 130 77 1500 300 Core #2 6 600 C3 Core 4"5263 5308 45 13.30 -3.4 23 77 1080 275 Core #3 7 700 3 Smith JK2201 PDC 8.5"5308 5610 302 12.80 0.990 23.6 13.1 90 1890 520 TD Production Alaska RIG:Nabors 9ES SPUD:7-Feb-2015 WELL NAME:Moraine 1 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-AM-0902129759 TD:26-Feb-2015 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: (max)(current) 0 0 Cly 8194 Set AtSize Grade 16" 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:T. Howe / H. Garney 1341 0 613 203 Units* Casing Summary Lithology (%) 0 MBT 1889' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5n 1033' 0.0 C-2 2815 in 0 1575'Minimum Depth Time: ahead to 1889' MD at time of report. 13 282' 1889' 1607' Max @ ft Current 7598'182.0 Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 351.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J. Riley/J. Haynes ShClyst TuffGvlCoal cP Footage 40 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Drilling Ahead PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 000 Depth in / out Mud Type Lst 60 Type Average N/A14Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 0 114' ConditionBit # 2 12.25"Mud Motor Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 9ES Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Depth 8-Feb-2015 12:00 AM Current Pump & Flow Data: 1493 Max 0 Chlorides mg/l Drilled ahead from surface to 282' MD, POOH, L/D dumb iron BHA and P/U drilling BHA. RIH and continued to drill Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade 16" 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:T. Howe / H. Garney 0 0 0 0 Units* Casing Summary Lithology (%) 0 MBT 2494' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.0- C-5n 2392' 0.0 C-2 84 in 0 1943'Minimum Depth Time: on the bottom of the hole then began to BROOH. Around 10 stands in the hole began to unload onto the shakers. Continued to 15 1889' 2494' 605' Max @ ft Current 2494'119.0 Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 173.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J. Riley/J. Haynes ShClyst TuffGvlCoal cP 13 Footage 100 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 BROOH, L/D BHA PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 11.00 000 DRILPLEX -2495'53 Depth in / out Mud Type Lst Type Average 330Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 0 BROOH to HWDP to flow check, static. Began to L/D BHA #2. 114' ConditionBit # 2 8.0 12.25" 9.70 Mud Motor 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 9ES Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Feb-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 2000.00 Continued to drill ahead from 1889' MD to TD surface section at 2494' MD. Circulated 2 bottoms up to clear cuttings Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:T. Howe / H. Garney 0 0 143 51 Units* Casing Summary Lithology (%) 0 MBT 2494' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 8.5- C-5n - 0.0 C-2 5 in 0 -Minimum Depth Time: Then continued to RIH from 596' MD to 2390' MD. Worked through any tight spots encountered, mostly in directional slide areas. 2 2494' 2494' 0' Max @ ft Current -- Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Dolcator/J. Haynes ShClyst TuffGvlCoal cP 12 282' 12.25"0.994 Footage 2212' 100 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 RIH w/ 9-5/8" Csg PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 11.00 000 Mud Motoe DRILPLEX 9.7 282' 2495'51 2494' Depth in / out Mud Type Lst Type Average N/A0Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 0 1RR 114' ConditionBit # 1 8.0 12.25" 9.70 Mud Motor 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 10-Feb-2015 12:00 AM Current Pump & Flow Data: 157 Max 0 Chlorides mg/l 2500.00 Rigged up and began to run 9-5/8" surface casing to 596' MD where the well was circulated with cement lines. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued to RIH w/ 9-5/8" casing to tight spot from 2392' MD to 2394' MD. L/D casing joint 62 and continued to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2100.00 0 11-Feb-2015 12:00 AM Current Pump & Flow Data: 0 Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 8.5 12.25" 9.70 Mud Motor 9.70 Size 1RR 2469' 114' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst Type Mud Motor DRILPLEX 9.7 282' 2495'30 2494' Depth in / out YP (lb/100ft2) 8.50 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 100 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Cement Surface Section PV 282' 12.25"0.994 Footage 2212' R. Dolcator/J. Haynes ShClyst TuffGvlCoal cP 8 Gas Summary 0 0 0 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 2494' 2494' 0' Max @ ft Current -- Date: Time: RIH to 2475' MD. Circulated and conditioned mud. RU for suface cement job. 4 in 0 -Minimum Depth C-5n - 0.0 C-2 19 SPP (psi) Gallons/stroke TFABit Type Depth 10.040 MBT 2494' pH 0.994 0 0 0 Siltst 9.625" 0 0 Units* Casing Summary Lithology (%) 0303 0 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:T. Howe / H. Garney Set AtSize 62.6 Grade 16" (max)(current) Surface 0 0 Cly 2685 . . * 24 hr Recap: (max)(current) Surface 0 0 Cly 0 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:T. Howe / H. Garney 0 0 9.625" 0 0 Units* Casing Summary Lithology (%) 0 MBT 2494' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.043 C-5n - 0.0 C-2 0 in 0 -Minimum Depth Time: N/D diverter and N/U well head. 0 2494' 2494' 0' Max @ ft Current -- Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Dolcator/J. Haynes ShClyst TuffGvlCoal cP 9 282' 12.25"0.994 Footage 2212' 100 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 N/D Diverter PV 24 hr Max 40.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.50 000 Mud Motor DRILPLEX 12.0 282' 2495'25 2494' Depth in / out Mud Type Lst Type Average N/A0Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 0 1RR 2469' 114' ConditionBit # 1 8.5 12.25" 9.70 Mud Motor 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 12-Feb-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 2100.00 Performed surface cement job, circulated and displaced bump plug. R/D cement lines and equipment. Currently Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 1RR Mud Motor 12.25"0.994 282' N/U well head and tested BOP's. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32000.00 0 13-Feb-2015 12:00 AM Current Pump & Flow Data: 0 Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 5.5 12.25" 9.40 Mud Motor 9.40 Size 2 2469' 114' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min 0Background Trip Average N/A Mud Type Lst Type DRILPLEX 7.42495'19 Depth in / out YP (lb/100ft2) 11.50 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 100 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Test BOP's PV 282' Footage 2494'2212' R. Dolcator/J. Haynes ShClyst TuffGvlCoal cP 9 Gas Summary 0 0 0 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 2494' 2494' 0' Max @ ft Current -- Date: Time: 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 2.553 MBT 2494' pH 0.994 0 0 0 Siltst 9.625" 0 0 Units* Casing Summary Lithology (%) 00 0 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 62.6 Grade 16" Surface 0 0 Cly 0 . . * 24 hr Recap: Surface 0 0 Cly 0 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney 0 0 9.625" 0 0 Units* Casing Summary Lithology (%) 0 MBT 2494' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5n - 0.0 C-2 0 in 0 -Minimum Depth Time: P/U BHA #3. RIH to tag cement. 0 2494' 2494' 0' Max @ ft Current -- Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Dolcator/J. Haynes ShClyst TuffGvlCoal cP 282' 8.5" Footage 2494'2212' Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 P/U BHA #3, RIH PV 24 hr Max 40.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 000 PDC DRILPLEX 2494' 2495' Depth in / out Mud Type Lst Type Average N/A0BackgroundTrip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 0 2 2469' 114' ConditionBit # 1 12.25"Mud Motor Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 14-Feb-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l Finished testing BOP's. RIH w 5" DP to 2000' MD, slip and cut drill line. Racked back DP and began M/U, Density (ppg) out (sec/qt) Viscosity Cor Solids % 1RR Mud Motor 12.25"0.994 282' . . * 24 hr Recap: 1RR Mud Motor 12.25"0.994 282' Drilled out cement and displaced spud mud to 9.4ppg Kla-shield then began to drill ahead in intermediate section. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 36000.00 0 15-Feb-2015 12:00 AM Current Pump & Flow Data: 1521 Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 7.0 12.25" 9.50 Mud Motor 9.50 Size 2 2469' 114' 100% Gas In Air=10,000 Units38Connection Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min 9Background Trip Average N/A Mud Type Lst Type PDC Kla-shield - 2494' 3413'30 Depth in / out YP (lb/100ft2) 10.00 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 20 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Drilling Ahead PV 282' 8.5" Footage 2494'2212' R. Dolcator/J. Haynes ShClyst TuffGvlCoal cP 8 Gas Summary 0 0 0 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 301.0 Flow In (gpm) Flow In (spm) 2494' 3542' 1048' Max @ ft Current 3260'33.0 Date: Time: 8 in 0 2494'Minimum Depth C-5n 2763' 50.0 C-2 58 SPP (psi) Gallons/stroke TFABit Type Depth 5.053 MBT 2494' pH 0.994 0 0 0 Siltst 9.625" 569 190 Units* Casing Summary Lithology (%) 0 80 82 0 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 62.6 Grade 16" Surface 22 0 Cly 5009 . . * 24 hr Recap: Surface 3184 15 Cly 19384 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 312 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney 100 4022 389 9.625" 566 189 Units* Casing Summary Lithology (%) 18 MBT 2494' pH 0.994 0 348 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 7.053 C-5n 4134' 55.0 C-2 291 in 3 3816'Minimum Depth Time: 4000' MD to 4300' MD for increased data and cuttings sampling collection. 40 3542' 4840' 1298' Max @ ft Current 4297'59.0 Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 240.0 Flow In (gpm) Flow In (spm) Gas Summary 0 952 0 (current) R. Dolcator/J. Haynes ShClyst TuffGvlCoal cP 14 282' 8.5" Footage 2494'2212' Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Drilling Ahead PV 24 hr Max 40.0 Weight 333 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 0480 PDC Kla-shield - 2494' 4692'27 Depth in / out Mud Type Lst Type Average N/A19BackgroundTrip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 Units148Connection 2189 2 2469' 114' ConditionBit # 1 8.5 12.25" 9.70 Mud Motor 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 16-Feb-2015 12:00 AM Current Pump & Flow Data: 1800 Max 155 Chlorides mg/l 38000.00 Continued to drill ahead in intermediate section pumping hi-vis sweeps as necessary. Slowed ROP's down from Density (ppg) out (sec/qt) Viscosity Cor Solids % 1RR Mud Motor 12.25"0.994 282' . . * 24 hr Recap: 1RR Mud Motor 12.25"0.994 282' Continued to drill ahead to TD of 5110' MD per Geologist. Circulated 3 bottoms up then began to POOH. L/D BHA #3. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 124 17-Feb-2015 12:00 AM Current Pump & Flow Data: - Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 12.25"Mud Motor Size 2 2469' 114' 100% Gas In Air=10,000 Units70Connection 394 Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min N/ABackground Trip Average 8 Mud Type Lst Type PDC Kla-shield 2494' 5110' Depth in / out YP (lb/100ft2) 0530 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 247 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Testing BOP's PV 282' 8.5"0.990 Footage 2616' 2494'2212' J. Riley / D. Mickey ShClyst TuffGvlCoal cP Gas Summary 0 166 0 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 4840' 4840' 0' Max @ ft Current -- Date: Time: Performed weekly BOP test early as to not interrupt coring. 11 in 0 5034'Minimum Depth C-5n 4946' - C-2 71 SPP (psi) Gallons/stroke TFABit Type Depth MBT 2494' pH 0.994 0 54 0 Siltst 9.625" - - Units* Casing Summary Lithology (%) 173109 0 907-659-7092Unit Phone: 46 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 62.6 Grade 16" Surface 769 0 Cly 8535 . . * 24 hr Recap: Surface 468 0 Cly 9724 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 12 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney 591 0 9.625" 299 100 Units* Casing Summary Lithology (%) 12 MBT 2494' pH 0.994 0 22 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 7.5210 C-5n - - C-2 72 in 0 -Minimum Depth Time: coring fluid then added tracer fluid and circulating and conditioning throughout system. 5 5100' 5100' 0' Max @ ft Current -- Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 50 0 (current) J. Riley / D. Mickey ShClyst TuffGvlCoal cP 45 282' 8.5"0.990 Footage 2616' 2494'2212' Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Circulating PV 24 hr Max 40.0 Weight 280 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 0470 PDC LICF - 2494' 5100'45 5110' Depth in / out Mud Type Lst Type Average 8N/ABackground Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 173 2 2469' 114' ConditionBit # 1 8.5 12.25" 9.60 Mud Motor 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 18-Feb-2015 12:00 AM Current Pump & Flow Data: 842 Max 104 Chlorides mg/l 25000.00 Finished testing BOP's. Rigged up coring equipment and RIH to 5000' MD and displace mud system to low invasion Density (ppg) out (sec/qt) Viscosity Cor Solids % 1RR Mud Motor 12.25"0.994 282' . . * 24 hr Recap: 1RR Mud Motor 12.25"0.994 282' Circulated and conditioned coring mud with deuterium and began coring operations. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 43 19-Feb-2015 12:00 AM Current Pump & Flow Data: 1278 Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 12.25"Mud Motor Size 2 2469' 114' 100% Gas In Air=10,000 UnitsN/AConnection 158 Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min 11Background Trip Average N/A Mud Type Lst 70 Type PDC LICF 2494' 5174' 5110' Depth in / out YP (lb/100ft2) 3190 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 74 Hours C-3 20 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Coring PV 282' 8.5"0.990 Footage 2616' 2494'2212' J. Riley / D. Mickey ShClyst TuffGvlCoal cP Gas Summary 0 75 0 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 8.7 Flow In (gpm) Flow In (spm) 5100' 5171' 71' Max @ ft Current 517'6.1 Date: Time: 6 in 0 -Minimum Depth C-5n 5170' 1.6 C-2 27 SPP (psi) Gallons/stroke TFABit Type Depth MBT 5100' pH 0.994 0 26 0 Siltst 9.625" 299 100 Units* Casing Summary Lithology (%) 5 10 949 0 907-659-7092Unit Phone: 26 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 62.6 Grade 16" Surface 257 0 Cly 6370 . . * 24 hr Recap: Surface 283 0 Cly 2545 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 28 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney 1708 0 9.625" - - Units* Casing Summary Lithology (%) 19 MBT 5100' pH 0.994 0 29 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 8.5120 C-5n 5171' - C-2 32 in 0 -Minimum Depth Time: 26 5171' 5171' 0' Max @ ft Current 5174'1.5 Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 2.2 Flow In (gpm) Flow In (spm) Gas Summary 0 85 0 (current) J. Riley / D. Mickey ShClyst TuffGvlCoal cP 39 282' 8.5"0.990 Footage 2616' 2494'2212' 50 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 L/D Core Barrels PV 24 hr Max 40.0 Weight 183 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 22570 PDC LICF 3.8 2494' 5174'33 5110' Depth in / out Mud Type Lst 50 Type Average N/AN/ABackground Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 187 2 2469' 114' ConditionBit # 1 8.5 12.25" 9.70 Mud Motor 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 20-Feb-2015 12:00 AM Current Pump & Flow Data: - Max 122 Chlorides mg/l 25500.00 Cored to 5174' MD then POOH due to bit becoming stuck. L/D 74' of core. Density (ppg) out (sec/qt) Viscosity Cor Solids % 1RR Mud Motor 12.25"0.994 282' . . * 24 hr Recap: 2616'2 PDC 8.5"0.990 2494' 1RR Mud Motor 12.25"0.994 282' Finished L/D Core #1, P/U 8 core barrels and RIH to 5174' MD, circulated and conditioned mud, dropped ball, Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 27000.00 97 21-Feb-2015 12:00 AM Current Pump & Flow Data: 1547 Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 9.0 12.25" 9.70 Mud Motor 9.70 Size 3 2469' 114' 100% Gas In Air=10,000 UnitsN/AConnection 160 Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min N/ABackground Trip Average 46 Mud Type Lst Type Coring Bit LICF 3.45206'32 Depth in / out YP (lb/100ft2) 9.40 04515 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 152 Hours C-3 80 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Coring PV 282' 8.5" Footage 2494'2212' 5110' J. Riley / D. Mickey ShClyst TuffGvlCoal cP 33 Gas Summary 0 76 27 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 7.6 Flow In (gpm) Flow In (spm) 5174' 5220' 46' Max @ ft Current 5180'4.0 Date: Time: began cutting core #2 11 in 0 -Minimum Depth C-5n 5175' 1.4 C-2 46 SPP (psi) Gallons/stroke TFABit Type Depth 8.8120 MBT 5100' pH 0.994 0 25 0 Siltst 9.625" 302 101 