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205-042
..: ,~ ~~ `' cif f ~f ~. ~, .. i ~~ Y ~ ~~ ~: ` •'~ '~. ~ ~~ I 1 y t # _ ,~.- . r!`:~[~ ~':.,. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • 18 iI-TRi)If-I'\I':~V~.-~~ • INEfKOFSEPTEMBER6,2~09 ([tltlllll~tl~ ~li~lli ~~tlhC 1 UNITS exploiatory work ~cithin the unii ureas. lt's a cood deal all around. said Gree Noble. nctinE chief of QLM Alaska's ener- ev and mine~als brnnch. "Units are supposed to be beneficial to botli panies." he said. "The lessees get more time ~o explore iheir leases and the govertunent gets a commitment that fur- Iher exploration will occur." WJ~ile mtiny leases ~cere uniiized. onoco ii ~ps an panners na ar ~o unc Pioneer Natural Reeources lel go 4J other lease~ co~-erine abow SOO.OOU sross acres, company spnkesu~oman Natalie Lo~ti~m&n tuld Petroleum Ne~~~s on 5ept. 2. The su~rendered leases didn't Gt the company's strategic plans bused on theu potential for development, she said What's mora manv were in the verv remote noiihwest section of die NPR-A. far to the ~~~est of existin~ produc~ion infrn- strucmre at the Alpine field. "We're really focuseA on Chukchi explOr2[ron rieht no~a~," Lowman added. ConocoPhillips hnd inore than $506 mil- lion in winninc bids in n ChuAchi Sea oB- shore lease sale in Februury 200R. New Bear Tooth unit The 6LM's Noble siened rwo Auc. ?5 letters creating a neti~ Bear Too~h unit and expandine the existine Greater Mooses Tooth unit. Both are in the northeast corner of the NPR-A. west of the Coh~ille Rirer and the Inupiat Eskimo villaee of Nwqsut. ConocoPhillips applied for the Dear Tooth unit on Aue. 19. Ic takes in all orpan of 23 leases coverine 105.655 acres, all federalland. Noble's letter says natural gas has been diccovered in the unit area. bm no oil. It idencifies the Cretaceous sandstone as the __ _ _ ~ - _ ~, . _~ ` s , ~ __ . } ~.^~ - . I ~.._.-._~ L . i ~- ~~ _ ' ~ ~ IJptLD~L ?CtYDLEL<YK KLStrVtAl.askA(N~-/~) ~ ; -,. NvRh o~l g r.,as u'+Ctr r--- ~-~ i ~_ ~ ~ -~ ~ ~ ~ ,: ~ ~ ~ '-- ~u~,..._- Tlie surrendeitd leases didn't (i[ the company'c sh~alegic plnns based on lhcir polen(inlJor dereloymeni, she snid. Whai's more, rnany wcrc in thc vcr~~ remote uordiwes~ sectiou af ihe NPN-A, (ar ~o d~c wcs~ o~ezistiug yrnAuction infrnsUUCnirr nl Ihe ,4lpine ficid. primary tareet and ~he upper .IUrassic sand- stone as ihe secnndary target. Under ihe unii aEreement. ConocoPhillips mu.i drill a~~ell to the pn- rnaiv target m~vhat's deciennted as Unit Area A lhe companv also must test the Scout I~rc « ~ i ie cecon aiv tareet in ieu of drilline a~~rll for Unrt Area [i~The sus- Lendrd Scou~ I u~ell, which shs on ~he nnrthem boundarv of the Greater Mooses Tooth unn. q'as spu m arc "linits nre supposed ~o bc beiieficial to both yarties. 71ie lessees get more time to exylore thcir len+es a~d Ihe bovernmeiv bEts n cOr~nuilmcnl lhal fur[her c~ylorcuinn ~vill occur ° -Greg Nobk, acting chief of BlM Akska's energy and minerals bran<h choice wuliin the expansion aren.'~ Noble's letier says. Failurc ~o spud the ~vell by the deadline will invnlidsie ihe unii expansion. the let- If'1 CAVti. NPR•A production coming ConocuPhillips has been the most acti~-e driller in rhe NPR-A. an Indiana- s¢ed ~rac~ of North Slope land former President Warren G NardinE cet aside in The e~reement eives ConocoPhillips a lune I. 2012, deadhne to carry out ihe c ri ing and tesung Z J S~IS~nC Greoter Mooses Tooth expnnded No61e also ~i~n~cd an eapansioii of ~he G'enter Mooccs Ti~oth unrt. originally foi~ned in January 2008. ConocoPhilhps nsked fm ihe expan- sion on July 29, Noble's approvnl letter says. The expansion adds four more leases ro the uni~. increasing rts size from 147.456 acres ~0 164.014 acres. AII ~he acreage is federal land. but 4Q?3R acres or about a quaner of ~he unic has been selecred for future subsurface conveyance to Aretic Slope Regional Co~p.. ~he lerter says. In exchanee for che expansion, ConocoPhdlips inust spud an esplora~ion ti~ell y ~he 1 urc qunner o~ ~. e we ail ~argei t e upper urass~c sandsrone and "will he loca~ed zt the Unit Operator's 1923 for its oil and gac potemial. Most of the expla~ation, and discwer- ies, have been confined to ihe reserve~s northeas~ comer. ciosest to the existinE pipelmes, roads and processine plants of the centrnl North Slope oil fields. Still. NPR-A ic ccrnsidered a fi~ontier e~here developmem diaatec an accumula- tion be erther very large or reasonably close to infrastrucwre- The NPR-A's lacest wave of leasing began in 1999. Since ~hen. ConocoPhillips has sun~endered leases on at least n+~o necasionc. The company ga~~e up 43 leas- es in 2007 and 41 leases lasi vear. Lowman said But the compam~ is marching to~card firs~ producuon &nw the NPR-A m late 12 with ttc CD-~ Alpine N'eci satelliic developmcnt. ~+'hic.h ic in the prrini[nnc ~hase. The produciion pad H~ouid cit roughly mid~<ny between the Alpine field to the east and the Greater Mooses Tooth unit to the wes~. • 2009 . .. • i 1~F_TR[~i.EU~ANF.1`/C • WEk.KOfAUGUST23,2009 ~9 ~ continued 1mm pege 17 LEASES erd go~-ernment began leasing land in the peu~oleum reserve more than a decade a~o. drilling a total of 20 wells. and participat- ine m two others. In 2007 ConocoPhillips began dropping leases in NPR-A, cullin~ whai it desa~ibed as acreage roo fnr from infieshvcwre to be economic to develop in areas where well results were Ioo smull to be commercial. But ConocoPhillip+ continued to pick up othei acreage in NPR-A. Its drilling in 2003 and 2D09 was closer to in(rasnvcture In 2008. ConocoPhillips and its fre- quent NPR-A partner Anadarho Petroleum, formed tlie (irst fedeial unit in NPR-A. Cireater Mooses Tooth. After ConocoPhillips and Anadarkds Alpine West (CD-51 satellite in the Coh~ille River unit has been developed Colville and Mooses Too[h operator ConocoPhillips has said development of CD-G and CD-7 NPR- A sa~elhtes would likely follo~n~. bMh of which are in the Mooses Tooth unit. Aipine West production is expected to come online at ehe end of 2012. -KAY CASHMAN ~ ~o~-a~ ~~~u~3 ~ ~os-o+~ti .~~ti-oc;c; ~~7l~'~~~ N~~ V~J~,~.~ e take from two «i three months. MMS said. joint bid with that kind of uncertai " e teases set t4 expire Aug. 31 ee weeks Co ust Z% companies partici- said during a telecrniferen ' mediately pated in Sale 21 _ - d U'ith S3 in last foliowmg Sale 21 your rendency is. ~,_m~~~~~,C~~~~~m~~ its ruling year~s Western Guli nf Mexico . e 'I can o ro the lease sale by goine Gal sale ~ura of the Natiorral ftVdeum Rtx'rtc-AIas1.3 ue sA ufort, and z~~ for example. ' u. robably saH~ some increase in meiyure`mAug.3L m ~. Interior Chris Oynes. MMS' associate d~ r the amount o , ompany) bids, or NCithef tt1C U.S. BuR`nu ol' Land Mao~ngeroent, utrr ourt with for offshore energy, indica et "underv e~~en the strength of ~he bi of Ctntxvf'luliq~ ww rradY 4~ cunvnN un n ~xuprn.al lbe wn- ss of hs curren~" stemmm ~ i uncenainty over thal undercurrent ~~ (any submiLLexl ydAier Ihis nrxiU~ tu HI.M ou dle expuuug . ~~"° 1O Ihe hti i~ely was a major factor in The SI 1546 million in apparent high DI.M ~L1S o0[ tom ICd itS fo t~l[ 2UC1gL, yG p1." 7CSp011SC pl0- cn~~irnn- ' e. bidc submitted in Wec~ern Culf Sale 210 Pnsol. ConacoPhittips soid mid BLdN anfirmed. s ener~~ ~y~'c verv. cery~ hard ~o makr the aGrec- (;I.M s~M~iwinwn Slurlx~ ~LSlln [Ob f~9'olCluf~ Tk1WS ~ . .,~.., ,,.~~c~.ui ~ ~ I ni~.~.~ r,~ .. ~. ..~ ~ LE~SF SRL[ ; ~ . ~ ~` Aug. 20, Jiat Grrru~PMlli~n has tcw q+tims fix a 10.yrar =10 ~vns :ompan} S!llfltSB psR1! 19 tinE iha~ •~:. iave sul- ~ + ' , . .._ __ . . , ~ .,.....~__ ~._..~ . .... .......:...: ...~.o., «.,,. ,.. ...,..o _~,.. _'" "'._..._ _ ...__. __ _.._..__ "" __'_ .._i deiaiL, ..........._:... ~ ~~ :k.~ .., _ ' . ..,~ _. r~ U ~'~! r ~ Permit to Drill 2050420 Wel MD 8425 TVD 8425 REQUIRED INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 ne/No. NOATAK 1 Operator CONOCOPHILLIPS ALASKA INC Completion Date 3/28/2007 Completion Status P&A Current Status P&A Mud Log Yes DATA INFORMATION Types Electric or Other Logs Run: Dipole sonic / GR /platform express / RWSC Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number ,fame D C Lis 14590 Induction/Resistivity og 14590 See Notes i og 14590 Induction/Resistivity 14590 ~ S• ~~ '- Je~g 14590 Si f!' S u~: ~- ~'f 5175 Report: Final Well R Pdf 15175 Report: Final Well R 15175 Mud Log Samples IVo API No. 50-279-20013-00-00 UIC N S1ia:1UC' ~~ Directional Survey No (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments 7100 8426 Open 4/9/2007 LIS Veri, FINAL AIT, CNT w/Graphics Col 8173 7306 Open 4/9/2007 Mechanical Sidewall Corring Tool 13-Mar-2007 5 Col 8000 8426 Open 4/9!2007 Platform Express, AIT, H, TLD, CNL, GR< Microlog 13-Mar-2007 2 Col 7160 8426 Open 4/9/2007 Dipole Sonic Imager, Compressional and Shear Data 13-Mar-2007 2 Col 7100 8412 Open 4/9/2007 BestTD* Processed Result Dipole Sonic 13-Mar-2007 0 0 Open 6/1/2007 Final Well Report: Table of Contents, Epuip & Crew, Well Details, Geo Data, Press/Form Strength Data, Drilling Data, Daily Reports, Formation Logs. Col 0 0 Open 6/1/2007 Final Well Report: Table of Contents, Epuip & Crew, Well Details, Geo Data, Press/Form Strength Data, Drilling Data, Daily Reports, Formation Logs.w/Graphics 2 Col 105 8425 Open 6/1/2007 MD Formation Log DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2050420 Well Name/No. NOATAK 1 8425 TVD __ _----- 15175 15175 15175 15175 C Lis 15227 8425 Completion Date 3/28/2007 - _ _ -- Lithology Gas Analysis Mud Log Maud Log <I nd uction/Resistivity 15227 Induction/Resistivity 1'og 15227 Neutron 15227 ~mma Ray 15275 See Notes Rp~ Sample See Notes Well Cores/Samples Information: Name -- -- - Cuttings ADDITIONAL INFORMATION Well Cored? ~/ N ~ ~ ~- o Chips Received? Y /~ Analysis ~/ N Received? ___ __ Comments: Operator CONOCOPHILLIPS ALASKA INC API No. 50-279-20013-00-00 Completion Status P&A Curren t Status P8~A UIC N 2 Col 105 ---- 8425 - Open 6/1/2007 MD Lithology Log 2 Col 105 8425 Open 6/1/2007 MD Gas Ratio 2 Col 105 8425 Open 6/1/2007 MD Drilling Dynamics 2 CoI 105 8425 Open 6/1/2007 MD Pore Pressure 0 2946 Open 6/18/2007 LIS Veri, ROP, GR, FET, NPHI, NCNT, RHOB w/Graphics PDF TIF 25 Col 123 8425 Open 6/18/2007 ROP, DGR, EWR phase 4 12-Mar-2007 25 Col 123 8425 Open 6/18/2007 DGR, CTN, ALD 12-Mar- 2007 25 Col 123 8425 Open 6/18/2007 DGR BAT 12-Mar-2007 0 0 Open 7/12/2007 Core Anal Report w/Graphics PDF and TIF 8173 8316 Open 10/15/2007 SideWall Core Description 0 0 3/10/2008 Geochemical Analysis report Sample Interval Set Start Stop Sent Received Number Comments 105 8425 3/28/2007 1222 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 3/29/2005. Daily History Received? / Formation Tops Y / N DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2050420 Well Name/No. NOATAK 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-279-20013-00-00 MD 8425 TVD 8425 Completion Date 3/28/2007 Completion Status P&A Current Status P&A UIC N - - - - -: Compliance Reviewed By: _ __ - - -- Date: ~7 ' ~ ~ ~ TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Noatak 1 Permit: 205-042 DATE: 2/2/2008 NPRA, North Slope, Alaska Noatak 1 502792001300 haracopy anarysls Geochemical Analysis Results: Noatak 1; Albert Holba and Debbie Stuart, ConocoPhillips Upstream Technology, Janaury 2008. Contains