Units* Casing Summary Lithology (%) 15 20 1325 0 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 62.6 Grade 16" Surface 329 0 Cly 5696 . . * 24 hr Recap: Surface 177 0 Cly 1402 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney 1121 0 9.625" - - Units* Casing Summary Lithology (%) 17 MBT 5100' pH 0.994 0 21 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 9.0115 C-5n 5240' - C-2 33 in 0 -Minimum Depth Time: 12 5220' 5262' 42' Max @ ft Current 5250'1.1 Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 7.7 Flow In (gpm) Flow In (spm) Gas Summary 0 64 27 (current) J. Riley / D. Mickey ShClyst TuffGvlCoal cP 40 282' 8.5" Footage 2494'2212' 5110' 30 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 L/D Core #2 PV 24 hr Max 40.0 Weight 143 Hours C-3 30 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.40 05221 Coring Bit LICF 6.85261'33 Depth in / out Mud Type Lst 40 Type Average 3N/ABackground Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 124 3 2469' 114' ConditionBit # 1 9.5 12.25" 9.70 Mud Motor 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 15 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 22-Feb-2015 12:00 AM Current Pump & Flow Data: 47 Max 98 Chlorides mg/l 24000.00 Continued to core ahead to 5262' MD then POOH to L/D core #2. Density (ppg) out (sec/qt) Viscosity Cor Solids % 1RR Mud Motor 12.25"0.994 282' 2616'2 PDC 8.5"0.990 2494' . . * 24 hr Recap: 2616'2 PDC 8.5"0.990 2494' 1RR Mud Motor 12.25"0.994 282' Finished P/U core #3, RIH to surface shoe, slip and cut drill line, conducted weekly BOP test then continued to RIH Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 24000.00 40 23-Feb-2015 12:00 AM Current Pump & Flow Data: 49 Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 9.5 12.25" 9.80 Mud Motor 9.80 Size 3 2469' 114' 100% Gas In Air=10,000 UnitsN/AConnection 76 Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min N/ABackground Trip Average 10 Mud Type Lst 40 Type Coring Bit LICF 3.05261'33 Depth in / out YP (lb/100ft2) 9.30 0239 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 56 Hours C-3 3030 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 RIH w/ Core #3 PV 282' 8.5" Footage 2494'2212' 5110' J. Riley / D. Mickey ShClyst TuffGvlCoal cP 31 Gas Summary 0 14 18 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 5262' 5262' 0' Max @ ft Current -- Date: Time: to 5261' MD 2 in 0 -Minimum Depth C-5n - - C-2 42 SPP (psi) Gallons/stroke TFABit Type Depth 9.0110 MBT 5100' pH 0.994 0 13 0 Siltst 9.625" - - Units* Casing Summary Lithology (%) 7513 0 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 62.6 Grade 16" Surface 115 0 Cly 2957 . . * 24 hr Recap: Surface 617 0 Cly 9014 Set AtSize 62.6 Grade 16" 907-659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney 30 4197 0 9.625" - - Units* Casing Summary Lithology (%) 40 MBT 5100' pH 0.994 0 48 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 9.0111 C-5n - - C-2 149 in 0 -Minimum Depth Time: 30 5262' 5307' 45' Max @ ft Current 5263'1.4 Date: Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 59.0 Flow In (gpm) Flow In (spm) Gas Summary 0 130 48 (current) J. Riley / A. Romero ShClyst TuffGvlCoal cP 33 282' 8.5" Footage 2494'2212' 5110' 40 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 POOH w/ Core #3 PV 24 hr Max 40.0 Weight 397 Hours C-3 10 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 441199 Coring Bit LICF 3.25306'21 Depth in / out Mud Type Lst 20 Type Average 10N/ABackground Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 318 3 2469' 114' ConditionBit # 1 9.5 12.25" 9.80 Mud Motor 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: Morning Report Report # 17 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth 24-Feb-2015 12:00 AM Current Pump & Flow Data: 49 Max 252 Chlorides mg/l 24000.00 Continued to run into the hole and began coring to 5307' MD. POOH per trip schedule. Density (ppg) out (sec/qt) Viscosity Cor Solids % 1RR Mud Motor 12.25"0.994 282' 2616'2 PDC 8.5"0.990 2494' . . * 24 hr Recap: 2616'2 PDC 8.5"0.990 2494' 1RR Mud Motor 12.25"0.994 282' Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 22000.00 327 25-Feb-2015 12:00 AM Current Pump & Flow Data: 1659 Max Conductor ROP ROP (ft/hr) 3.56 @ Mud Data Depth Morning Report Report # 18 Customer: Well: Area: Location: Rig: Moraine #1 ConocoPhillips Alaska, Inc. Moraine North Slope Job No.: Daily Charges: Total Charges: MWD Summary 97% Rig Activity: Nabors 9ES Report For: ConditionBit # 1 9.0 12.25" 9.70 Mud Motor 9.70 Size 3 to TD at 5306' MD. Began drilling ahead to 5355' MD. 2469' 114' 100% Gas In Air=10,000 UnitsN/AConnection 50 498 Tools Telescope API FL Chromatograph (ppm) 0'282' WOB Conductor Avg Min Comments Surface RPM ECD (ppg) ml/30min 60Background Trip Average N/A Mud Type Lst 30 Type Coring Bit LICF 3.45306'20 Depth in / out YP (lb/100ft2) 9.40 4112536 08 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 569 Hours C-3 20 Ss (ppb Eq) C-1 C-5i AK-AM-0902129759 Drilling Aheaad PV 282' 8.5" Footage 2494'2212' 5110' J. Riley / A. Romero ShClyst TuffGvlCoal cP 32 Gas Summary 0 187 52 (current) Avg to282' Yesterday's Depth: Current Depth: 24 Hour Progress: 114.7 Flow In (gpm) Flow In (spm) 5307' 5355' 48' Max @ ft Current 5263'56.0 Date: Time: Finished laying down coring BHA. Picked up new drilling BHA and tripped into the hole to 5080' MD. Reamed and logged 76 in 5 5322'Minimum Depth C-5n 5321' 40.0 C-2 109 SPP (psi) Gallons/stroke TFABit Type Depth 9.097 MBT 5100' pH 0.994 15 70 0 Siltst 9.625" 512 171 Units* Casing Summary Lithology (%) 465321 157 907-659-7092Unit Phone: 61 T. Wilson Maximum Report By:Logging Engineers:T. Wilson / H. Garney Set AtSize 62.6 Grade 16" Surface 866 23 Cly 8666 WELL INFORMATION Created On : Mar 13 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :Moraine #1 Job Number :AK-XX-0902129759 Rig Name :Nabors 9ES Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 50.15 0.07 15.81 50.15 0.03 N 0.01 E 0.03 0.14 143.12 0.16 65.13 143.12 0.14 N 0.14 E 0.14 0.14 232.43 0.60 236.09 232.43 0.07 S 0.13 W -0.07 0.85 328.18 0.51 247.16 328.17 0.51 S 0.94 W -0.51 0.15 417.48 0.44 324.33 417.47 0.39 S 1.51 W -0.39 0.67 505.97 0.84 344.58 505.96 0.51 N 1.88 W 0.51 0.51 599.49 1.86 8.96 599.45 2.67 N 1.82 W 2.67 1.23 687.75 4.25 21.88 687.58 7.12 N 0.38 W 7.12 2.80 779.88 4.66 25.03 779.43 13.68 N 2.47 E 13.68 0.52 878.30 7.03 31.61 877.33 22.43 N 7.32 E 22.43 2.50 972.19 8.42 32.85 970.37 33.10 N 14.06 E 33.10 1.49 1065.74 10.98 30.60 1,062.57 46.53 N 22.31 E 46.53 2.77 1159.66 12.72 30.02 1,154.49 63.18 N 32.04 E 63.18 1.86 1254.76 14.89 31.12 1,246.84 82.71 N 43.60 E 82.71 2.30 1348.98 16.59 31.82 1,337.52 104.50 N 56.95 E 104.50 1.82 1443.23 18.60 32.79 1,427.36 128.57 N 72.18 E 128.57 2.16 1541.36 18.08 32.64 1,520.50 154.55 N 88.87 E 154.55 0.53 1632.47 17.53 33.08 1,607.25 177.95 N 103.98 E 177.95 0.62 1726.28 16.85 33.77 1,696.87 201.09 N 119.25 E 201.09 0.76 1819.99 15.26 28.04 1,786.92 223.27 N 132.60 E 223.27 2.39 1914.34 15.06 28.54 1,877.99 245.00 N 144.29 E 245.00 0.25 2007.85 11.95 25.83 1,968.90 264.39 N 154.32 E 264.39 3.39 2102.27 11.06 27.45 2,061.43 281.23 N 162.75 E 281.23 1.00 2196.45 9.62 27.24 2,154.07 296.24 N 170.52 E 296.24 1.53 2291.25 6.91 27.86 2,247.88 308.33 N 176.81 E 308.33 2.86 2384.85 3.77 32.87 2,341.06 315.89 N 181.11 E 315.89 3.39 2423.89 1.83 52.14 2,380.06 317.35 N 182.30 E 317.35 5.46 2536.29 0.22 104.60 2,492.44 318.40 N 183.93 E 318.40 1.52 2631.39 0.06 60.09 2,587.54 318.38 N 184.15 E 318.38 0.19 INSITE V8.1.10 Page 1Job No:AK-XX-0902129759 Well Name:Moraine #1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2725.23 0.09 23.91 2,681.38 318.47 N 184.22 E 318.47 0.06 2819.77 0.06 156.10 2,775.92 318.49 N 184.27 E 318.49 0.15 2913.81 0.09 313.33 2,869.96 318.50 N 184.24 E 318.50 0.16 3007.68 0.09 251.92 2,963.83 318.53 N 184.11 E 318.53 0.10 3101.93 0.06 325.19 3,058.08 318.54 N 184.02 E 318.54 0.10 3195.68 0.11 103.19 3,151.83 318.56 N 184.08 E 318.56 0.17 3289.79 0.06 96.32 3,245.94 318.54 N 184.21 E 318.54 0.05 3384.25 0.06 39.98 3,340.40 318.57 N 184.29 E 318.57 0.06 3572.50 0.06 311.74 3,528.64 318.71 N 184.28 E 318.71 0.04 3759.61 0.09 137.59 3,715.75 318.67 N 184.31 E 318.67 0.08 3853.81 0.09 58.52 3,809.95 318.65 N 184.42 E 318.65 0.12 3948.64 0.09 19.22 3,904.78 318.76 N 184.51 E 318.76 0.06 4042.70 0.09 63.71 3,998.84 318.86 N 184.60 E 318.86 0.07 4137.28 0.06 93.38 4,093.42 318.89 N 184.72 E 318.89 0.05 4232.51 0.09 295.36 4,188.65 318.92 N 184.70 E 318.92 0.15 4326.94 0.09 71.16 4,283.08 318.98 N 184.70 E 318.98 0.18 4421.03 0.09 216.54 4,377.17 318.94 N 184.73 E 318.94 0.18 4515.67 0.06 17.18 4,471.81 318.93 N 184.70 E 318.93 0.16 4610.28 0.09 332.90 4,566.42 319.04 N 184.68 E 319.04 0.07 4704.10 0.09 151.28 4,660.24 319.04 N 184.68 E 319.04 0.19 4797.74 0.06 261.05 4,753.88 318.97 N 184.67 E 318.97 0.13 4891.66 0.06 325.28 4,847.80 319.01 N 184.59 E 319.01 0.07 5038.29 0.12 333.74 4,994.43 319.21 N 184.48 E 319.21 0.04 5371.42 0.09 90.77 5,327.56 319.52 N 184.59 E 319.52 0.05 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (Grid) - A total correction of 0.00 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 5,371.42 feet is 369.00 feet along 30.02 degrees (Grid) INSITE V8.1.10 Page 2Job No:AK-XX-0902129759 Well Name:Moraine #1 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 3Job No:AK-XX-0902129759 Well Name:Moraine #1 Survey Report 28-Feb-15 22:43:18 Prepared by: Hoda Tahani Fransiska Goenawan Reviewed by: Rohin Naveena-Chandran Formation & Reservoir Solutions (FRS) RDT Interpretation Report Formation Testing and Sampling Conoco Phillips Alaska Moraine#1 Moraine 8.5” Open Hole Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 2 Table of Contents Table of Contents .................................................................................................................................... 2 Overview ................................................................................................................................................. 6 Tool String Diagram ................................................................................................................................. 7 Pressure Test Summary ........................................................................................................................... 8 Pressure and Mobility Summary ............................................................................................................ 11 Sample Summary................................................................................................................................... 13 Gradient Plots and Pressure Gradients............................................................................................... 14 Gradient Plot in Coyote Formation .................................................................................................... 15 Gradient Plot in Moraine Formation ...................................................................................................... 16 Composite Plot in Coyote Formation ................................................................................................. 17 Plots ...................................................................................................................................................... 19 Test No. 1.1; MD: 5252.70 ft; TVD: 5208.85 ft .................................................................................... 19 Test No. 1.2; MD: 5252.70 ft; TVD: 5208.85 ft .................................................................................... 20 Test No. 1.3; MD: 5252.70 ft; TVD: 5208.85 ft .................................................................................... 21 Test No. 1.4; MD: 5252.70 ft; TVD: 5208.85 ft .................................................................................... 22 Test No. 1.5 (After Pumping); MD: 5252.70 ft; TVD: 5208.85 ft .......................................................... 23 Bubble Point; MD: 5252.70 ft; TVD: 5208.85 ft................................................................................... 24 Fluid ID Plot; MD: 5252.70 ft; TVD: 5208.85 ft .................................................................................... 25 5252.70 ft RDT Fluid ID Second Sample .............................................................................................. 26 5252.70 ft RDT Fluid ID Third Sample ................................................................................................. 26 Contamination Estimation; MD: 5252.70 ft; TVD: 5208.85 ft .............................................................. 27 Test No. 2.1; MD: 5271.96 ft; TVD: 5228.11 ft .................................................................................... 30 Test No. 2.2; MD: 5271.96 ft; TVD: 5228.11 ft .................................................................................... 31 Test No. 3.1; MD: 5382.54 ft; TVD: 5338.68 ft .................................................................................... 32 Test No. 4.1; MD: 5372.29 ft; TVD: 5328.43 ft .................................................................................... 33 Test No. 5.1; MD: 5371.50 ft; TVD: 5327.65 ft .................................................................................... 34 Test No. 5.2; MD: 5371.50 ft; TVD: 5327.65 ft .................................................................................... 35 Test No. 5.3; MD: 5371.50 ft; TVD: 5327.65 ft .................................................................................... 36 Test No. 5.4; MD: 5371.50 ft; TVD: 5327.65 ft .................................................................................... 37 Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 3 Test No. 6.1; MD: 5350.00 ft; TVD: 5306.14 ft .................................................................................... 38 Test No. 7.1; MD: 5284.52 ft; TVD: 5240.67 ft .................................................................................... 39 Test No. 7.2; MD: 5284.52 ft; TVD: 5240.67 ft .................................................................................... 40 Test No. 7.3; MD: 5284.52 ft; TVD: 5240.67 ft .................................................................................... 41 Test No. 7.4; MD: 5284.52 ft; TVD: 5240.67 ft .................................................................................... 42 Fluid ID Plot: 5284.52 ft; TVD: 5240.67 ft ........................................................................................... 43 Fluid ID Plot at 5284.5 ft , Zoomed in Plot (Samples) .......................................................................... 44 Test No. 8.1; MD: 5304.03 ft; TVD: 5260.17 ft .................................................................................... 47 Test No. 8.2; MD: 5304.03 ft; TVD: 5260.17 ft .................................................................................... 48 Test No. 8.3; MD: 5304.03 ft; TVD: 5260.17 ft .................................................................................... 49 Test No. 8.4; MD: 5304.03 ft; TVD: 5260.17 ft .................................................................................... 50 Test No. 8.5; MD: 5304.03 ft; TVD: 5260.17 ft .................................................................................... 51 Test No. 9.1; MD: 5330.01 ft; TVD: 5286.16 ft .................................................................................... 52 Test No. 9.2; MD: 5330.01 ft; TVD: 5286.16 ft .................................................................................... 53 Test No. 9.3; MD: 5330.01 ft; TVD: 5286.16 ft .................................................................................... 54 Test No. 9.4; MD: 5330.01 ft; TVD: 5286.16 ft .................................................................................... 55 Test No. 10.1; MD: 5217.03 ft; TVD: 5173.17 ft .................................................................................. 56 Test No. 10.2; MD: 5217.03 ft; TVD: 5173.17 ft .................................................................................. 57 Test No. 10.3; MD: 5217.03 ft; TVD: 5173.17 ft .................................................................................. 58 Test No. 10.4; MD: 5217.03 ft; TVD: 5173.17 ft .................................................................................. 59 Test No. 10.5 (After Pumping); MD: 5217.03 ft; TVD: 5173.17 ft ........................................................ 60 Test No. 10.6 (After Pumping); MD: 5217.03 ft; TVD: 5173.17 ft ........................................................ 61 Test No. 10.7 (After Pumping); MD: 5217.03 ft; TVD: 5173.17 ft ........................................................ 62 Bubble Point; MD: 5217.03 ft; TVD: 5173.17 ft................................................................................... 63 Fluid ID Plot; MD: 5217.03 ft; TVD: 5173.17 ft .................................................................................... 