final analysis of mud gas and rock extract geochemistry. Please sign, scan transmittal, save as .pdf format and a-mail to address below. Or return to CPAI via mail. To all data recipients: All data is confidential until State ofA/aska designated,,.40GCC release date CC: Greg Wilsgq~~~~Q~C-gi,~D Receipt: R 1 n ~gn~ Date: ' ~~~Cons. Commission. ~~~S Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265, 6947 Sandra. . L emkeCa~Conocophi7lips. com ~b~ =~~~a Page 1 of 1 • • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Wednesday, September 05, 2007 11:34 AM To: NSK Expl Env Cc: Brassfield, Tom J; Winfree, Mike B Subject: RE: Pictures of CPAI Exploratory Wells ~Q ~ -®~-~a I left a voice message with the Environmental Coordinators (659-7217) on 8/31/07 regarding the location clearance inspections at Intrepid #2 and Noatak #1. The photos provided indicate conditions at the Intrepid #2 well location that require additional surface work. Noatak #1 location is acceptable. Please call to discuss, or summarize what CPAI plans to do to complete the surface abandonment at Intrepid #2. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Expl Env [mailto:n1662@conocophillips.com] Sent: Friday, August 17, 2007 6:15 PM To: Regg, James B (DOA) Cc: Brassfield, Tom J; Winfree, Mike B Subject: Pictures of CPAI exploratory Wells Jim, I talked to Chuck Sheve yesterday about flying by helicopter to inspect the two exploratory wells that ConocoPhillips drilled this past winter. Unfortunately, he couldn't make the flight but he said that sending pictures of the locations to you would suffice. Attached are two pictures of the Intrepid #2 location drilled south of Barrow and two pictures of the Noatak #1 location drilled in NE NPRA. If you need more information, let me know. Chris Chris Brown/Bob Lipchak Exploration Environmental Coordinators Office: (907) 659-7217 Fax: (907) 659-7706 Truck Phone: (907) 448-1976 6/2/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 30, 2007 8:07 AM To: Regg, James B (DOA) Subject: RE: Pictures of CPAI Exploratory Wells I agree that Noatak looks good, shouldn't be a problem giving location clearance there. Intrepid is another matter. I was copied on some recent messages from guys at DNR about location clearance and subsidence/ponding issues. I am surprised to see the extent of disturbance at Intrepid. It might be interesting to see if CPAI has photos from prior to drilling. It would appear that Intrepid may have different "soils" than Noatak. It is the furthest west of any location recently drilled. I think CPAI needs to be notified that the Intrepid site needs some work. Tom _ From: Regg, James B (DOA) Sent: Wednesday, August 29, 2007 2:47 PM To: Maunder, Thomas E (DOA) Subject: FW: Pictures of CPAI Exploratory Wells Pictures from Noatak and Intrepid locations are attached. Noatak is in good shape; mound still intact. I'd be interested in your thoughts about clearing location with subsidence around Intrepid well? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Expl Env [mailto:n1662@conocophillips.com] Sent: Friday, August 17, 2007 6:15 PM To: Regg, James B (DOA) Cc: Brassfield, Tom J; Winfree, Mike B Subject: Pictures of CPAI Exploratory Wells Jim, I talked to Chuck Sheve yesterday about flying by helicopter to inspect the two exploratory wells that ConocoPhillips drilled this past winter. Unfortunately, he couldn't make the flight but he said that sending pictures of the locations to you would suffice. Attached are two pictures of the Intrepid #2 location drilled south of Barrow and two pictures of the Noatak #1 location drilled in NE NPRA. If you need more information, let me know. Chris Chris Brown/Bob Lipchak Exploration Environmental Coordinators Office: (907) 659-7217 Fax: (907) 659-7706 Truck Phone: (907) 448-1976 6/2/2008 AOGCC Memorandum Date: August 30, 2007 To: Noatak #1 Well File PTD 205-042 From: Jim Regg, Petroleum Engineer -~ ~l~ ~ , Subject: Location Clearance Inspection • A Commission Inspector was unable to travel to the Noatak #1 well site for a location clearance inspection due to other priorities. In lieu of the Commission witness, I requested ConocoPhillips Alaska Inc. ("CPAI") submit photos. Noatak #1 was drilled from an ice pad in February-March 2007, located in northeastern part of the NPRA. CPAI provided 2 photographs of the well site from their July 26, 2007 location clearance visit. Pictures indicate the conditions at Noatak # I location are consistent with AOGCC requirements and location clearance can be granted. ConoCOF'Ilillips NOATAK #1 SIDEWALL CORE DESCRIPTIONS Described by: Greg Wilson 03/17/2007 35 Attemped, 35 recovered ~~~~ ~~ t~lNE10~1'TIN. ~ ZOS o~Ez Description Nates: 1 Most cores are very hard and covered with very fine LCM & Mud; descriptions are based on small chipped edges; percentages are very approximate 2 Soft, ubiquitous light grayish green detrital to compacted grains are identified as glauconite, althought positive identificaion will require XRD or Microprobe work 3 Due to the hardness of the sidewall cores, argillaceous material described below is suspected of containing microgranular sideritic cement 4 Abbreviations: GI =Glauconite; Qtz =Quartz, Arg = Argillaceous, of =very fine, U = Upper, L =Lower Fluorescence Sample Integrity Depth Recovery (inchesi (soft, firm, hard) Description Visible Porosity Odor Oil Stain % Intensity Color 8173 1.5 est firm Dk silt mudstone, subfissle None 8174 1 soft Siltstone, soft None Dk gry Glauconitic mudstone; GI vfU-f~; GI 30% Arg Matrix 65% Qtz 5%: GI is It grayish grn, appears altered, resinous to 8202 2 feces; 1.2 & .5 hard wa luster, soft None 8211 1.5+est 8212 1.9 - 2.0 hard AA None 8216 1.6 est Dk gry Glauconite Mudstone; GI vfU-fL; GI 55% Arg Matrix 35% Qtz 10%: GI is It grayish gm, appears alterred, resinous to waxy luster, soft; GI fL-fU; Qtz 8223 1.9 hard vfU-fL 8227 1.9 est sideritic Glauconite Ss; vfU-fL; GI 35% Qtz 35% sideritic Matrix 30%; GI is soft, but sample is 8234 hard extremet hard "vu s" <5% Petroliferous None 0 Glauconite Ss: GI vfU-fl. Qtz vfL- vfU to silt; GI 60% Arg Matrix 20% Qtz 20%; GI is It grayish green, subrounded to blocky, soft, locally appears partly compacted to a pseudomatrix; 8237.5 1.7 hard Qtz suban ular None Petroliferous None 0 8241 1.7 est r, U ._~ '` 4 Abbreviations: GI =Glauconite; Qtz =Quartz, Arg = Argillaceous, of =very fine, U = Upper, L =Lower Fluorescence Sample Integrity Depth Recovery (inches (soft, firm, hard) Description Visible Porosity Odor Oil Stain % Intensity Color Glauconite Ss: vfU-fL; GI 60% Arg Matrix 20-30% Qtz 10-20%; GI is If grayish green, blocky, soft, locally appears partly compacted to a pseudomatrix; 8247 1.8 hard Qtz suban ular None Petroliferous None 0 8248 1.7 est Glauconitic Ss: vfU-fL; Qtz 50% GI 40% Arg Matrix 10%; Qtz subangular; GI is It grayish green, subrounded to blocky, soft, locally appears partly 8251 1.8 hard com acted to a seudomatrix None Petroliferous None 0 8255 1.7 est Gtauconitic Ss: vfU-fL; GI 40% Qtz 40%Arg Matrix 20%; GI as 8256 1.8 hard above None Petroliferous None 0 8265 1.5 est Glauconite Ss; GI vfU-fL, Qtz vfU fL, locally fU; GI 50-60%, Qtz 20- 30%, Arg Matrix 1 D-20%; GI is ft grayish green, soft, subrounded; 8268 1.2 & 0.6 hard Qtz is suban ular to an ular None Petroliferous None 0 8273 1.7 est Glauconite Ss; GI vfU, Qtz vfU- fL; GI 60% Qtz 30°~ Arg Matrix 10%; GI subrounded to blocky, soft, pale grayish green; Qtz 8280 1.2 & 0.3 & 0.2 hard suban ular to an afar Petroliferous 8287 1.9 est Glauconite Ss; GI vfU-fL; Qtz vfU fL; GI 60°Io QtZ 30% Argillaceous Matrix 10% (trace oxidized); Glauconite occurs in blocky to subrounded to irregularly shaped grains and is soft, pale green, and appears alterred; Qtz is 8289 1.7 hard suban ular to an ular None Petroliferous None 0 8290 1.9 est CONFIDENTIAL • i 4 Abbreviations: GI =Glauconite; Qtz =Quartz, Arg =Argillaceous, of =very fine, U = Upper, L =Lower Fluorescence Sample integrity Death Recovery linchesl (soft, firm, hard- Description Visible Porosity Odor Oil Stain % Intensity Color Glauconite Ss; GI fL-fU; Qtz vfU- fL; GI 60% Qtz 30% Partly Oxidized Argillaceous Matrix 10%; Glauconite occurs in blocky to subrounded to irregularly shaped grains and is soft, pale green, and appears alterred; Qtz 8295 1.8 hard is suban ular to an ular None Petroliferous none 0 8297 1.6 est Glauconite 50% Qtz 30% Argillaceous Matrix 10% Oxidized Grains <5%; Glauconite appears altered; GI vfU-fU, subrounded to subangular; Qtz 8298 hard vfU-fU, suban ular to an ular None Petroliferous 8299 1.$ est Glauconitic Ss, vfU-fU; Qtz subangular to angular, Qtz 60%, GI 30%, Argillaceous material 8300 10%; tauconite a ears altered None Petroliferous 8309 1.5 est Glauconitic Ss, vfU-fU; Qtz subangular to angular; Qtz 60%, GI 30%, Argillaceous material 8302 hard 10%; tauconite a ears altered None Petroliferous 8304 1.4 est 8305 8306 1,5 est 8313 Ss, vfU-fL; argillaceous and 8316 1.8 hard cemented siderite? None CONFIDENiigL n I~ ~t~-r'1rJ+C~~"11~~1 ~ TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Noatak 1 Permit: 205-042 DATE: 10/10/2007 Hand deliver Tr n mitt NPRA, North Slope, Alaska Noatak 1 502792001300 Hardcopy analysis Sidewall Core Descriptions 8173' to 8316' md, Noatak 1, by Greg Wilson, 3/17/2007. CPAI apologizes for oversight on delivery of this data as required in AOGCC regs: b{3) lithology Please sign, scan transmittal, save as .pdf format and e-mail to address below. Or return to PAi via mail. To aU data reci Tents A/l data is confidentia/until State ofAlaska desi Hated AOCG'C re%ase date CC: Taimar Ramirez, CPAI Geologist Recei t: ~ Date: ~,~ U N °M GIS-Technical Data Management ~ ConocoPhillips ~ Anchorage, Alaska (Ph. 907.265.6947 Sandra.D.LemkeCa~Conocophi!lips com ~Or'I~C~-~"11~~1 ~ ~' TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7~' Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Noatak 1 Permit: 205-042 DATE: 07112/2007 NPRA, North Slope, Alaska Noatak 1 502792001300 Core Analysis Results(rotary sidewall cores): Noatak 1; CL file 57111-107160CP; Core Labs, Bakersfield CA Please sign, scan transmittal, save as .pdf format and e-mail to address below. Or return to CPAI via mail. all data recipients: All data is confidential until State ofAlaska CC: Andy Andreou, CPAI Geologist Receipt: Date: ~ ~ ~ k ~ ~` d'J re%ase K~~ `''~ ~ GIS-Technical Data Management I ConocoPhillips I Anchorage, A/aska I Ph: 907,265.6947 ~ndra.D.Lemkenu ConocoPhillips cvm ab5 -o~~a '~ ~5 a~s_ ,~~~~~ Core Lab AESEAVAIA OPSIMIZA'IION - ~'~~ ~i...i~ ~ t~;.. CORE ANALYSIS RESULTS CONOCOPHILLIPS ALASKA, INC. IVOATAK 1 WELL BAR~tOW SOUTH FIELD CL FILE 57111-107160CP Performed by: Core Laboratories 3437 Landco Dr. Bakersfield, CA 93308 (661) 392-8600 • PETROLEUM SERVICES ~bS -b~12 '~ t'S~~,S- • '~, '} Core Lab AESEAVO[A APTIMI2A7ION Mr. Greg Wilson ConocPhillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Subject: Core Analysis Data Well: Noatak 1 Field: Barrow-South Umiat Meridian, Alaska File No.: 107160CP API No.: 50-279-20013-00 Dear Mr. Wilson; • Petroleum Services Division 3437 Landco Dr. Bakersfield, California 93308 Tel: 661-325-5657 Fax:661-325-5808 www.corelab.com June 29, 2007 Rotary sidewall cores recovered from the subject well were submitted for permeability, porosity, and