64 Fluid ID Plot at 5217.03 ft , First Sample ............................................................................................. 65 Fluid ID Plot at 5217.03 ft , Second Sample ........................................................................................ 65 Contamination Estimation; MD: 5217.03 ft; TVD: 5173.17 ft .............................................................. 66 Test No. 11.4; MD: 4133.00 ft; TVD: 4089.15 ft .................................................................................. 69 Test No. 11.2; MD: 4133.00 ft; TVD: 4089.15 ft .................................................................................. 70 Test No. 11.3; MD: 4133.00 ft; TVD: 4089.15 ft .................................................................................. 71 Test No. 11.4; MD: 4133.00 ft; TVD: 4089.15 ft .................................................................................. 72 Test No. 12.1; MD: 4142.10 ft; TVD: 4098.25 ft .................................................................................. 73 Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 4 Test No. 12.2; MD: 4142.10 ft; TVD: 4098.25 ft .................................................................................. 74 Test No. 13.1; MD: 4141.01 ft; TVD: 4097.16 ft .................................................................................. 75 Test No. 13.2; MD: 4141.01 ft; TVD: 4097.16 ft .................................................................................. 76 Test No. 13.3; MD: 4141.01 ft; TVD: 4097.16 ft .................................................................................. 77 Test No. 14.1; MD: 4132.02 ft; TVD: 4088.17 ft .................................................................................. 78 Test No. 14.2; MD: 4132.02 ft; TVD: 4088.17 ft .................................................................................. 79 Test No. 15.1; MD: 4234.90 ft; TVD: 4191.04 ft .................................................................................. 80 Test No. 16.1; MD: 4234.90 ft; TVD: 4191.04 ft .................................................................................. 81 Test No. 17.1; MD: 4234.84 ft; TVD: 4190.98 ft .................................................................................. 82 Test No. 17.2; MD: 4234.84 ft; TVD: 4190.98 ft .................................................................................. 83 Test No. 17.3; MD: 4234.84 ft; TVD: 4190.98 ft .................................................................................. 84 Test No. 18.1; MD: 5297.55 ft; TVD: 5253.70 ft .................................................................................. 85 Test No. 18.2; MD: 5297.55 ft; TVD: 5253.70 ft .................................................................................. 86 Test No. 18.3; MD: 5297.55 ft; TVD: 5253.70 ft .................................................................................. 87 Test No. 19.1; MD: 5321.20 ft; TVD: 5277.34 ft .................................................................................. 88 Test No. 20.1; MD: 5362.47 ft; TVD: 5318.61 ft .................................................................................. 89 Test No. 20.2; MD: 5362.47 ft; TVD: 5318.61 ft .................................................................................. 90 Test No. 20.3; MD: 5362.47 ft; TVD: 5318.61 ft .................................................................................. 91 Test No. 20.4; MD: 5362.47 ft; TVD: 5318.61 ft .................................................................................. 92 Test No. 21.1; MD: 5285.37 ft; TVD: 5241.51 ft .................................................................................. 93 Test No. 21.2; MD: 5285.37 ft; TVD: 5241.51 ft .................................................................................. 94 Test No. 21.3; MD: 5285.37 ft; TVD: 5241.51 ft .................................................................................. 95 Test No. 21.4; MD: 5285.37 ft; TVD: 5241.51 ft .................................................................................. 96 Test No. 21.5; MD: 5285.37 ft; TVD: 5241.51 ft .................................................................................. 97 Test No. 22.1; MD: 4133.10 ft; TVD: 4089.24 ft .................................................................................. 98 Test No. 22.2; MD: 4133.10 ft; TVD: 4089.24 ft .................................................................................. 99 Test No. 22.3; MD: 4133.10 ft; TVD: 4089.24 ft ................................................................................ 100 Test No. 23.1; MD: 4234.78 ft; TVD: 4190.92 ft ................................................................................ 101 Test No. 23.2; MD: 4234.78 ft; TVD: 4190.92 ft ................................................................................ 102 Test No. 23.3; MD: 4234.78 ft; TVD: 4190.92 ft ................................................................................ 103 Disclaimer ........................................................................................................................................... 104 Drawdown Buildup Analysis ................................................................................................................ 105 Exact Mobility Analysis .................................................................................................................... 105 Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 5 Test Quality Parameters .................................................................................................................. 107 Automatic Test Comments .............................................................................................................. 108 Dual Probe Anisotropy Analysis (Vertical Interference Testing) ........................................................ 109 Anisotropy Dip-angle Corrections ................................................................................................ 109 Flow Rate Determination ................................................................................................................. 110 Automatic Flow Rate Option ........................................................................................................ 110 Manual Flow Rate Option ............................................................................................................ 110 Manual Volume Option ................................................................................................................ 110 RTS Mobility Drawdown and Buildup Calculation Summary ............................................................. 111 Table 1 PTA Spherical Flow Regime Calculations (Typical Physical Units) ..................................... 111 Table 2 PTA Radial Flow Regime Calculations (Typical Physical Units) ........................................... 111 Table 3 PTA Variables & Constants Using Internal Program (Typical Physical Units) ..................... 112 Table 4 PTA Spherical Flow Regime Calculations (SI Units) ........................................................... 113 Table 5 PTA Radial Flow Regime Calculations (SI Units) ................................................................ 113 Table 6 PTA Variables & Constants Using Internal Program SI Units ............................................. 114 RTS Theory References .................................................................................................................... 115 Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 6 Overview At the request of ConocoPhillips Alaska Inc, Halliburton ran the RDT tool configured with one Oval Pad Section (OPS) and one Dual Probe Section (DPS) in the Moraine #1 well, Moraine field, U.S.A., in an 8.5 inch open hole for formation pressures, mobility, fluid ID, sampling, and establishing gradient. 23 pressure points and 7 samples (5 oil samples and 2 water samples) from three depths were taken during the job; all are captured by N2 chambers. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 7 Tool String Diagram Pressure 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 2-8.1 5252.70 5208.85 2658.53 2644.48 8.35 9.76 2261.00 2220.46 2261.05 383.42 128.00 10.25 140.50 Good Test 1.2 2-8.2 5252.70 5208.85 2658.53 2644.48 8.35 9.76 2261.00 2220.46 2261.05 383.42 128.00 10.25 140.50 Good Test 1.3 2-8.3 5252.70 5208.85 2658.53 2644.48 8.35 9.76 2260.18 2191.25 2260.90 383.58 128.30 10.00 161.75 Good Test 1.4 2-8.4 5252.70 5208.85 2658.53 2644.48 8.35 9.76 2261.00 2134.86 2260.83 383.65 127.80 8.00 305.75 Good Test 1.5 2-8.5 5252.70 5208.85 2658.53 2644.48 8.34 9.76 2257.29 2090.42 2258.40 386.07 129.40 30.25 236.00 Good Test 2.1 2-9.1 5271.96 5228.11 2654.92 2653.58 8.41 9.76 2300.60 2028.84 2286.16 367.42 134.90 21.00 391.50 Good Test 2.2 2-9.2 5271.96 5228.11 2654.92 2653.58 8.41 9.76 2300.60 2028.84 2286.16 367.42 134.90 21.00 391.50 Good Test 3.1 2-10.1 5382.54 5338.68 2734.57 2725.88 8.39 9.82 2300.10 1908.57 2329.93 395.95 133.00 2.51 103.50 Tight Test 4.1 2-11.1 5372.29 5328.43 2713.45 2707.67 8.17 9.77 2324.06 1602.30 2264.76 442.91 134.50 25.78 118.64 Tight Test 5.1 2-12.1 5371.50 5327.65 2705.95 2705.76 8.33 9.77 2304.75 2082.54 2308.22 397.54 136.10 25.51 379.92 Good Test 5.2 2-12.2 5371.50 5327.65 2705.95 2705.76 8.33 9.77 2304.75 2082.54 2308.22 397.54 136.10 25.51 379.92 Good Test 5.3 2-12.3 5371.50 5327.65 2705.95 2705.76 8.31 9.77 2310.60 1797.58 2302.82 402.94 136.10 24.76 127.06 Good Test 5.4 2-12.4 5371.50 5327.65 2705.95 2705.76 8.33 9.77 2305.22 1861.41 2307.88 397.88 136.10 10.50 336.15 Good Test 6.1 2-13.1 5350.00 5306.14 2693.09 2696.53 8.27 9.77 2228.11 1791.63 2281.24 415.29 137.00 9.49 119.17 Tight Test 7.1 2-14.1 5284.52 5240.67 2663.88 2664.36 8.40 9.78 2292.22 2202.36 2289.93 374.44 137.50 20.75 44.50 Good Test 7.2 2-14.2 5284.52 5240.67 2663.88 2664.36 8.40 9.78 2292.22 2202.36 2289.93 374.44 137.50 20.75 44.50 Good Test 7.3 2-14.3 5284.52 5240.67 2663.88 2664.36 8.41 9.78 2290.36 2202.54 2291.40 372.96 137.30 20.50 190.00 Good Test 7.4 2-14.4 5284.52 5240.67 2663.88 2664.36 8.41 9.78 2291.74 2126.48 2291.52 372.84 137.70 20.25 279.75 Good Test 8.1 2-15.1 5304.03 5260.17 2681.42 2670.67 8.41 9.76 2306.95 1781.37 2301.62 369.05 137.80 20.26 382.42 Good Test 8.2 2-15.2 5304.03 5260.17 2681.42 2670.67 8.41 9.76 2306.95 1781.37 2301.56 369.11 137.80 20.26 382.42 Good Test 8.3 2-15.3 5304.03 5260.17 2681.42 2670.67 8.41 9.76 2302.11 1702.49 2299.52 371.15 138.40 60.03 556.74 Good Test 8.4 2-15.4 5304.03 5260.17 2681.42 2670.67 8.40 9.76 2300.43 1717.28 2298.54 372.13 138.80 60.53 621.02 Good Test 8.5 2-15.5 5304.03 5260.17 2681.42 2670.67 8.40 9.76 2296.01 2028.68 2297.43 373.24 139.00 50.27 272.37 Good Test 9.1 2-16.1 5330.01 5286.16 2696.71 2684.46 8.39 9.77 2324.09 2021.87 2307.11 377.35 141.30 60.49 447.67 Good Test 9.2 2-16.2 5330.01 5286.16 2696.71 2684.46 8.39 9.77 2324.09 2021.87 2307.11 377.35 141.30 60.49 447.67 Good Test 9.3 2-16.3 5330.01 5286.16 2696.71 2684.46 8.39 9.77 2308.71 2017.64 2306.38 378.08 141.50 60.74 502.91 Good Test 9.4 2-16.4 5330.01 5286.16 2696.71 2684.46 8.39 9.77 2306.80 2227.53 2306.81 377.65 141.60 21.00 185.97 Good Test 10.1 2-20.7 5217.03 5173.17 2632.33 2190.32 8.44 8.14 2271.11 2244.02 2269.39 -79.07 139.40 20.25 86.25 Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 9 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) 10.2 2-20.1 5217.03 5173.17 2632.33 2190.32 8.44 8.14 2271.11 2244.02 2269.40 -79.08 131.40 20.25 86.25 Good Test 10.3 2-20.2 5217.03 5173.17 2632.33 2190.32 8.44 8.14 2269.93 2244.38 2269.34 -79.02 139.10 20.75 86.50 Good Test 10.4 2-20.3 5217.03 5173.17 2632.33 2190.32 8.44 8.14 2269.19 2226.09 2269.26 -78.94 138.70 20.25 163.25 Good Test 10.5 2-20.4 5217.03 5173.17 2632.33 2628.87 8.42 9.77 2265.83 2224.80 2263.82 365.05 139.60 20.25 386.25 Good Test 10.6 2-20.5 5217.03 5173.17 2632.33 2628.87 8.42 9.77 2263.97 2223.86 2263.70 365.17 139.60 20.25 261.25 Good Test 10.7 2-20.6 5217.03 5173.17 2632.33 2628.87 8.42 9.77 2264.15 2254.96 2263.85 365.02 139.60 24.75 277.25 Good Test 11.1 2-24.1 4133.00 4089.15 2092.93 2086.78 8.50 9.81 1807.19 1670.16 1806.51 280.27 116.10 50.52 782.25 Good Test 11.2 2-24.2 4133.00 4089.15 2092.92 2086.27 8.49 9.81 1809.24 1674.14 1805.33 280.94 113.10 50.52 719.23 Good Test 11.3 2-24.3 4133.00 4089.15 2092.92 2086.27 8.49 9.81 1809.24 1745.35 1806.32 279.95 113.20 21.26 533.42 Good Test 12.1 2-25.1 4142.10 4098.25 2097.26 2101.11 8.53 9.86 1819.61 1607.81 1818.07 283.04 108.70 20.25 1187.02 Lost Seal 12.2 2-25.2 4142.10 4098.25 2097.26 2101.11 8.53 9.86 1819.61 1607.81 1818.07 283.04 108.70 20.25 1187.02 Lost Seal 13.1 2-26.1 4141.01 4097.16 2090.69 2091.87 8.50 9.82 1823.59 1642.35 1810.30 281.57 108.10 10.50 316.50 Good Test 13.2 2-26.2 4141.01 4097.16 2090.69 2091.87 8.50 9.82 1823.59 1642.35 1810.30 281.57 108.10 10.50 316.50 Good Test 13.3 2-26.3 4141.01 4097.16 2090.69 2091.87 8.50 9.82 1813.18 1715.76 1809.99 281.88 107.90 25.50 382.75 Good Test 14.1 2-27.1 4132.02 4088.17 2088.23 2086.64 8.49 9.82 1794.85 1744.67 1805.60 281.04 110.00 77.00 610.25 Good Test 14.2 2-27.2 4132.02 4088.17 2088.23 2086.64 8.49 9.82 1794.85 1744.67 1805.60 281.04 110.00 77.00 610.25 Good Test 15.1 2-28.1 4234.90 4191.04 2155.81 2146.73 9.21 9.85 2241.46 1812.69 2007.12 139.61 107.80 20.02 47.04 Lost Seal 16.1 2-29.1 4234.90 4191.04 2146.76 2143.87 9.84 9.84 2159.61 2132.73 2144.49 -0.62 107.90 23.02 39.03 No Seal 17.1 2-30.1 4234.84 4190.98 2138.65 2134.71 8.47 9.80 1846.54 1717.87 1845.08 289.63 107.80 25.76 511.39 Good Test 17.2 2-30.2 4234.84 4190.98 2138.65 2134.71 8.47 9.80 1846.54 1717.87 1845.08 289.63 107.80 25.76 511.39 Good Test 17.3 2-30.3 4234.84 4190.98 2138.65 2134.71 8.46 9.80 1846.28 1712.54 1844.70 290.00 107.80 25.51 505.89 Good Test 18.1 2-34.1 5297.55 5253.70 2683.70 2668.50 8.44 9.77 2750.22 2012.31 2304.62 363.88 135.00 25.50 759.60 Good Test 18.2 2-34.2 5297.55 5253.70 2683.70 2668.50 8.44 9.77 2750.22 2012.31 2304.62 363.88 135.00 25.50 759.60 Good Test 18.3 2-34.3 5297.55 5253.70 2683.70 2668.50 8.43 9.77 2337.72 2056.75 2304.24 364.27 135.10 10.00 515.07 Good Test 19.1 2-35.1 5321.20 5277.34 2678.24 2678.43 7.93 9.76 2400.56 1418.56 2176.25 502.18 135.10 5.75 164.21 Tight Test 20.1 2-36.6 5362.47 5318.61 2713.98 2698.48 8.31 9.76 2420.60 2000.66 2298.95 399.53 137.10 25.75 156.50 Good Test 20.2 2-36.3 5362.47 5318.61 2713.98 2698.48 8.31 9.76 2420.60 2000.66 2298.95 399.53 137.20 25.75 156.50 Good Test 20.3 2-36.4 5362.47 5318.61 2713.98 2698.48 8.31 9.76 2325.72 1924.21 2298.95 399.53 137.20 13.50 274.50 Good Test 20.4 2-36.5 5362.47 5318.61 2713.98 2698.48 8.31 9.76 2304.49 1960.28 2298.94 399.54 137.20 13.25 430.75 Good Test 21.1 2-37.8 5285.37 5241.51 2662.63 2661.14 8.38 9.76 2280.47 1948.15 2284.73 376.41 138.50 10.50 223.75 Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 10 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) 21.2 2-37.2 5285.37 5241.51 2662.63 2661.14 8.38 9.76 2280.47 1948.15 2284.73 376.41 138.50 10.50 223.75 Good Test 21.3 2-37.3 5285.37 5241.51 2662.63 2661.14 8.37 9.76 2285.47 2156.48 2282.38 378.76 138.50 26.00 266.25 Good Test 21.4 2-37.6 5285.37 5241.51 2662.63 2661.14 8.37 9.76 2284.81 2158.51 2282.57 378.57 138.60 25.75 236.25 Good Test 21.5 2-37.7 5285.37 5241.51 2662.63 2661.14 8.37 9.76 2281.03 2174.86 2282.55 378.59 138.60 25.50 112.50 Good Test 21.6 2-37.8 5285.37 5241.51 2662.63 2661.14 8.38 9.76 2280.47 1948.15 2284.73 376.41 138.50 10.50 223.75 Good Test 22.1 2-39.1 4133.10 4089.24 2092.04 2088.43 8.49 9.82 1808.29 1665.92 1804.37 284.06 121.30 25.26 206.07 Good Test 22.2 2-39.2 4133.10 4089.24 2092.04 2088.43 8.49 9.82 1808.29 1665.92 1804.37 284.06 121.30 25.26 206.07 Good Test 22.3 2-39.3 4133.10 4089.24 2092.04 2088.43 8.49 9.82 1805.21 1665.99 1804.64 283.78 119.90 25.51 266.09 Good Test 23.1 2-40.1 4234.78 4190.92 2166.15 1802.15 8.47 8.27 1847.85 1645.59 1845.29 -43.14 113.70 20.27 249.99 Good Test 23.2 2-40.2 4234.78 4190.92 2166.15 1802.15 8.47 8.27 1847.85 1645.59 1845.29 -43.14 113.70 20.27 249.99 Good Test 23.3 2-40.3 4234.78 4190.92 2166.15 1802.15 8.47 8.27 1846.29 1648.61 1844.90 -42.75 113.30 20.52 239.23 Good Test Legend: Phyds1: Initial Hydrostatic Pressure Phyds2: Final Hydrostatic Pressure EqFmMw:Equivalent Formation Mud Weight (Pstop / (TVD * Constant)) 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 Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 11 Pressure and Mobility Summary Test Identification PTA Pressure PTA Mobilities Remarks Test No. File No. MD (ft) TVD (ft) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 1.2 2-8.2 5252.70 5208.85 2261.05 0.08 14.5 14.5 Good Test 1.3 2-8.3 5252.70 5208.85 2260.90 0.10 17.0 17.0 Good Test 1.4 2-8.4 5252.70 5208.85 2260.83 0.09 18.7 18.7 Good Test 1.5 2-8.5 5252.70 5208.85 2258.40 0.18 3.61 3.62 Good Test 2.2 