fluid saturation determinations. The results of these measurements are presented in the accompanying report. The saturations were determined by Dean Stark Methods with toluene as the distillation solvent. Following distillation, the samples were extracted of remaining hydrocarbon by soxhlet with methylene chloride/methanol. Prior to measurement of porosity and permeability to air, the samples were dried at 235 degrees Fahrenheit. Grain volumes were determined by Boyle's Law Double-cell Methods with helium as the gaseous medium. Bulk volumes were measured by mercury displacement at ambient conditions. Pore volumes were calculated from bulk volume and grain volume data. Permeability measurements were made with a confining pressure of 400 psig. The analysis procedures are noted on the data pages. We are pleased to have performed this service and hope it is beneficial in the evaluation of this reservoir. ®istribution: 1 original, 4 copies, 5 CDs: Addressee CL _~ ~ S~ Company: Conoco Phillips ,...~ Well: Noatak 1 '`~"- ~° Loc.: NAD 83 ASP4=5989076ftN 1747038ft W Care Lati HF.SF.AVOIA OPTIM(2hT1~N Rotary Sidewall Core Analysis Results File No.: 57111-107160CP Date: 4/24/2007 API No.:50-279-20013-00 Sample Depth Rec Perm. Porosity Fluid Saturation Grain Sample Method Description Number ft in Kair and % Oil % Water % O/W Ratio Total % Den 9/CC Wt. $ 1 8202.0 1.0 0.03 14.2 0.0 44.9 0.00 44.9 2.77 15.8 2 Sst dgry vfgr slty no stn no flor 2 8212.0 2.0 0.02 16.3 0.0 40.6 0.00 40.6 2.77 34.1 2 Sst dgry vfgr slty no stn no flor 3 8223.0 2.0 0.04 21.2 0.0 53.5 0.00 53.5 2.80 33.8 2 Sst dgry vfgr slt lams no stn no flor 4 8234.0 2.0 *" 21.7 0.0 46.2 0.00 46.2 3.16 31.3 2 Sst gry vfgr vslty no stn no flor 5 8237.5 1.8 0.02 17.1 0.0 42.4 0.00 42.4 2.76 32.4 2 Sst gry vfgr vslty no stn no flor 6 8247.0 1.8 0.02 18.9 0.0 64.9 0.00 64.9 2.78 33.8 2 Sst dgry of-fgr slty no stn no flor 7 8251.0 1.8 0.03 16.1 0.0 72.2 0.00 72.2 2.78 30.7 2 Sst dgry of-fgr slty sltst incl no stn no flor 8 8256.0 1.8 0.03 18.4 0.0 54.2 0.00 54.2 2.81 32.4 2 Sst dgry of-fgr slt strks no stn no flor 9 8268.0 1.1 0.04 21.0 0.0 83.5 0.00 83.5 2.81 15.5 2 Sst dbrn of-fgr slty no stn no flor 10 8280.0 1.3 0.19 22.0 0.0 85.3 0.00 85.3 2.80 20.6 2 Sst dbrn of-fgr slty slt incl no stn no flor 11 8289.0 1.8 0.15 23.2 0.0 75.4 0.00 75.4 2.80 28.5 2 Sst dbrn of-fgr slty slt incl no stn no flor 12 8295.0 1.6 0.07 19.6 0.0 57.8 0.00 57.8 2.82 31.8 2 Sst dbrn of-fgr slty no stn no flor 13 8298.0 1.8 0.43 23.2 0.0 66.7 0.00 66.7 2.81 25.1 2 Sst dbrn of-fgr slty no stn no flor 14 8300.0 1.7 0.03 19.8 0.0 67.1 0.00 67.1 2.83 31.2 2 Sst dbrn of-fgr slty no stn no flor 15 8302.0 1.6 0.03 19.8 0.0 57.5 0.00 57.5 2.82 23.7 2 Sst dbrn of-fgr slty no stn no flor 16 8305.0 1.7 0.45 24.1 0.0 78.8 0.00 78.8 2.78 29.9 2 Sst dbrn of-fgr slty no stn no flor "" Sample failed prior to permeability measurement Please note: Siderite cement is suspected in all samples based upon the high measured grain densities. No pyrite was observed. • • For Method Definition See Procedures Page Company: Conoco Phillips ~u- Well: Noatak 1 Core Lal~ Loc.: NAD 83 ASP4=5989076ftN 1747038ft W AGSF.AYl1IA OPTIMI2A'IION CORE ANALYSIS PROCEDURES AND CONDITIONS File No.: 57111-107160CP API No.:50-279-20013-00 Date: 4\24\2007 Core Type: Sidewall Cores Procedure (4) Procedure (2) Procedure (3) Procedure (4) Sampling Method Rotary Drilled Rotary Drilled Rotary Drilled Rotary Drilled Drill Coolant N/A N/A N/A N/A Jacket Matera _ Lead None N/A None Saturation Method ; Dean Stark (Toluene) Dean Stark (Toluene) Retort Dean Stark (Toluene) Porosity Method Grain Volume` Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Pore Vol Boyle's Law (Helium) Pore volume Boyle's Law (Helium) Bulk Vol-Grain Vol Summation Of Fluids Bulk Vol-Grain Vol i3uik volume Pore Vol + Grain Vol. Mercury Displacement Mercury Displacement Mercury Displacement Permeability Method Air Air Em irical Em irical Common Conditions Sleeved Sample Seating Pressure: N/A Confining Pressure Pore Vol & Permeability: 400 psig Samples Dried At 235 Degrees Fahrenheit Additional Extraction by Soxhlet with Methylene Chloride/Methanol Oil Density used in Calculation: 0.97g/cc ~J l'~r1+U~"11~~1 S ~' R~C~IiJED TRANSMITTAL JUN ~ ~ 2007 CONF/DENT/AL DATA ~lask~ Iai1 ~ ~~ ~o~~, emission FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken Ancfaora~o ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7~' Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Noatak 1 Permit: 205-042 DATE: 06/15/2007 NPRA, North Slope, Alaska Noatak 1 502792001300 Sperry Sun LWD data CDROM LWD digital log data LWD color log images Final Directional Survey report 0-8425' and ~ 1 color print each ROP/DGR/EWR-Phase4 - MD DGR/BAT - MD DGR/CTN/ALD - MD oos-~a og ~ r~~~..~ Please sign, scan transmittal, save as .pdf format and e-mail to address below. Or return to CPAI via mail. To a/1 data recipients: All data /s con~dent/a/ untr! State ofA/aska designated A4GCC re%ase CC: Andy Andreou, CPAI Geologist Receipt: ~ _ _ _.C~A - Date: S o~ ~D ~-- 4.~~ 1 ~i~ GIS-Technical Data Management ~ ConocoPhillips ~ Anchorage, Alaska ~ Ph: 907,265.6947 Sandra.D,Lemkena Conoci_phil/ips.com ~'~ • • ~t"1C~CC~1~"11~~I~5 TRANSMITTAL R~CE~V~p CONF/DENT/AL DATA Jul ~ Y 2007 FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken Alaska p~/ ConocoPhillips Alaska, Inc. AOGCC & Gas Cons, P.O. Box 100360 333 W. 7"' Ave., Suite 100 Anchorage ~0f~m'ssion Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Noatak 1 Permit: 205-042 DATE: 06/01 /2007 a NPRA, North Slope, Alaska Noatak 1 502792001300 Mudlog Report and CDROM Epoch-Final Well Report- mudlogging data, Noatak #1; O'Fallen/V1/alker 3/14/2007; distributed 5/07/07; Geological data, pressure/formation strength data, drilling data, daily reports, Formation logs (color, 2"=100'L Formation Log; LWD Lithology Log MD; Gas Ratio Log MD Drilling Loas {color, 2"=100' Drilling Dynamics MD; Pore Pressure Log MD ~CDROM contains Final well report text, morning reports, LAS files, DML data and Lithology remarks text files. Please check off each item as received, promptly sign and return the transmittal to address below. To all data reci tents: All data is confidential until State ofAlaska desi Hated AOGCC re/ease date CC: Andy Andreou, CPAI Geologist Receipt: Date: GIS-Technical Data Management ~ ConocoPhillips ~ Anchorage, Alaska ~ Ph: 907.Z6S.6947 Sandra. D. L emkeCa~Conocophillips. com s ~5-~~~ ~ ~~r~`5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 205-042 ConocoPhillips Alaska, Inc. Development ^ Exploratory ~ 7. Well Name: NOatak #1 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-279-20013-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ~ or Continuation ^ or Final ^ 307-086 3/9/2007 NPRA Exploration 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added 210.6"` 210.6 totals (obis): 2007 / 1st 991 100 0 1091 4 3/13/2007 3/16/2007 Noatak #1 2007 / 2nd 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume 991 100 210.6 1301.6 4 (obis): of the month following the final month of the quarter. Ex: July 20 for the second quarter, Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): "Leak-Off Test 1 hereby certify that the fore oing is true and correct to the best of my knowledge. ~ sly/~~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • ConocoPhillips April "L7,LUU7 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 [1~AY 0 3 20Q7 Alaska iii ~ Cas Cons. Commission Anchorage Subject: Well Completion Report for Noatak 1 (205-042 / 307-091) Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits this Well Completion Report for the recent work on the exploration well Noatak 1. The attachments include a summary of the daily drilling operations, a directional survey, an as-built, a summary of the P&A operations, list of the formation markers and photos of the site. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). This data is from federal lands. By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, lnc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Exploration Team Leader CPAI Drilling G. C. Aivord IG~ V E® Exploration Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 GCA/skad ~E~vty STATE OF ALASKA ~ MAY Q 3 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOF~~~-~~~~~I~pCO~"~'ISSion 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^ Exploratory Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. ~ t(~1 ~ 5. Date Comp., Susp., ~ orAband.: March.2~2007 2. Permit to Drill Number: 205-0421307-091 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~'~ ~_~ February 1r~, 20 7 S~ 13. API Number: 50-279-20013-00 4a. Location of Well (Governmental Section): Surface: 2504' FNL, 1932' FWL, Sec. 22, T12N, R5W, UM 7. Date TD Reached: March 11, 2007 14. Well Name and Number: Noatak 1 Top of Productive Horizon: 2504' FNL, 1932' FWL, Sec. 22, T12N, R5W, UM 8. KB (ft above MSL): 123.5' AMSL ' Ground (ft MSL): 103' 15. Field/Pool(s): Total Depth: 2504' FNL, 1932' FWL, Sec. 22, T12N, R5W, UM 9. Plug Back Depth (MD + ND): surface NPRA Exploration 4b. Location of Well (State Base Plane Coordinates): Surface: x- 607020 y- 5989360• Zone- 5 10. Total Depth (MD + ND): ' 8425' MD / 8425' TVD 16. Property Designation: ALK AA-081839 TPI: x- 607020 y- 5989360 Zone- 5 Total Depth: x- 607020 y- 5989360 Zone- 5 11. SSSV Depth (MD + ND): none 17. Land Use Permit: AK 5184 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 870' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Dipole sonic / GR /platform express / RWSC 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 63# H-40 21' 101' 21' 101' 24" 19o sx AS 1 9.625" 40# L-80 21' 2987' 21' 2987' 12.25" 167 bbls AS LITE, 40 bbls LiteCRETE 7" 26# L-80 21' 8148' 21' 8148' 8.75" 37 bbls Class G 23. Open to production or injection? Yes ^ No / If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET none none no perforations 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement from 7930'-8425' 19 bbls Class G plug from surf. - 1773' 21 bbls Class G, 29 bbls AS cement plug @ 313' 1z bblsAS 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ^/ Sidewall Cores Acquired? Yes Q No ^ If Yes to either question, list formations and intervals cored (MD+ND 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. # ~~ ~~n%~Fir~~ TO BE SENT UNDER SEPARATE COVER ~ yfRi 4 Form 10-407 Revised 2/2007 ORIGINAL CONTINUED ON REVERSE SIDE 'l'~+~ ~~ ~~~ ~ ~ 20D7 .~ r~ 28. GEOLOGIC MARKERS (List all formations and mark ncountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~/ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 870' g70~ needed, and submit detailed test information per 20 AAC 25.071. refer to attachment for geologic markers N/A Formation at total depth: Kingak 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, As-Built, photos of location, formation tops 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassflield @ 265-6377 Printed Name /~ Chi Alvord Title: Exploration Team Leader +S ~e ~2oD? ~ Signature .~i~, ~ Phone a. u S _ ~ ~2Q Date INSTRUCTIONS Sharon Allsup-Drake 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 2/2007 ~ ~ ~ ~ Operations Summary 1 ~ ~ NOATAK 1 's i Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10148733 1!17/2007 2/10/2007 3/16!2007 1l17/20u7 MIRU Uu:uii iviuVt NivB Noatak pad Is luuro complete. Continued to pioneer and construct ice road to M0410 for airstrip using water & snow from M0413. Started up Bluebird and began pumping onto lake M0410 for airstrip. Offloaded Rologons as they arrived, (camp loads 1-19 have been set). 