2-9.2 5271.96 5228.11 2286.16 2.40 7.12 7.12 Good Test 3.1 2-10.1 5382.54 5338.68 Tight Test 4.1 2-11.1 5372.29 5328.43 Tight Test 5.2 2-12.2 5371.50 5327.65 2308.22 2.57 0.530 0.537 Good Test 5.3 2-12.3 5371.50 5327.65 2302.82 8.28 0.588 0.593 Good Test 5.4 2-12.4 5371.50 5327.65 2307.88 3.22 0.589 0.652 Good Test 6.1 2-13.1 5350.00 5306.14 Tight Test 7.2 2-14.2 5284.52 5240.67 2289.93 1.82 3.37 3.37 Good Test 7.3 2-14.3 5284.52 5240.67 2291.40 0.90 3.36 3.36 Good Test 7.4 2-14.4 5284.52 5240.67 2291.52 1.01 3.60 3.60 Good Test 8.2 2-15.2 5304.03 5260.17 2301.56 3.66 0.545 0.578 Good Test 8.3 2-15.3 5304.03 5260.17 2299.52 5.28 0.511 0.512 Good Test 8.4 2-15.4 5304.03 5260.17 2298.54 4.85 0.524 0.526 Good Test 8.5 2-15.5 5304.03 5260.17 2297.43 4.32 0.460 0.461 Good Test 9.2 2-16.2 5330.01 5286.16 2307.11 3.09 1.07 1.07 Good Test 9.3 2-16.3 5330.01 5286.16 2306.38 2.95 1.06 1.06 Good Test 9.4 2-16.4 5330.01 5286.16 2306.81 1.10 0.787 0.787 Good Test 10.2 2-20.1 5217.03 5173.17 2269.40 0.14 11.8 11.8 Good Test 10.3 2-20.2 5217.03 5173.17 2269.34 0.18 11.7 11.7 Good Test 10.4 2-20.3 5217.03 5173.17 2269.26 0.19 13.9 13.9 Good Test 10.5 2-20.4 5217.03 5173.17 2263.82 0.39 5.31 7.68 Good Test 10.6 2-20.5 5217.03 5173.17 2263.70 0.54 5.54 7.50 Good Test 10.7 2-20.6 5217.03 5173.17 2263.85 0.17 4.28 5.44 Good Test 11.2 2-24.1 4133.00 4089.15 1806.51 2.08 0.696 0.894 Good Test 11.3 2-24.2 4133.00 4089.15 1805.33 1.87 0.725 0.929 Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 12 Test Identification PTA Pressure PTA Mobilities Remarks Test No. File No. MD (ft) TVD (ft) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 11.4 2-24.3 4133.00 4089.15 1806.32 1.07 0.559 0.962 Good Test 12.1 2-25.1 4142.10 4098.25 Lost Seal 12.2 2-25.2 4142.10 4098.25 Lost Seal 13.2 2-26.2 4141.01 4097.16 1810.30 1.69 1.33 1.70 Good Test 13.3 2-26.3 4141.01 4097.16 1809.99 1.10 1.17 1.28 Good Test 14.2 2-27.2 4132.02 4088.17 1805.60 0.87 2.45 2.47 Good Test 15.1 2-28.1 4234.90 4191.04 Lost Seal 16.1 2-29.1 4234.90 4191.04 No Seal 17.2 2-30.2 4234.84 4190.98 1845.08 0.14 0.948 0.948 Good Test 17.3 2-30.3 4234.84 4190.98 1844.70 0.45 0.914 0.914 Good Test 18.2 2-34.2 5297.55 5253.70 2304.62 3.92 0.373 0.406 Good Test 18.3 2-34.3 5297.55 5253.70 2304.24 2.75 0.361 0.479 Good Test 19.1 2-35.1 5321.20 5277.34 Tight Test 20.2 2-36.3 5362.47 5318.61 2298.95 0.43 1.21 1.21 Good Test 20.3 2-36.4 5362.47 5318.61 2298.95 0.31 1.84 1.84 Good Test 20.4 2-36.5 5362.47 5318.61 2298.94 0.45 2.13 2.13 Good Test 21.2 2-37.2 5285.37 5241.51 2284.73 1.22 5.21 5.21 Good Test 21.3 2-37.3 5285.37 5241.51 2282.38 0.80 5.90 5.90 Good Test 21.4 2-37.6 5285.37 5241.51 2282.57 0.18 6.01 6.01 Good Test 21.5 2-37.7 5285.37 5241.51 2282.55 0.44 6.95 6.95 Good Test 22.2 2-39.2 4133.10 4089.24 1804.37 0.42 5.43 5.43 Good Test 22.3 2-39.3 4133.10 4089.24 1804.64 0.35 5.48 5.48 Good Test 23.2 2-40.2 4234.78 4190.92 1845.29 1.71 2.97 2.99 Good Test 23.3 2-40.3 4234.78 4190.92 1844.90 1.67 3.00 3.02 Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 13 Sample Summary Sample Identification Step MCS# Tank Type TVP (cc) FT (degF) Den (g/cc)* Res (ohmm) Cap (pF) SV(cc) Remarks Test# File# TVD (ft) MD (ft) 1.1 2-8.1 5208.85 5252.70 Close Chamber 1014 N2 46482.58 128.60 0.79 8.18 50.61 1185.35 Oil 1.2 2-8.2 5208.85 5252.70 Close Chamber 1073 N2 52814.19 129.30 0.79 7.37 11.77 801.98 Oil 1.3 2-8.3 5208.85 5252.70 Close Chamber 1336 N2 53568.86 129.30 0.79 9.03 31.49 652.03 Oil 7.1 2-14.1 5240.67 5284.52 Close Chamber 1681 N2 97422.09 134.60 0.99 0.32 40.45 812.88 Water 7.2 2-14.2 5240.67 5284.52 Close Chamber 1728 N2 99639.61 134.60 0.99 0.38 36.70 669.61 Water 10.1 2-20.1 5173.17 5217.03 Close Chamber 1742 N2 30554.56 131.40 0.78 6.83 9.36 591.59 Oil 10.2 2-20.2 5173.17 5217.03 Close Chamber 1759 N2 37143.84 131.40 0.78 5.35 7.67 681.75 Oil *average density during sampling. Please see fluid ID plot for details Legend Step: Sample Step MCS#: Bottle MCS Serial Number TVP: Total Volume Pumped APR: Average Pump Rate FT: Fluid Temperature FM: Flowing Mobility Den: Density @ Sampling Res: Resistivity @ Sampling Cap: Capacitance @ Sampling SV: Sample Volume Gradient Plots and Pressure Gradients Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 15 Gradient Plot in Coyote Formation Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 16 Gradient Plot in Moraine Formation Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 17 Composite Plot in Coyote Formation Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 18 Composite Plot in Moraine Formation Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 19 Plots Test No. 1.1; MD: 5252.70 ft; TVD: 5208.85 ft RDT Test File # 2-8.1 Date: 27-Feb-15 18:20:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5252.70 5208.85 2220.46 2261.05 2261.05 14.5 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.76 0.95 2.04 0.15 4.84e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.08 0.08 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 20 Test No. 1.2; MD: 5252.70 ft; TVD: 5208.85 ft RDT Test File # 2-8.2 Date: 27-Feb-15 18:20:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5252.70 5208.85 2220.46 2261.05 2261.05 14.5 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.76 0.95 2.04 0.15 4.84e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.08 0.08 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 21 Test No. 1.3; MD: 5252.70 ft; TVD: 5208.85 ft RDT Test File # 2-8.3 Date: 27-Feb-15 18:20:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5252.70 5208.85 2191.25 2260.90 2260.90 17.0 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.15 1.91 2.04 0.15 7.63e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.10 0.04 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 22 Test No. 1.4; MD: 5252.70 ft; TVD: 5208.85 ft RDT Test File # 2-8.4 Date: 27-Feb-15 18:20:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5252.70 5208.85 2134.86 2260.83 2260.83 18.7 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 30.47 3.81 2.04 0.15 1.07e-004 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.09 0.00 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 23 Test No. 1.5 (After Pumping); MD: 5252.70 ft; TVD: 5208.85 ft RDT Test File # 2-8.5 Date: 27-Feb-15 18:20:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5252.70 5208.85 2090.42 2258.40 2258.40 3.61 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 29.74 0.98 2.04 0.15 6.85e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.18 0.02 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 24 Bubble Point; MD: 5252.70 ft; TVD: 5208.85 ft Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 25 Fluid ID Plot; MD: 5252.70 ft; TVD: 5208.85 ft Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 26 Three oil samples were taken at 5252.7 FT. First sample was taken as a safety sample after pumping 45 liters. Both inlet and outlet shows erratic density during sampl ing. Second and third bottles show more stable density around 0.8 gram/cc. 5252.70 ft RDT Fluid ID Second Sample 5252.70 ft RDT Fluid ID Third Sample Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 27 Contamination Estimation; MD: 5252.70 ft; TVD: 5208.85 ft The contamination shows high error contamination due to variance of fluid density in water based mud during pumping. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 28 Mril-Prime Two Dimensional Fluid Characterization T1-T2 (2DFC-T1T2) Map Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 29 Processed MRIL plots at the sampling points were used prior to RDT job to give a better idea of the fluid typing and saturation. The petrophysical quantities are extracted from the T1T2 distribution. These quantities include gas volume, oil volume and water volume for oil based mud environment. 2D map of T1T2 distributions are the feasible region that are established to constrain the results of the inversion. The following table shows the comparison of different fluids saturation at 5252.0 ft using both MRIL processed results and optical results. The saturation values are in acceptable agreement for the sampling points. Depth MCS # Sample Order Density Composition ICS (in chamber) MRIL Saturation 5252.7 ft 1073 Second 0.79 g/cc Water 54% 56% Gas 2% 3% Oil 27% 41% Residual 18% 1336 Third 0.79 g/cc Water 27% 56% Gas 0% 3% Oil 9% 41% Residual 64% Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 30 Test No. 2.1; MD: 5271.96 ft; TVD: 5228.11 ft RDT Test File # 2-9.1 Date: 28-Feb-15 05:26:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5271.96 5228.11 2028.84 2286.16 2286.16 7.12 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 10.00 0.48 0.33 0.25 1.15e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.40 0.41 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 31 Test No. 2.2; MD: 5271.96 ft; TVD: 5228.11 ft RDT Test File # 2-9.2 Date: 28-Feb-15 05:26:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5271.96 5228.11 2028.84 2286.16 2286.16 7.12 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 10.00 0.48 0.33 0.25 1.15e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.40 0.41 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 32 Test No. 3.1; MD: 5382.54 ft; TVD: 5338.68 ft RDT Test File # 2-10.1 Date: 28-Feb-15 06:00:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5382.54 5338.68 1908.57 2329.93 2335.62 0.275 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.54 0.62 0.66 0.25 1.32e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 8.67 38.78 0.29 REMARKS Tight Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 33 Test No. 4.1; MD: 5372.29 ft; TVD: 5328.43 ft RDT Test File # 2-11.1 Date: 28-Feb-15 06:11:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5372.29 5328.43 1602.30 2264.76 2286.02 0.093 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.98 0.19 2.04 0.15 1.38e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 14.23 80.25 0.27 REMARKS Tight Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 34 Test No. 5.1; MD: 5371.50 ft; TVD: 5327.65 ft RDT Test File # 2-12.1 Date: 28-Feb-15 06:25:37 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5371.50 5327.65 2082.54 2308.22 2308.22 0.530 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 5.00 0.20 2.04 0.15 1.26e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.57 0.52 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 35 Test No. 5.2; MD: 5371.50 ft; TVD: 5327.65 ft RDT Test File # 2-12.2 Date: 28-Feb-15 06:25:37 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5371.50 5327.65 2082.54 2308.22 2308.22 0.530 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 5.00 0.20 2.04 0.15 1.26e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.57 0.52 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 36 Test No. 5.3; MD: 5371.50 ft; TVD: 5327.65 ft RDT Test File # 2-12.3 Date: 28-Feb-15 06:25:37 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5371.50 5327.65 1797.58 2302.82 2302.82 0.588 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 11.99 0.48 2.04 0.15 1.47e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 8.28 4.04 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 37 Test No. 5.4; MD: 5371.50 ft; TVD: 5327.65 ft RDT Test File # 2-12.4 Date: 28-Feb-15 06:25:37 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5371.50 5327.65 1861.41 2307.88 2307.88 0.589 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.94 0.47 2.04 0.15 1.58e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.22 1.09 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 38 Test No. 6.1; MD: 5350.00 ft; TVD: 5306.14 ft RDT Test File # 2-13.1 Date: 28-Feb-15 06:57:10 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5350.00 5306.14 1791.63 2281.24 2288.29 0.067 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.77 0.19 2.04 0.15 7.65e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 11.45 49.05 0.00 REMARKS Tight Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 39 Test No. 7.1; MD: 5284.52 ft; TVD: 5240.67 ft RDT Test File # 2-14.1 Date: 28-Feb-15 07:14:18 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5284.52 5240.67 2202.36 2289.93 2289.93 3.37 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.91 0.48 2.04 0.15 1.71e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.82 3.13 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 40 Test No. 7.2; MD: 5284.52 ft; TVD: 5240.67 ft RDT Test File # 2-14.2 Date: 28-Feb-15 07:14:18 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5284.52 5240.67 2202.36 2289.93 2289.93 3.37 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.91 0.48 2.04 0.15 1.71e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.82 3.13 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 41 Test No. 7.3; MD: 5284.52 ft; TVD: 5240.67 ft RDT Test File # 2-14.3 Date: 28-Feb-15 07:14:18 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5284.52 5240.67 2202.54 2291.40 2291.40 3.36 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.90 0.48 2.04 0.15 2.97e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.90 0.27 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 42 Test No. 7.4; MD: 5284.52 ft; TVD: 5240.67 ft RDT Test File # 2-14.4 Date: 28-Feb-15 07:14:18 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5284.52 5240.67 2126.48 2291.52 2291.52 3.60 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.48 0.96 2.04 0.15 2.78e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.01 0.24 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 43 Fluid ID Plot: 5284.52 ft; TVD: 5240.67 ft Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 44 Two water samples were taken at 5284.52 FT. The samples were taken after 97 liters pumped and show density 0.99 gram/cc for both sampling. Fluid ID Plot at 5284.5 ft , Zoomed in Plot (Samples) Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 45 Mril-Prime Two Dimensional Fluid Characterization T1-T2 (2DFC-T1T2) Map Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 46 The following table shows the comparison of different fluids saturation at 5284.52 ft using both MRIL processed results and optical results. The saturation values are in acceptable agreement for the sampling points. Depth MCS # Sample Order Density Composition ICS (in chamber) MRIL Saturation 5284.52 ft 1681 First 0.99 gr/cc Water 94% 82% Gas 1% 0% Oil 2% 18% Residual 3% 1728 Second 0.99 g/cc Water 99% 82% Gas 0% 0% Oil 0% 18% Residual 1% Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 47 Test No. 8.1; MD: 5304.03 ft; TVD: 5260.17 ft RDT Test File # 2-15.1 Date: 28-Feb-15 16:24:50 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5304.03 5260.17 1781.37 2301.62 2301.62 0.545 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.85 0.49 2.04 0.15 1.46e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.70 1.07 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 48 Test No. 8.2; MD: 5304.03 ft; TVD: 5260.17 ft RDT Test File # 2-15.2 Date: 28-Feb-15 16:24:50 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5304.03 5260.17 1781.37 2301.56 2301.56 0.545 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.85 0.49 2.04 0.15 1.46e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.66 1.07 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 49 Test No. 8.3; MD: 5304.03 ft; TVD: 5260.17 ft RDT Test File # 2-15.3 Date: 28-Feb-15 16:24:50 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5304.03 5260.17 1702.49 2299.52 2299.52 0.511 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 29.70 0.49 2.04 0.15 1.13e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 5.28 0.47 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 50 Test No. 8.4; MD: 5304.03 ft; TVD: 5260.17 ft RDT Test File # 2-15.4 Date: 28-Feb-15 16:24:50 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5304.03 5260.17 1717.28 2298.54 2298.54 0.524 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 29.92 0.49 2.04 0.15 1.27e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 4.85 0.37 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 51 Test No. 8.5; MD: 5304.03 ft; TVD: 5260.17 ft RDT Test File # 2-15.5 Date: 28-Feb-15 16:24:50 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5304.03 5260.17 2028.68 2297.43 2297.43 0.460 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 10.07 0.20 2.04 0.15 1.30e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 4.32 0.83 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 52 Test No. 9.1; MD: 5330.01 ft; TVD: 5286.16 ft RDT Test File # 2-16.1 Date: 28-Feb-15 17:17:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5330.01 5286.16 2021.87 2307.11 2307.11 1.07 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 29.91 0.49 2.04 0.15 1.16e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.09 0.39 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 53 Test No. 9.2; MD: 5330.01 ft; TVD: 5286.16 ft RDT Test File # 2-16.2 Date: 28-Feb-15 17:17:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5330.01 5286.16 2021.87 2307.11 2307.11 1.07 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 