1/18/2007 MIRU 00:00 MOVE MOB Continued to pioneer ice road to lake M0410 for landing strip. Began construction of cuttings pit using water & snow from M0413. Continued using Bluebird unit to pump water onto,lake M0410 for the Herc airstrip. Offloaded rologons as they arrived. All of the rig camp is set and warming up. 1/19/2007 MIRU 00:00 MOVE MOB Continued building ice road to M0410 for airstrip. Continued. pumping with Bluebird onto - - lake M0410 for airstrip.. Continued building cuttings pit utilizing snow & ice from M0413. Offloaded rologons as they arrived. Caterers are now on site. Begin drilling conductor hole & cellar. 1/20/2007 MIRU 00:00 MOVE MOB Finished building ice road to staging area of airstrip. Still working on apron/staging area. Continued pumping with Bluebird onto lake M0410 for airstrip. Finished construction of cuttings pit. Offloaded rologons as they arrived. Continue drilling conductor hole i~ cellar box. 1!21/2007 MIRU 00:00 MOVE MOB Continued working on staging pad at airstrip, (approximately 20% complete). Using small dozer to knock down drifts on airstrip. Continue flooding airstrip with bluebirds. Finished digging out cellar. Set the cellar box in the hole and backfili. Unload rollgons as they arrive. Rigged up Kuukpik truck shop. 101.01 101.00 i i Page 1/17 Report Printed:. 5/2/20071 ti /, -- -_~\ i IlLL/2007 MIRU 00:00 MUVE MUB Kun L x 4uttjoints of ie° conductor 24.00 101.0 1ULU u.uu i pipe in & spud on bottom, (80ft). Conduct PJSM. Rig up Schlumberger. Mix & pump 250sx ArcticSet 1 D816 down annulus with no returns. Cement ~ u-tubed -tagged in conductor @ 25'. Shut down & let cement set up. Start pumping again and got returns back to surface. Rig down cementers. After 10hrs cement had not setup. Checked at 4:30am, Jan. 23, (20hrs) and it had finally set up. Continued work on staging area of herc i strip & taxiway. Clearing snow from airstrip & using bluebird pumpers to flood same. ' Staging area 50% complete. Taxiway 20% complete. ~ Unloading rig pieces off rolligons. 1/23/2007 MIRU 00:00 MOVE MOB Backfilled around cellar & froze in 24.00 101.0. 101.0 0.00 place. Welded baseplate to conductor Cut conductor 17" below ice pad level (after discussions with Anchorage office). Welded landing ring to conductor. Unload rig pieces from rolligons as they arrive. Continued work on staging pad of herc strip & taxiway. Using dozer to knock down drifts and flood with Bluebird pumpers. Staging area 80% complete. Taxiway 80% complete. Note: Tomorrow's Wellview report will switch from "Location Building" job type to "Drilling Original" job type. 1/24/2007 MIRU 00:00 MOVE RURD Laid out rig liner around cellar & laid 24.00 101.0 101.0 0.00 down rig mats. Spotted rig sub-structure base over conductor pipe. Continued work on Herc strip & staging area. Clearing drifts & flooding with bluebirds. Doing minor maintenance on ice road Had Telecom do all prep work/wifing at I Peak camp today prior to shutting it down sattelite tomorrow to minimize the amount of time that we have no ' communication. Bill St. Lawrence & Lounsbury I Surveyors scouting airstrips. Found new location for Otter strip south of the ~ Herc Strip that is mostly. grounded, (2200' grounded, 800' floating, <4.5' water depth, 3-3.5' ice thickness). i Bill will check ice thickness on the Herc i I strip in the next day or two. !, Page 2/17 Report Printed: 5/2/2007 Operations Summary NOATAK 1 j .., ,,~ ,` 1/z5/ZUU7 MIKU UU:UW MOVE 1 /26/2007 1/27/2007 1/28/2007 I /29/2007 MIRU MIRU I MIRU MIRU I Operations Summary NOATAK 1 00:00 00:00 )0:00 )0:00 MOVE MOVE MOVE MOVE ~~ ,, _ ~ ~ ~~; kUKD Installed ny ioor on sub-structure. 24.vU 101.0 101.0 0.00 base. Started spotting other ng modules. Bill St.Lawrence drilling & checking ice depth of Herc strip: currently at an average thickness of 3.8', (began with 3.0•) Surveyors laying out new Otter strip. Continue to-flood herc strip with Bluebirds. Continue work on staging area & taxiway. Staging area: 95% complete. Taxiway 90% complete. RURD Continue putting rig modules together. 24.00 101.0 101.0 0.00 Continue flooding Herc strip with bluebirds. Finished construction of#axiway and staging area. Constructed generator pad and access road to Otter strip. Cleared snow from Otter strip. Started putting water down on Otter strip to build ice thickness on floating section. Still unloading rolligons as they arrive with rig pieces. RURD Pinned derrick to substructure. 24.00. 101.0 101.0 0.00 Conduct PJSM. Raised derrick safely. Raise rig floor as well. Continue putting rig modules together. Rig went to working days & nights. Continue flooding Herc strip with bluebirds. Doing some minor maintenance on ice Yoad/creek crossing. Finished clearing snow & watering Otter strip. Waiting on Fairweather to fly out & install lights, (Sunday or Monday). Still unloading rolligons as they arrive with rig pieces. RURD Continue putting rig together. 24.00 101.0 101.0 0.00 Continued flooding Herc strip. Doing some minor maintenance on ice road/creek crossing. Bald Mountaint Single Otter flew Fairweather out to start installing lights on Otter strip and set up associated equipment. Offloading rolligons as they arrive. RURD Install landings. Work on service lines. 24.00 101.0 . 