29.91 0.49 2.04 0.15 1.16e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.09 0.39 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 54 Test No. 9.3; MD: 5330.01 ft; TVD: 5286.16 ft RDT Test File # 2-16.3 Date: 28-Feb-15 17:17:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5330.01 5286.16 2017.64 2306.38 2306.38 1.06 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 30.06 0.49 2.04 0.15 1.34e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.95 0.39 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 55 Test No. 9.4; MD: 5330.01 ft; TVD: 5286.16 ft RDT Test File # 2-16.4 Date: 28-Feb-15 17:17:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5330.01 5286.16 2227.53 2306.81 2306.81 0.787 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.12 0.10 2.04 0.15 5.05e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.10 0.44 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 56 Test No. 10.1; MD: 5217.03 ft; TVD: 5173.17 ft RDT Test File # 2-20.7 Date: 28-Feb-15 19:01:54 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5217.03 5173.17 2244.02 2269.39 2269.39 11.8 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.77 0.48 2.04 0.15 4.94e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.13 0.07 -0.20 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 57 Test No. 10.2; MD: 5217.03 ft; TVD: 5173.17 ft RDT Test File # 2-20.1 Date: 28-Feb-15 19:01:54 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5217.03 5173.17 2244.02 2269.40 2269.40 11.8 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.77 0.48 2.04 0.15 4.94e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.14 0.07 -0.20 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 58 Test No. 10.3; MD: 5217.03 ft; TVD: 5173.17 ft RDT Test File # 2-20.2 Date: 28-Feb-15 19:01:54 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5217.03 5173.17 2244.38 2269.34 2269.34 11.7 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.81 0.47 2.04 0.15 5.22e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.18 0.12 -0.26 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 59 Test No. 10.4; MD: 5217.03 ft; TVD: 5173.17 ft RDT Test File # 2-20.3 Date: 28-Feb-15 19:01:54 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5217.03 5173.17 2226.09 2269.26 2269.26 13.9 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.61 0.97 2.04 0.15 7.72e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.19 0.08 -0.15 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 60 Test No. 10.5 (After Pumping); MD: 5217.03 ft; TVD: 5173.17 ft RDT Test File # 2-20.4 Date: 28-Feb-15 19:01:54 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5217.03 5173.17 2224.80 2263.82 2263.82 5.31 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.82 0.48 2.04 0.15 1.23e-004 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.39 0.06 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 61 Test No. 10.6 (After Pumping); MD: 5217.03 ft; TVD: 5173.17 ft RDT Test File # 2-20.5 Date: 28-Feb-15 19:01:54 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5217.03 5173.17 2223.86 2263.70 2263.70 5.54 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.78 0.48 2.04 0.15 4.69e-004 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.54 0.08 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 62 Test No. 10.7 (After Pumping); MD: 5217.03 ft; TVD: 5173.17 ft RDT Test File # 2-20.6 Date: 28-Feb-15 19:01:54 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5217.03 5173.17 2254.96 2263.85 2263.85 4.28 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.94 0.08 2.04 0.15 1.79e-004 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.17 0.11 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 63 Bubble Point; MD: 5217.03 ft; TVD: 5173.17 ft Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 64 Fluid ID Plot; MD: 5217.03 ft; TVD: 5173.17 ft Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 65 Two oil samples were taken at 5217.03 FT. The samples were taken after 30 liters pump and show density 0.78 gram/cc for both sampling. The inlet density not shows valid density due to lost temperature stabilization. Fluid ID Plot at 5217.03 ft , First Sample Fluid ID Plot at 5217.03 ft , Second Sample Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 66 Contamination Estimation; MD: 5217.03 ft; TVD: 5173.17 ft The contamination shows high error contamination because of formation water that might observe during pumping. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 67 Mril-Prime Two Dimensional Fluid Characterization T1-T2 (2DFC-T1T2) Map Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 68 The following table shows the comparison of different fluids saturation at 5217.03 ft using both MRIL processed results and optical results. The saturation values are in acceptable agreement for the sampling points. Depth MCS # Sample Order Density Composition ICS (in chamber) MRIL Saturation 5217.03 ft 1742 First 0.78 g/cc Water 1% 75% Gas 1% 0% Oil 73% 26% Residual 25% 1759 Second 0.78 g/cc Water 81% 75% Gas 4% 0% Oil 5% 26% Residual 10% Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 69 Test No. 11.4; MD: 4133.00 ft; TVD: 4089.15 ft RDT Test File # 2-24.4 Date: 01-Mar-15 08:50:23 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4133.00 4089.15 1670.16 1806.51 1806.51 0.696 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.96 0.20 2.04 0.15 5.66e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.08 0.02 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 70 Test No. 11.2; MD: 4133.00 ft; TVD: 4089.15 ft RDT Test File # 2-24.1 Date: 01-Mar-15 08:50:23 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4133.00 4089.15 1670.16 1806.51 1806.51 0.696 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.96 0.20 2.04 0.15 5.66e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.08 0.02 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 71 Test No. 11.3; MD: 4133.00 ft; TVD: 4089.15 ft RDT Test File # 2-24.2 Date: 01-Mar-15 08:50:23 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4133.00 4089.15 1674.14 1805.33 1805.33 0.725 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.96 0.20 2.04 0.15 5.94e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.87 0.00 -0.22 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 72 Test No. 11.4; MD: 4133.00 ft; TVD: 4089.15 ft RDT Test File # 2-24.3 Date: 01-Mar-15 08:50:23 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4133.00 4089.15 1745.35 1806.32 1806.32 0.559 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.02 0.09 2.04 0.15 4.58e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.07 0.05 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 73 Test No. 12.1; MD: 4142.10 ft; TVD: 4098.25 ft RDT Test File # 2-25.1 Date: 01-Mar-15 10:01:21 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4142.10 4098.25 1607.81 1818.07 1818.07 1.07 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.88 0.49 2.04 0.15 1.57e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 5.01 1.06 0.00 REMARKS Lost Seal Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 74 Test No. 12.2; MD: 4142.10 ft; TVD: 4098.25 ft RDT Test File # 2-25.2 Date: 01-Mar-15 10:01:21 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4142.10 4098.25 1607.81 1818.07 1818.07 1.07 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.88 0.49 2.04 0.15 1.57e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 5.01 1.06 0.00 REMARKS Lost Seal Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 75 Test No. 13.1; MD: 4141.01 ft; TVD: 4097.16 ft RDT Test File # 2-26.1 Date: 01-Mar-15 10:52:17 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4141.01 4097.16 1642.35 1810.30 1810.30 1.33 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.86 0.46 2.04 0.15 3.16e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.69 0.13 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 76 Test No. 13.2; MD: 4141.01 ft; TVD: 4097.16 ft RDT Test File # 2-26.2 Date: 01-Mar-15 10:52:17 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4141.01 4097.16 1642.35 1810.30 1810.30 1.33 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.86 0.46 2.04 0.15 3.16e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.69 0.13 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 77 Test No. 13.3; MD: 4141.01 ft; TVD: 4097.16 ft RDT Test File # 2-26.3 Date: 01-Mar-15 10:52:17 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4141.01 4097.16 1715.76 1809.99 1809.99 1.17 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.96 0.19 2.04 0.15 3.04e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.10 0.16 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 78 Test No. 14.1; MD: 4132.02 ft; TVD: 4088.17 ft RDT Test File # 2-27.1 Date: 01-Mar-15 11:26:53 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4132.02 4088.17 1744.67 1805.60 1805.60 2.45 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.74 0.24 2.04 0.15 2.80e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.87 0.09 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 79 Test No. 14.2; MD: 4132.02 ft; TVD: 4088.17 ft RDT Test File # 2-27.2 Date: 01-Mar-15 11:26:53 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4132.02 4088.17 1744.67 1805.60 1805.60 2.45 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.74 0.24 2.04 0.15 2.80e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.87 0.09 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 80 Test No. 15.1; MD: 4234.90 ft; TVD: 4191.04 ft RDT Test File # 2-28.1 Date: 01-Mar-15 12:17:45 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.90 4191.04 1812.69 2007.12 2015.63 1.09 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.68 0.48 2.04 0.15 1.15e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 9.80 117.28 0.00 REMARKS Lost Seal Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 81 Test No. 16.1; MD: 4234.90 ft; TVD: 4191.04 ft RDT Test File # 2-29.1 Date: 01-Mar-15 12:33:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.90 4191.04 2132.73 2144.49 2145.84 27.3 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 18.03 0.78 2.04 0.15 7.25e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.50 15.47 0.00 REMARKS No Seal Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 82 Test No. 17.1; MD: 4234.84 ft; TVD: 4190.98 ft RDT Test File # 2-30.1 Date: 01-Mar-15 12:45:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.84 4190.98 1717.87 1845.08 1845.08 0.948 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 5.02 0.20 2.04 0.15 8.83e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.14 0.01 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 83 Test No. 17.2; MD: 4234.84 ft; TVD: 4190.98 ft RDT Test File # 2-30.2 Date: 01-Mar-15 12:45:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.84 4190.98 1717.87 1845.08 1845.08 0.948 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 5.02 0.20 2.04 0.15 8.83e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.14 0.01 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 84 Test No. 17.3; MD: 4234.84 ft; TVD: 4190.98 ft RDT Test File # 2-30.3 Date: 01-Mar-15 12:45:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.84 4190.98 1712.54 1844.70 1844.70 0.914 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.98 0.20 2.04 0.15 9.08e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.45 0.03 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 85 Test No. 18.1; MD: 5297.55 ft; TVD: 5253.70 ft RDT Test File # 2-34.1 Date: 01-Mar-15 14:01:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5297.55 5253.70 2012.31 2304.62 2304.62 0.373 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.90 0.19 2.04 0.15 3.32e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.92 0.41 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 86 Test No. 18.2; MD: 5297.55 ft; TVD: 5253.70 ft RDT Test File # 2-34.2 Date: 01-Mar-15 14:01:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5297.55 5253.70 2012.31 2304.62 2304.62 0.373 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.90 0.19 2.04 0.15 3.32e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.92 0.41 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 87 Test No. 18.3; MD: 5297.55 ft; TVD: 5253.70 ft RDT Test File # 2-34.3 Date: 01-Mar-15 14:01:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5297.55 5253.70 2056.75 2304.24 2304.24 0.361 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 1.92 0.19 2.04 0.15 6.56e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.75 0.46 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 88 Test No. 19.1; MD: 5321.20 ft; TVD: 5277.34 ft RDT Test File # 2-35.1 Date: 01-Mar-15 16:06:45 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5321.20 5277.34 1418.56 2176.25 2207.09 0.014 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 0.97 0.17 2.04 0.15 3.82e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 20.22 84.29 0.00 REMARKS Tight Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 89 Test No. 20.1; MD: 5362.47 ft; TVD: 5318.61 ft RDT Test File # 2-36.6 Date: 01-Mar-15 16:29:17 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5362.47 5318.61 2000.66 2298.95 2298.95 1.21 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.42 0.09 0.33 0.25 2.53e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.43 0.17 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 90 Test No. 20.2; MD: 5362.47 ft; TVD: 5318.61 ft RDT Test File # 2-36.3 Date: 01-Mar-15 16:29:17 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5362.47 5318.61 2000.66 2298.95 2298.95 1.21 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.42 0.09 0.33 0.25 2.53e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.43 0.17 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 91 Test No. 20.3; MD: 5362.47 ft; TVD: 5318.61 ft RDT Test File # 2-36.4 Date: 01-Mar-15 16:29:17 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5362.47 5318.61 1924.21 2298.95 2298.95 1.84 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.42 0.18 0.33 0.25 5.37e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.31 0.07 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 92 Test No. 20.4; MD: 5362.47 ft; TVD: 5318.61 ft RDT Test File # 2-36.5 Date: 01-Mar-15 16:29:17 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5362.47 5318.61 1960.28 2298.94 2298.94 2.13 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 2.49 0.19 0.33 0.25 6.30e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.45 0.08 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 93 Test No. 21.1; MD: 5285.37 ft; TVD: 5241.51 ft RDT Test File # 2-37.8 Date: 01-Mar-15 17:30:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5285.37 5241.51 1948.15 2284.73 2284.73 5.21 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.57 0.91 0.66 0.25 1.42e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.22 0.50 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 94 Test No. 21.2; MD: 5285.37 ft; TVD: 5241.51 ft RDT Test File # 2-37.2 Date: 01-Mar-15 17:30:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5285.37 5241.51 1948.15 2284.73 2284.73 5.21 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 9.57 0.91 0.66 0.25 1.42e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.22 0.50 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 95 Test No. 21.3; MD: 5285.37 ft; TVD: 5241.51 ft RDT Test File # 2-37.3 Date: 01-Mar-15 17:30:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5285.37 5241.51 2156.48 2282.38 2282.38 5.90 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 5.02 0.19 0.33 0.25 1.09e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.80 -0.11 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 96 Test No. 21.4; MD: 5285.37 ft; TVD: 5241.51 ft RDT Test File # 2-37.7 Date: 01-Mar-15 17:30:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5285.37 5241.51 2174.86 2282.55 2282.55 6.95 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.96 0.19 0.33 0.25 8.98e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.44 0.27 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 97 Test No. 21.5; MD: 5285.37 ft; TVD: 5241.51 ft RDT Test File # 2-37.6 Date: 01-Mar-15 17:30:46 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 5285.37 5241.51 2158.51 2282.57 2282.57 6.01 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 5.00 0.19 0.33 0.25 8.28e-006 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.18 0.05 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 98 Test No. 22.1; MD: 4133.10 ft; TVD: 4089.24 ft RDT Test File # 2-39.1 Date: 01-Mar-15 18:27:38 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4133.10 4089.24 1665.92 1804.37 1804.37 5.43 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.93 0.20 0.33 0.25 1.44e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.42 0.12 -0.16 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 99 Test No. 22.2; MD: 4133.10 ft; TVD: 4089.24 ft RDT Test File # 2-39.2 Date: 01-Mar-15 18:27:38 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4133.10 4089.24 1665.92 1804.37 1804.37 5.43 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 4.93 0.20 0.33 0.25 1.44e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.42 0.12 -0.16 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 100 Test No. 22.3; MD: 4133.10 ft; TVD: 4089.24 ft RDT Test File # 2-39.3 Date: 01-Mar-15 18:27:38 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4133.10 4089.24 1665.99 1804.64 1804.64 5.48 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 5.04 0.20 0.33 0.25 1.28e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.35 0.05 -0.13 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 101 Test No. 23.1; MD: 4234.78 ft; TVD: 4190.92 ft RDT Test File # 2-40.1 Date: 01-Mar-15 19:10:36 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.78 4190.92 1645.59 1845.29 1845.29 2.97 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.60 0.97 2.04 0.15 2.86e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.71 0.27 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 102 Test No. 23.2; MD: 4234.78 ft; TVD: 4190.92 ft RDT Test File # 2-40.2 Date: 01-Mar-15 19:10:36 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.78 4190.92 1645.59 1845.29 1845.29 2.97 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.60 0.97 2.04 0.15 2.86e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.71 0.27 0.00 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 103 Test No. 23.3; MD: 4234.78 ft; TVD: 4190.92 ft RDT Test File # 2-40.3 Date: 01-Mar-15 19:10:36 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia) Pstop (psia) Pexact (psia) Mexact(md/cp) 4234.78 4190.92 1648.61 1844.90 1844.90 3.00 CONSTANTS - SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow-line Storage (cc) 19.69 0.96 2.04 0.15 2.71e-005 180.00 TEST CONDITIONS & STATUS +/- stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.67 0.22 -0.20 REMARKS Good Test Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 104 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. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 105 Drawdown Buildup Analysis During the pretest a small amount of fluid is withdrawn from the formation through the snorkel and into the tool at a known rate. This causes the pressure pulse called a pretest drawdown. The combination of low rate and snorkel D determines an effective range of operation. The maximum drawdown pressure pulse can be determined from the well-known spherical flow equation where Pdd is the final drawdown pressure differential at time t=. fp pdd dd kr q = P 2696,14 Where: Pdd ......................................................................... drawdown differential pressure (psi) qo ......................................................................................... drawdown flow rate (cc/sec) ks ............................................................................ formation spherical permeability(md) .................................................................................................................. viscosity (cp) rp ............................................................................................................probe radius(cm) p ................................................................................. probe flow coefficient (1.37to0.95) With a 0.10cc/sec to 1.5cc/sec drawdown flow rate and a 1.0cm probe employed, it is possible to test formations ranging from 1000 to 0.5 md with pressure differentials ranging from 2 to 5000 psi. Exact Mobility Analysis By analyzing the drawdown curve and the build-up curve it is possible to calculate the mobility of the formation. The mobility is defined as the permeability divided by the viscosity (md/cp). Therefore if the viscosity of the fluid being drawn is known, it is also possible to determine the formation permeability. The fluid being drawn into the pretest is normally assumed to be the mud filtrate so if the mud type is known it is possible to estimate the filtrate viscosity. The two methods of determining the mobility are shown by the two equations below. First is the drawdown mobility Mdd that uses the drawdown pressure differential (i.e.,Pdd=Pstop-Pdd_end) and is the most common method used in the industry. It is normally referred to as the steady-state spherical method. The second is the exact spherical mobility Mexact that typically uses the buildup curve. A simplified form of the exact method is shown in Figure-1 which is an exponential with a magnitude of (pressure, psi) and a time constant of (sec). Both the drawdown and buildup curves can be analyzed but normally the buildup is used. The curve fit parameters alpha and beta are used to determine the mobility. Generally these Mdd and Mexact are very similar except in low mobility zones where the mobility is < 1 md/cp. In this case the Exact method yields the most accurate estimate of Mobility. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 106 Mdd= p p dd o rP q 2 696,14 Drawdown spherical mobility (md/cp) Mexact= pt p po er q 12 696,14 Exact spherical mobility (md/cp) Where: tp .............................................................. draw down production time(tdd_end-tdd_start ,sec) .................................................................................. Exact curve fit time constant (sec) ............................................................................ Exact curve fit build up constant (psi) Pr e s s u r e ( p s i ) Time (sec)tstop Q tdd_end tdd TPdd_end t = T –tdd_end tdd_start t fbu eP(t)P * Pdd_start Pdd=Pstop-Pdd_end Pstop Phyds Fig–1 Buildup function where formation pressure (Pf*), Alpha ( ) and beta () are determined from the Exact curve fit and Pf* is normally reported a PExaxt. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 107 Test Quality Parameters There are two different measurements of test quality. The first is called the sigma which is a measure of how closely the data conforms to the Exact model and is reported in ± pressure units (normally psi). The sigma is determined by calculating the standard deviation of the data from the theoretical curve as follows. )1( )()(p)( 2 n iPi=P bu bu .......... standard deviation ± pressure units (normally psi) Where: Pbu ......................................................... buildup pressure from Exact curve fit (see Fig. 1) p(i) ........................................................................................ measured buildup pressures i .......................................................................................................... index of data point n ............................................................................... total number of pressure points used The second method of measuring the test quality is the pressure and temperature stability. The “Pressure Stability” and “Temperature Stability are determined using a linear regression over the time period specified (i.e., default of 30 sec) and reported for each selected stop pressure. The stability can be either positive or negative. The stability period can be modified if desired in RTS. The source data for this derivative is the pressure gauge selected by the engineer for formation pressure which is normally the Quartz gauge closest to the probe. There are some exceptions to the stability period during buildups which are outlined below. 1. Start of buildup continues stability calculation until the buildup time reaches the stability period (i.e., 30 default). 2. Reset stability period to 1/3 of the buildup time (10 seconds default). 3. As the buildup progresses increase the stability period using 1/3 of the buildup time until the specified stability time is reached (30 sec default). Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 108 Automatic Test Comments Automatic test comments are generated based on the sigma quality parameter and the logic below. Test are classified by types and are normally Type A, B, C, and D. Any test that is not Type A, B, C or D is type F. The logic below determines the test type automatically but as explained below the RTS analysis can always override these comments and classify the tests as he sees fit. If Abs(Pstop - Phyd2) < 50 psi: “Potential Mud set” elseif Pstop < 1000 psi and alpha > 30 sec: “Dry/Tight test” elseif Pstop < 750 psi, “Dry/Tight test” elseif sigma <= 0.1: “Excellent Buildup Stability” (Type A) elseif sigma <= 1.0: “Good Buildup Stability” (Type B) elseif sigma <= 10.0: “Fair Buildup Stability” (Type C) elseif sigma > 10.00 and beta > 500 and alpha > 30: “Low Perm, still building” else: “Unstable Buildup (Type D)” The RTS analysts can override these comments based on his discretion, but if the key words Excellent, Good, Fair or Unstable are used the test comments the type associated with these key words used to apply the test type. The color coding to the test types are as follows. Type A Green Type B Orange Type C Pink Type D Red Type F Black Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 109 Dual Probe Anisotropy Analysis (Vertical Interference Testing) When one of the probes is isolated it may be possible to determine the horizontal permeability and anisotropy from the isolated (observation) probe that is spaced at a vertical distance from the source probe (lv) Mh_exact= v pt v vo v el Q 12 1696,14 Exact Horizontal Mobility (md/cp) 3 _ _ exacth exacts exacth v exact M M k k Exact anisotropy Anisotropy Dip-angle Corrections The calculation for anisotropy assumes the bedding plane is oriented relative to the borehole. The correction chart shown below can be used to find the anisotropy when the relative dip angle is known. Entering the chart from the left hand side with the real -time anisotropy and following one of the lines to the right determines the correction with increasing dip-angle. For example, using a real-time anisotropy of 10 and with a dip-angle of 700 the corrected anisotropy is slightly less than 0.1. This would be the case of a nearly horizontal well. Notice that as the dip-angle approaches 450 the lines converge. This means that measurements taken close to a 450 dip-angle are not very sensitive to anisotropy. 0.00001 0.0001 0.001 0.01 0.1 1 10 100 1000 0 10 20 30 40 50 60 70 80 90 Dip Angle (deg) An i s o t r o p y ( k v / k h ) 300 100 30 10 1 0.1 0.01 0.001 0.0001 0.00001 Real-Time Anisotropy Fig. 2 Anisotropy Dip-angle Correction Chart. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 110 Flow Rate Determination There are three methods of determining the drawdown (and pumping) flow rates which can be selected in the Job Parameters. In the newer tools the flow rate is measured and the “Automatic Method” is the preferred default. In older tools the flow rate or test volume can be specified but the values must be entered manually. With any of these three options it is rare that the volumes and rates exactly match that specified by the engineer since there is variability in the actual execution of a pretest and the rates and volume in RTS are determined from actual events and measured data. Automatic Flow Rate Option The automatic flow rate option determines rate from the measured rate curve(s) directly. For pretesting the averaged rage between the selected starting and ending times of the drawdown is used (i.e., Tstard_dd and Tend_dd). It is possible to select a Tend_dd that may not fall within the drawdown period and still estimate the mobility using the averaged rate for the drawdown period chosen. When this happens the simulated drawdown curve is turned off. For both pumping and pretesting the rate should be determined from the active rate curves. Since some tools like the RDT can have more than one pretest module or pump the total average from all the rate curves are used to for the “Automatic Rate” calculation. Then the volume for the drawdown is determined by using this averaged rate times the drawdown time (i.e., AvgRate/(Tend_dd-Tstart_dd)). However, the time used to average should not exceed 30 minutes which would apply to pumpouts or miniDST testing and it is desirable to determine the rate just prior to the buildup. In this case the averaged rate would be from Tdd-30 minutes to Tdd. Also, rates less than 0.02 cc/sec from Meas PT Rate are filtered out (set to 0 values) and rates less than 0.1 cc/sec for Pump Rates are set to 0 before averaging. Manual Flow Rate Option With this option selection in the Job Parameters the rate is fixed to the value entered. The volume of the pretest is determined by multiplying this rate time the drawdown time period selected (i.e., Tstard_dd and Tend_dd). Manual Volume Option With this option selection in the Job Parameters the volume is fixed to the value entered. The rate of the pretest is determined by dividing this volume by the drawdown time period selected (i.e., Tstard_dd and Tend_dd). Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 111 RTS Mobility Drawdown and Buildup Calculation Summary Table 1 PTA Spherical Flow Regime Calculations (Typical Physical Units) Mdd= p p dd o rP q 2 696,14 ...................................... Drawdown Mobility, Pressure/Time Plot (md/cp) Ms_exact= pt p po er Q 12 696,14 .......................... Exact Mobility, Pressure/Time Plot (md/cp) Mloglog= 5.1 1 5.2 5.1 4 696,14 dt dpt cV fo ..................................... FasTest Mobility, Log-Log Plot (md/cp) Mfast= 5.1 1 5.1 4 696,14 fast fo m cV .......................................... FasTest Mobility, FasTest Plot (md/cp) Msphere= 5.1 1 4 696,14 sphere fo m cq ................................................ Spherical Mobility, FastPlot (md/cp) Table 2 PTA Radial Flow Regime Calculations (Typical Physical Units) Mdd= p wf o dd dd o t rc q hPLambertWhP q 2 4 696,14 ..................... Drawdown Mobility (md/cp) Mloglog= dt dpth V eLog o 2)(4 696,14 ...............................................FasTest Mobility, Log-Log Plot (md) Mfast= fast o mh V eLog)(4 696,14 ....................................................... FasTest Mobility, FasTest Plot (md) Mradial= radial o mh q eLog)(4 696,14 .............................................................. Radial Mobility, FastPlot (md) Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 112 Table 3 PTA Variables & Constants Using Internal Program (Typical Physical Units) qo ............................................................................................................. drawdown flow rate (cc/sec) Vo ..................................................................................................................... drawdown volume(cc) Vs........................................................................................................................... storage volume(cc) ............................................................................................................................................. porosity ...................................................................................................................................... viscosity(cp) cf ............................................................................................................... fluid compressibility(1/psi) Pdd .............................................................................................. drawdown differential pressure(psi) p .................................................................................................... prove flow coefficient (1.37to0.95) rp .............................................................................................................................. probe radius(cm) rw .......................................................................................................................... wellbore radius(cm) h ................................................................................................................................ zone height (cm) T ......................................................................................................................... actual testtime(T,sec) t ................................................................................................. shut in or buildup time ((tdd_end-T,sec) t’ ..................................................................................... production or drawdown time (tdd_start-T,sec) tp ................................................................. production or drawdown time period (tdd_end-tdd_start,sec) dp/dt .............................................................................. Log-Log Plot buildup time derivative(psi/sec) mfast......................................................................................................................... FasTest Plot slope msphere ....................................................................................................................Spherical Plot slope mradial ........................................................................................................................ Radial Plot slope ........................................................................................................... Exact Plot time constant (sec) ............................................................................................................. Exact curve fit constant (psi) ...................................................................................................................... Eulier’sconstant (1.78) Log(e) .................................................................................... logbase10conversionconstant (0.43429) Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 113 Table 4 PTA Spherical Flow Regime Calculations (SI Units) Mdd= p p dd o rP q 2 1013 ......................................... Drawdown Mobility, Pressure/Time Plot (md/cp) Ms_exact= pt p po er Q 12 1013 ............................. Exact Mobility, Pressure/Time Plot (md/cp) Mloglog= 5.1 1 5.2 5.1 4 1013 dt dpt cV fo ......................................... FasTest Mobility, Log-Log Plot (md/cp) Mfast= 5.1 1 5.1 4 1013 fast fo m cV .............................................. FasTest Mobility ,FasTest Plot (md/cp) Msphere= 5.1 1 4 1013 sphere fo m cq .................................................... Spherical Mobility, FastPlot (md/cp) Table 5 PTA Radial Flow Regime Calculations (SI Units) Mdd= p wf o dd dd o t rc q hPLambertWhP q 2 4 1013 ........................ Draw down Mobility (md/cp) Mloglog= dt dpth Vo 24 1013 ........................................................FasTest Mobility, Log-Log Plot (md) Mfast= fast o mh V 4 1013 ................................................................ FasTest Mobility, FasTest Plot (md) Mradial= radial o mh q eLog)(4 1013 ......................................................... Radial Mobility, FastPlot (md) Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 114 Table 6 PTA Variables & Constants Using Internal Program SI Units qo ............................................................................................................. drawdown flow rate(m2/sec) Vo ..................................................................................................................... drawdown volume(m2) Vs........................................................................................................................... storage volume(m2) ............................................................................................................................................. porosity ............................................................................................................................ viscosity (cp, Pa-s) cf ................................................................................................................ fluid compressibility(1/Pa) Pdd .............................................................................................. drawdown differential pressure(Pa) p .................................................................................................... prove flow coefficient (1.37to0.95) rp ................................................................................................................................ probe radius(m) rw ........................................................................................................................... wellbore radius(m) h .................................................................................................................................. zone height (m) T ....................................................................................................................... actual test time (T,sec) t ................................................................................................... shutin or buildup time((tdd_end-T,sec) t’ ...................................................................................... production or drawdown time(tdd_start-T,sec) tp .................................................................. production or drawdown time period(tdd_end-tdd_start,sec) dp/dt .............................................................................. Log-Log Plot buildup time derivative(Pa/sec) mfast......................................................................................................................... FasTest Plot slope msphere ....................................................................................................................Spherical Plot slope mradial ........................................................................................................................ Radial Plot slope ........................................................................................................... Exact Plot time constant (sec) .............................................................................................................. Exact curve fit constant (Pa) ......................................................................................................................Eulier’s constant (1.78) Log(e) ................................................................................. logbase 10 conversion constant (0.43429) Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 115 RTS Theory References An Integrated Approach to Reservoir Connectivity and Fluid Contact Estimates by Applying Statistical Analysis Methods to Pressure Gradients, SPWLA 2007_HH paper presented at the 48th Annual Logging Symposium, June 3 - 6, 2007 , Austin, Texas. Formation Pressure Testing in the Dynamic Drilling Environment , SPE 112816 presentation was an SPE Distinguished Lecture during 2006-2007. Formation Testing and Sampling Using an Oval Pad in Al Hamd Field, Egypt, SPE 102366 presented at the SPE Annual Technical Conference and Exhibition, 24-27 September 2006, San Antonio, Texas, USA. Formation Tester While Drilling Experience in Caspian Development Projects, SPE 96719 paper presented at the SPE Annual Technical Conference and Exhibition, 9-12 October 2005, Dallas, Texas. Experience Using the First Commercial Pad and Probe Style Formation Tester While Drilling Service Has Led To Value Creation at the Valhall Flank De velopment, SPE 92712 paper presented at the SPE/IADC Drilling Conference, 23-25 February 2005, Amsterdam, Netherlands The Influence of Water-Base Mud Properties and Petrophysical Parameters on Mudcake Growth, Filtrate Invasion, and Formation Pressure, Petrophysics Volume 46, Number 1, January - February, 2005. Formation Tester Immiscible and Miscible Flow Modeling for Job Planning Applications, SPWLA 2005-L paper presented at the SPWLA 46th Annual Logging Symposium, 2005 Results of Laboratory Experiments to Simulate the Downhole Environment of Formation Testing While Drilling. SPWLA 2005R paper was presented at the SPWLA 45th Annual Logging Symposium held in Noordwijk, The Netherlands, June 6–9, 2004. Formation Testing In The Dynamic Drilling Environment, SPWLA 2005N paper was presented at the SPWLA 45th Annual Logging Symposium held in Noordwijk, The Netherlands, June 6–9, 2004. Formation Pressure Testing In the Dynamic Drilling Environment. SPE 87090 was presentated at the IADC/SPE Drilling Conference held in Dallas, Texas, U.S.A., 2–4 March 2004. Formation Testing While Drilling, a New Era in Formation Testing . SPE 84087 was presentated at the 2003 SPE Annual Technical Conference and Exhibition held in Denver, Colorado, USA, 5-8 October 2003. Formation Testing While Drilling, a New Technique for Acquiring Pressure Data, Paper presented at the SPE Nigerian Annual International Conference and Exhibition 4-8 August 2003. A New Inversion Technique Determines In-Situ Relative Permeabilities And Capillary Pressure Parameters From Pumpout Wireline Formation Tester Data, Spwla Forty-Fourth Annual Logging Symposium, Galveston, Texas, June 22-25, 2003. Performance Optimization of Perforated Completions Using a New 3D Finite -Element Wellbore Inflow Model and Artificial Neural Network, ExiPet Petroleum Congress, held in Veracruz, Mexico, February 16 - 18, 2003. Well Test Analysis Review, and Future Development, ExiPet Petroleum Congress, held in Veracruz, Mexico, February 16 - 18, 2003. Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 116 Sample Quality Prediction with Integrated Oil and Water-based Mud Invasion Modeling, SPE paper 77964 presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Melbourne, Australia, 8 –10 October 2002. Inversion of Multi-Phase Petrophysical Properties Using Pumpout Sampling Data Acquired with a Wireline Formation Tester, SPE paper 77345 presented at the SPE Annual Technical Conference and Exhibition held in San Antonio, Texas, 29 September –2 October 2002. Multiple Factors that Influence Wireline Formation Tester Pressur e Measurements and Fluid Contact Estimates, SPE paper 71566 presented at the 2001 SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, 30 September –3 October 2001. New Wireline Formation Testing Tool with Advanced Sampling Technol ogy, SPE paper 71317, SPE Reservoir Evaluation and Engineering Journal, April 2001. Testing of Gas Condensate Reservoirs — Sampling, Test Design and Analysis, SPE paper 68668 presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Jakarta, Indonesia, 17–19 April 2001. Advanced Dual Probe Formation Tester with Transient, Harmonic, and Pulsed Time -Delay Testing Methods Determines Permeability, Skin, and Anisotropy, SPE paper 64650 presented at the SPE International Oil and Gas Conference and Exhibition in China held in Beijing, China, 7–10 November 2000 Advanced Permeability and Anisotropy Measurements While Testing and Sampling in Real -time Using a Dual Probe Formation Tester, SPE paper 62919 presented at the 2000 SPE Annual Technical Conference and Exhibition held in Dallas, Texas, 1–4 October 2000. New Dual-Probe Wireline Formation Testing and Sampling Tool Enables Real -Time Permeability and Anisotropy Measurements, SPE paper 59701 presented at the SPE Permian Basin Oil and Gas Recovery Conference held in Midland, Texas, 21–23 March 2000. New Wireline Formation Testing Tool with Advanced Sampling Technology, SPE paper 56711 presented at the 1999 SPE Annual Technical Conference and Exhibition, Houston, Texas, 3–6 October 1999 Exact Spherical Flow Solution with Storage for Early-Time Test Interpretation, SPE Journal of Petroleum Technology, Nov. 1998 New Exact Spherical Flow Solution with Storage and Skin for Early-Time Interpretation, with Applications to Wireline Formation and Early-Evaluation Drillstem Testing, SPE Paper No. 49140, 1998 SPE Annual Technical Conference and Exhibition, New Orleans, La., Sept. 1998 New Exact Spherical Flow Solution for Early-Time Well Test Interpretation with Applications to Wireline Formation Testing and Early-Evaluation Drillstem Testing, SPE Paper No. 39915, SPE Rocky Mountain Regional Meeting/Low Permeability Reservoirs Symposium, Denver, Co., April 1998 New Exact Spherical Flow Solution for Early-Time Well Test Interpretation with Applications to Wireline Formation Testing and Early-Evaluation Drillstem Testing, SPE Paper No. 39768, SPE Permian Basin Oil and Gas Recovery Conference, Midland, Texas, March 1998 Pressure Test Validity Shown by Comparing Field Tests and Simulations, Part II: Formation Pressure Test Tools, Oil & Gas Journal, Jan. 12, 1998 Testing System Combines Advantages of Wireline and Drillstem Testers, Part I: Formation Pressure Test Tools, Oil & Gas Journal, Jan. 5, 1998 Formation and Reservoir Solution - Houston 10200 Bellaire Boulevard, Hosuton, TX 77072 Confidential Page 117 Low Permeability Interpretation Using a New Wireline Formation Tester ‘Tight Zone’ Pressure Transient Analysis, SPWLA 94 III Paper, presented at the 35th Annual Symposium in Tulsa, Oklahoma, June (1994). Real Time Pressure Transient Analysis Methods Applied to Wireline Formation Test Data , SPE paper 28449, presented at the 69th Annual Technical Conference of SPE in New Orleans, La., Sep. 25-28, 1994. Interpretation of Wireline Formation Tester Pressure Response, Mud Super -charging and Mud Invasion Effects, SPWLA 92 HH Paper, presented at the 33rd Annual Symposium in Oklah oma City, Oklahoma, June (1992). Improved Models for Interpreting the Pressure Response of Formation Testers, SPE paper 22754, presented at the 66th SPE Annual Technical Conference and Exhibition, Dallas, Texas, October 1991 Mril-Prime Two Dimensional Fluid Characterization T 1-T2 2DFC-T1T2 Customer: ConocoPhillips Well: CPAI_Moraine_1 Field: Moraine Rig: Nabors 9ES Country: USA Logged: 02/27/15 Analyst: Peyton Lowrey Report Date: 03/02/15 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 2 Table of Contents Table of Contents .................................................................................................................................... 2 Tabulated NMR Analysis Results .............................................................................................................. 3 Plots ........................................................................................................................................................ 4 Interval 4133.00 - 4133.00 ................................................................................................................... 4 Interval 4243.00 - 4243.00 ................................................................................................................... 5 Interval 5217.00 - 5217.00 ................................................................................................................... 6 Interval 5218 - 5230............................................................................................................................. 7 Interval 5250 - 5254............................................................................................................................. 8 Interval 5252.00 - 5252.00 ................................................................................................................... 9 Interval 5284.00 - 5284.00 ................................................................................................................. 10 Interval 5330.00 - 5330.00 ................................................................................................................. 11 Interval 5382 - 5382.5 ........................................................................................................................ 12 Disclaimer ............................................................................................................................................. 13 Appendix ............................................................................................................................................... 14 General Discussion of 2DFC- T1T2 ........................................................................................................... 14 1 Introduction ................................................................................................................................ 14 Theoretical Foundations ................................................................................................................ 14 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 3 Tabulated NMR Analysis Results Tabulated 2DFC T1T2 Results Stack Interval (feet) Volume (PU) Saturation (v/v) Top Bottom Water Oil Gas Total Water Oil Gas 4133.00 4133.00 19.155 3.332 0.011 22.498 0.851 0.148 0.000 4243.00 4243.00 21.093 0.331 0.000 21.424 0.985 0.015 0.000 5217.00 5217.00 14.637 5.002 0.015 19.654 0.745 0.255 0.001 5218.00 5230.00 15.794 1.284 0.432 17.509 0.902 0.073 0.025 5250.00 5254.00 12.542 6.878 0.533 19.953 0.629 0.345 0.027 5252.00 5252.00 12.164 8.853 0.625 21.641 0.562 0.409 0.029 5284.00 5284.00 15.778 3.426 0.044 19.248 0.820 0.178 0.002 5330.00 5330.00 14.318 1.180 0.000 15.498 0.924 0.076 0.000 5382.00 5382.50 16.612 0.121 0.054 16.787 0.990 0.007 0.003 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 4 Plots Interval 4133.00 - 4133.00 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 19.155 0.851 Oil 3.332 0.148 Gas 0.011 0.000 Total 22.498 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 0.280 Irreducible 11.209 11.209 9.823 Free Fluid 11.289 11.289 12.675 Permeability [mD] Log Mean [ms] Coates 25.989 T1 65.036 LogMean 5.621 T2 23.421 Ben Swanson 0.685 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 5 Interval 4243.00 - 4243.00 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 21.093 0.985 Oil 0.331 0.015 Gas 0.000 0.000 Total 21.424 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 5.478 Irreducible 17.692 17.692 14.503 Free Fluid 3.732 3.732 6.921 Permeability [mD] Log Mean [ms] Coates 0.937 T1 20.629 LogMean 0.359 T2 6.527 Ben Swanson 0.010 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 6 Interval 5217.00 - 5217.00 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 14.637 0.745 Oil 5.002 0.255 Gas 0.015 0.001 Total 19.654 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 0.041 Irreducible 8.371 8.371 7.305 Free Fluid 11.282 11.282 12.349 Permeability [mD] Log Mean [ms] Coates 27.102 T1 112.960 LogMean 7.877 T2 36.329 Ben Swanson 2.158 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 7 Interval 5218 - 5230 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 15.794 0.902 Oil 1.284 0.073 Gas 0.432 0.025 Total 17.509 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 2.032 Irreducible 11.935 11.935 9.940 Free Fluid 5.573 5.573 7.568 Permeability [mD] Log Mean [ms] Coates 3.366 T1 41.071 LogMean 0.749 T2 12.553 Ben Swanson 0.225 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 8 Interval 5250 - 5254 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 12.542 0.629 Oil 6.878 0.345 Gas 0.533 0.027 Total 19.953 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 1.418 Irreducible 6.265 5.881 5.807 Free Fluid 13.426 13.810 13.884 Permeability [mD] Log Mean [ms] Coates 116.741 T1 151.931 LogMean 21.018 T2 51.061 Ben Swanson 3.668 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 9 Interval 5252.00 - 5252.00 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 12.164 0.562 Oil 8.853 0.409 Gas 0.625 0.029 Total 21.641 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 1.902 Irreducible 5.153 4.432 5.153 Free Fluid 16.488 17.209 16.488 Permeability [mD] Log Mean [ms] Coates 224.583 T1 201.997 LogMean 35.796 T2 63.874 Ben Swanson 6.122 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 10 Interval 5284.00 - 5284.00 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 15.778 0.820 Oil 3.426 0.178 Gas 0.044 0.002 Total 19.248 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 0.738 Irreducible 8.168 8.168 7.695 Free Fluid 11.081 11.081 11.553 Permeability [mD] Log Mean [ms] Coates 25.264 T1 95.512 LogMean 4.336 T2 28.102 Ben Swanson 0.645 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 11 Interval 5330.00 - 5330.00 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 14.318 0.924 Oil 1.180 0.076 Gas 0.000 0.000 Total 15.498 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 0.114 Irreducible 9.068 9.068 7.495 Free Fluid 6.430 6.430 8.003 Permeability [mD] Log Mean [ms] Coates 2.900 T1 54.121 LogMean 0.749 T2 18.013 Ben Swanson 0.094 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 12 Interval 5382 - 5382.5 MRIL PRIME 2DFC T1T2 MRIL PRIME 2DFC T1T2 Results Fluid Volume (PU) Saturation (V/V) Water 16.612 0.990 Oil 0.121 0.007 Gas 0.054 0.003 Total 16.787 MRIL PRIME 2DFC T1T2 Fluids Max. Volume [PU] Cutoff [PU] Spectral [PU] Clay Bound 0.525 Irreducible 8.212 8.212 7.961 Free Fluid 8.575 8.575 8.825 Permeability [mD] Log Mean [ms] Coates 8.662 T1 57.432 LogMean 1.121 T2 18.801 Ben Swanson 0.103 Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 13 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. Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 14 Appendix General Discussion of 2DFC- T1T2 1 Introduction 2DFC-T1T2 (2 Dimensional Fluid Characterization T1T2) is a standalone MRIL answer product model designed towards evaluating NMR well data with 2 dimensional inversion of simultaneous T1T2 data. The primary application of 2DFC-T1 T2 is for methane identification and quantification in either water base or oil base mud systems. The resulting outputs may be used in combination with conventional logs to enhance and improve log interpretation of gas (methane) bearing reservoirs. The 2DFC-T1T2 model neither assumes, nor relies on knowing, the nature of hydrocarbons present in the formation in most instances. However, an option is available for selecting the drilling mud system for the well to be analyzed. Selecting OBM or WBM will determine how the 2D map partitions are initialized to distinguish individual fluid types. Specific acquisition activation sets are recommended to acquire appropriate NMR datasets for applying 2DFC-T1T2 processing. These activation sets are considered “simultaneous T1T2” activation sets. These activation sets provide for a long wait time to achieve full/near polarization and higher number of echoes in the shorter wait times to better characterize the T2 components at various T1 values. The primary output from 2DFC-T1T2 is a 2 dimensional map of T1T2 distribution. We extract petrophysical quantities from this distribution. These quantities include gas volume and liquid volume for water based mud environments and gas volume, oil volume and water volume for oil based mud environments. Individual T1 and T2 distributions for each fluid type are also easily computed from the 2D map and displayed as outputs. For faster computation of T1 and T2 inversions that can be performed in real-time, we introduce the Dual Spectra Analysis (DSA). DSA is the real time data acquisition inversion utilized when acquiring simultaneous T1T2 NMR data with WLI. While both 2DFC-T1T2 and DSA are designed based on the same theoretical principles and based on the same ideas of simultaneous inversion, DSA is designed primarily for speed. Unlike 2DFC-T1T2, DSA does not generate the 2 dimensional map, but computes only the individual T1 and T2 distributions. Theoretical Foundations 2.1 Basics of DSA and 2DFC-T1T2 DSA and 2DFC-T1T2 use simultaneous inversion of all echo trains available from the activation set logged. The results of the 2DFC-T1T2 inversion produce a 2-dimensional map of the distribution (T1 & T2), where a feasible region is established to constrain the results of the inversion. The 1-dimensional T1 and T2 inversions can be trivially computed from this resulting 2D map. The results of the DSA inversion Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 15 produce only the 1-dimensional distributions for T1 and T2. DSA does not produce a two dimensional map. Simultaneous T1T2 NMR data has to be acquired to apply DSA and 2DFC-T1T2 processing. To resolve the T2 components, a long echo train using a long wait time is needed. Resolving the T1 components (only) requires echo trains corresponding to multiple wait times which do not need to be that long. As a rule of thumb, these short echo trains need not contain more than 10 echoes each. With DSA, increasing the length of the echo trains in the shorter wait times (1) results in improved time-zero intercept estimates (explained below) on the T1 buildup curve; and (2) facilitates using a somewhat shorter echo train in the longest wait time, although long enough to all full decay to zero amplitude. 2DFC-T1T2 utilizes information from all the echo trains as each echo train carries some of the T2 information corresponding to different T1 values. Figure 1 shows an example of a T1T2 measurement. Denote by M the measured data (vector of echo amplitudes in the echo train) and let subscripts A, B, C,… etc. correspond to the ntW different echo trains, in decreasing order of wait time, such that MA(t) corresponds to the echo train of the longest wait time. Figure 1: NMR T1T2 measurements (blue circles) and T1 buildup curve (red line). Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 16 To use DSA and 2DFC-T1T2 , appropriate activation sets should be selected. Guidelines to select activation set for DSA are the following: 1. Longest wait time large enough to fully polarize all fluids within the pore space. This requirement stems from the assumption in the DSA inversion algorithm to make it viable. 2. Multiple echo trains with different wait times. Only the echo train corresponding to the longest wait time need to be long (several hundred echoes); other echo trains can be short (of the order of 10 echoes). A depiction of an ideal activation set for DSA is shown in Figure 2(a). The sole guideline to design a good activation set for 2DFC-T1T2 is the following: Multiple echo trains with different wait times. Several (ideally, all) of these echo trains need to be long (several hundred echoes), as illustrated in Figure 2(b). The reason for the requirement of several large echo trains corresponding to different wait times stems from the fact that the information to compute the 2-dimensional T1T2 distribution lies in these long echo trains. Figure 2(a): Example of a good DSA activation set. The longest wait time has a long echo train while the other echo trains can be short. Furthermore, the longest wait time is large enough to almost fully polarize the pore fluids. Figure 2(b): Example of a good 2DFC-T1T2 activation set. Several echo trains corresponding to different wait times, each of which is long. Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 17 An example of an activation set for acquiring data with DSA would be a BRAZIL09 which has the longest wait time (Tw) large enough to fully polarize all fluids within the pore space. Examples of activation sets for processing with 2DFC-T1T2 would be T1T2G708, T1T2G711 and T1T2G718. A table with the activation set parameters of T1T2G711 is given below. Group ID Tw (ms) Te (ms) NE A 11,044 0.9 500 B 3,056 0.9 100 D 1,000 0.9 100 C 10 0.6 50 (8 repeats) E 30 0.6 50(8 repeats) F 100 0.6 100 G 300 0.6 100 2.2 Mathematical Foundations The measured data MA(t) for a particular wait time TwA is related to the two-dimensional probability density function x(T1,T2) by a Fredholm integral of the first kind: wAT wA t A dTdTTTTTxTttM 0 21112122 0 ),(),(),()(, (1) where 2/ 22 ),(TteTt, and 1/ 11 1),(Tt wA WAeTT. To simplify the problem, the unknown parameters T2 and T1 are discretized into n2 and n1 values respectively -- to obtain a grid of size n2 x n1 in the (T1,T2) space -- so that the only unknowns in (1) are the components in the function x(T1,T2). In practice, we use the values n1=n2=54. Let mA denote the Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 18 number of echoes in the echo train A. In matrix notation, the discretized version of (1) can then be written as ,KXK Y T 1 T 2AA (2) where 1Am AY , 2 2 nm A AK , 21nnX, and 11 1 nK. X is the discretized T1T2 distribution that we seek to compute. From Equation (2), it can be seen that each of the measured echoes in an echo train is related to T1 and T2 as follows: 2 21 1 1 // , 1 )1()( n j TtTt ji n i qA jqiWAeexty , (3) where xi,j is the corresponding entry in the matrix X and the index ],...,2,1[Amq identifies the sequence number of the chosen echo in the echo train A. The variables T1i and T2j respectively correspond to the i’th and j’th discretized values of T1 and T2 times. The quantity xi,j measures the amount of Hydrogen atoms (which determines the NMR response) present in the fluid component that has T1 and T2 values given by T1i and T2j respectively. In terms of petro-physical parameters, we can write jijitruejiSHIx,,,, where true is the true porosity of the formation, jiHI, is the Hydrogen index of the fluid component jiS, is the fractional saturation of the fluid component. 2DFC-T1T2 attempts to solve Equation (3) by solving for the matrix X. DSA on the other hand, solves Equation (3) but seeks only the solution of the one dimensional T1 and T2 distributions. In other words, DSA computes only the row sum and the column sum of X. In the following Sections, we describe the specific principles used in the DSA and 2DFC- T1T2 inversions. Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 19 2.3 DSA - Dual Spectra Analysis In DSA, we solve Equation (3) for the one-dimensional T1 and T2 distributions. Solving for T1 and T2 using Equation (3) is obviously a non-linear problem that is highly non-trivial. To remedy this, a 2-step process is used to compute an approximate solution consisting of (1) Time-zero inversion; and (2) Simultaneous 1-dimensional T1 and T2 inversions. Figure 3: Time-zero inversion solves for the intercepts (shown as yellow circles) for each echo train. These intercepts are computed by extrapolating the decay curves up to Time=0. This computation is an optimization problem captured by Equation (5). 2.3.1 Time-zero inversion The optimization can be made into a linear problem by first finding the time -zero intercepts (Figure 3) for each echo train corresponding to the different wait times. This is equivalent to the following T2 inversion problem: Axyx x x A A A y y y C B A C B A C B A ......000 000 000 000 ... , (4) Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 20 where 222///,,Tt C Tt B Tt A CBAeAeAeA, and xA, xB, xC denote the T2 distributions for the three longest wait times. A regularization term is added (to introduce a requirement on the smoothness of the solution) resulting in the following linear least-squares time-zero inversion: 2 2 2 20 *minarg LxyAxx x , where (5) is the regularization coefficient L is the regularization matrix 2 2 is the square of the 2-norm of the vector argument. The time-zero intercept for each wait time is then obtained by summing the amplitudes in the corresponding T2 distribution. The advantage of including all wait times in the same optimization problem is that constraints on the relationships between T2 distributions for different wait times can be included. For instance, for each transverse relaxation time, the porosities have to be monotonically decreasing with wait time. When the time-zero intercepts have been found, the simultaneous T1T2- inversion can be formed. 2.3.2 Simultaneous T1T2 inversion Denote by 1xntWm the vector of time-zero intercepts, and by 1/1 TtWeP the T1 polarization matrix. The simultaneous T1T2 inversion problem can then be formed as Hxz x x x x A A A P y y y m C B A T T T T C B A C B A ......0000 0000 0000 0000 0000 ... 2 2 2 1 , (6) and adding T1 and T2 regularization terms results in the following linear least-squares problem: Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 21 2 2 2 2 2 20 * 2211minarg xLxLzHxxTTTTx , where (7) 1T is the regularization coefficient for T1 2T is the regularization coefficient for T2 1TL is the regularization matrix for T1 2TL is the regularization matrix for T2 The main advantage of including all wait times and both relaxation distributions in the same problem is that the total porosity computed from the T1 distribution is identical to the total porosity computed from the T2 distribution. Note that Equation (6) assumes that the longest wait time fully polarizes the pore fluids; this assumption limits the success of DSA. Additionally, we can impose the physical constraint on the T1/T2 ratio to account for the fact that the T2 relaxation always occurs faster than the T1 relaxation. This constraint is discussed below. 2.3.3 T1/T2 ratio constraints Figure 4 shows T1 (red) and a T2 (blue) distributions and their corresponding cumulative distributions. Let R denote the T1 / T2 ratio. The physical constraint R 1 corresponds to T1 T2, which translates to the following restriction on the cumulative distributions: the transverse relaxation time (T2) at a particular cumulative amplitude has to be greater than, or equal to, the longitudinal relaxation time (T1). In the bottom plot of Figure 4, one can see that this constraint is fulfilled for all cumulative amplitudes by noting that the blue curve is at or above the red curve. For instance, at a cumulative amplitude of 3.0, the corresponding T2 value is 32 ms and the corresponding T1 value is 1200 ms, giving rise to a T1 / T2 ratio of about 37. Note that R increases with increased horizontal separation between the two curves. Constraints such as R Rmax for a chosen maximum ratio Rmax can be implemented in a similar manner. Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 22 Figure 4: T1 (red) and T2 (blue) distributions (top), and their corresponding cumulative distributions (bottom). 2.4 2DFC-T1T2 : Two Dimensional Fluid Characterization In 2DFC-T1T2, we solve Equation (3) for the two-dimensional distribution (2D map) for each value of xi,j and hence solve for the matrix X in (2). In an optimization framework, the problem to determine X can be posed as 2 120 *||||minarg F TT AAX KXKYX. (8) We refer the interested reader to the Appendix to gain further insight on how the optimization problem is solved. The Appendix also presents assumptions on the feasible region where the solution is expected to reside in order to facilitate faster computation. Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 23 The difference between 2DFC-T1T2 and DSA is as follows. Whereas the 2DFC-T1T2 method provides an image of the {T1, T2} distribution (see Figure 5), the DSA method only seeks to compute the projection of this image on the T1 and T2 axes (this projection yields the T1 and T2 distributions). Figure 5 illustrates a sample output of 2DFC-T1T2. Figure 5: Outputs from the 2DFC-T1T2 method. 2.5 Advantages of using DSA and 2DFC-T1T2 Benefits common to both the 2DFC-T1T2 and the DSA methods are: T1 and T2 distributions that satisfy ratio constraints using data from a single logging pass; The two total porosities computed from T1 and T2 distributions are equal; More accurate distributions compared to existing inversion methods. Benefits unique to the 2DFC-T1T2 method are: Generation of a 2 dimensional volumetric map of porosity; Denver FRS 1125 17th St Suite 1900, Denver, CO 80202 2 March 2015 Confidential Page 24 Generation of individual fluid distributions from the 2 dimensional volumetric map partitioning; Benefits unique to the DSA method are: computationally very fast as compared to the 2DFC-T1T2 suitable for real time processing