101.0 .0.00 Warm up boiler room. Set in #2 centrifuge building. String auxiliary hydraulic lines. Set mats for pipe skate. ~ Take on water for boiler hotwelC Continue flooding herc strip. FWX , installed lights on otter strip. , I Page 3/17 Report Printed: 5/2/2007 ~ `~ Operations Summary f j NOATAK 1 ~, -. ~~ ~ _ , - ~ ~ ~~~ ~ ~, K, ii3u«uu7 'ivilkU u0:00 'MOVE KURD Build cattle chute and install. Hd~ust G~t.uu 101.0 101.0 U.00 catwalk. Continue work on service lines. Lay herculite and plywood for fuel tanks. Remove and plug lower ~ valves on fuel tanks. Finish setting pipe shed and connect power. Connect hopper room mud lines. Set tioagas and connect fuel lines. Clean snow from ducts. Connect hydraulic hoses to rig floor. Rig up pump room. 1/31/2007 MIRU 00:00 MOVE RURD Off load rolligons. Fire up tioga 24.00 101.0 101.0 0.00 heaters. Rig up pump room. Shovel out pipe shed. Connect hydraulic hoses to rig floor. Assist Hand-Y-Berm installers. Keep snow shoveled from exits during blow. Install guards on mud pumps. Cover broken windows. RU new centrifuge and dewater modules. 2/1/2007.. MIRU 00:00 MOVE RURD Finish guard on #2 pump. Install 24.00 101.0 101,0. 0,00 guages. Work on cuttings chute. Remove snow from walk. Chink up buildings. RU steam heaters to blow on drawworks. Hook up equilizer. RU outside lights on buildings. Trouble shoot hydraulics and generator. Lay herculite for upright tanks. String up blocks. Strip line onto drum. Hook up weight indicator and deadman. PUtop drive and hook up bridle lines. Telescope derrick out. Pick up and pin lower torque tube. 2/2/2007 MIRU 00:00 MOVE KURD Make up T-baron torque tube. Rig up 24.00 101.0 101.0 0.00 dog house on the board. Hook up trolly beam in the pipe shed. Unbridle, slip on 8T of drill line. Install goose neck. Rig up top drive service loop. Rig up mud line. Rig up Koomey hoses. Set water tank, lay plywood and set 6ea mud storage tanks. Hook up poor boy u-tube. Hang rig tongs. Rig up floor mud manifold. I Page 4/17 Report Printed: 5/2/2007 • /' - __ `\ ~i Operations Summary NOATAK 1 i ~, ,_ ,. :, (z/3/zuu/ MIkU uu:uu iv1U'vE kUkD RU tongs and spinners. Putotl in -fop z4.uu~ 1vi.u lui.Ul 0.00 Drive. Clean area on location for mud products, assist in setting up handy-berm, lay herculite for mud products. Transfer mud products to bermed area. Installed safety chains across v-door. Modified DS derrick board windwall. Clean debris from pits. Install safety cable on high pressure mud lines. Install bleed off line. Set diverter line and bolt up knife valve. Set fuel transfer house. Ready pits for water. Offload rolligons. RU choke hose to manifold. Install savor sub. Pressure up counterbalance system: I I Make up water lines to tank. ~ Spotvacuum connex and plug in. Repair derrick board lights and heater. ~ RU geronimo line. Adjust kelly hose ' away from elevators, hook up bleed off ~ ~ ~ hose. I I 2/4/2007 MIRU 00:00 MOVE RURD Install fire. extinguishers. Install no 24.00 101.0 101.0 0.00 freeze valve in water tank. Dig iron out of dumpster. Start rigging up vacuum system. Re-install DS derrick board windwall. Rig down truck shop. Lay herculite and move shop next to rig. Rig up truck shop with power: Build drip pans for light plants: set change ~ room and Sperry Sun shack. Sperry I. sun is rigging up to run lines. Finish rigging up water lines. Hook tap fuel transfer house. Set service buildings. Set bbl storage connex. Placed starter head in the cellar. Removed ODS derrick board wind wall. Pumped water through pits. 2/5/2007 MIRU 00:00. MOVE RURD Remove shaker stairs, place starter 24.00 101.0 101.0 0.00 head, adapter spool and annular. preventer in cellar to thaw. Re-install shaker stairs. Spot portable HPU. Connect hydraulic lines to BOP hoist. Install new torque gauge bracket and torque gauge. Finish dressing derrick board. Orginize pump part inventory. Function shakers, centrifuge, agitaters, charge pumps and auger. Set starter head. NU diverter and diverter spool i NU knife valve and diverter line. Hook up Koomey hoses. Install 2" valves. Hook up chains. Hank flow line. Pressure up Koomey and function test ~ diverter system: Lay herculite and ~ moved barreled mud products into the ~ bermed areas. Offload rolligons. I _ -- --~ - ' Page 5/17 Report Printed: 5/2/2007 • I c/6l2007 2/7/2007 2/8/2007 MIRU MIRU MIRU 2!9/2007 I MIRU. Operations Summary NOATAK 1 J i X0:00 X0:00 D0:00 I ,_ '~ ~.~ ~r, of mud products to t4.uu lu i.0 101.0 U.OU MUV E ~ MOB ~ ~ont.wi transfer berm area gather up floor valves,. xo's & sub rack place on rig floor, NU bell nipple and flow line, cont plumbing II h k m lex MOVE MOVE MOVE pits,insta stairway on s a er co p build additional mud product containment and stack mud product in same. Re-install OD side derrick board wind wall, remove flow line for additional mods & re-install, roll pump 1 &2, troubleshoot elect. [probs on #2, install shaker screens, 2" line from chk to shakers,change knife valve orientation, NU,test run #2 trouble shoot PLC, install trolly and chain hoist in pipe shed, install bolts on diverter and tighten, add hyd oil to HP, cont working on HP and PLC KURD Work on steam heat to water tanks, ' 24.00 101.0 101.0 0.00 unload rolligons, trouble shoot HPU and PLC, finish steam loop to water Tanks, contd work on mods to shaker cuttings chute, load HWDP,install mouse hole and dress slips, test run pumps fix stroke counter, generator shut down, restart generator, change. UOS, work on shaker dumps, PU and stand back 44 stds of DP in derrick set 4 mud storage tanks, hok up steam to water tank KURD Rig accept @ 00:00 2/8/07, Re-install 24.00 101.0 101.0 0.00 handi-berm around tank farm, repair fuel line to generator kid, work on mods to de-water house auger cuttings chute, dress spare heads for mud pumps, finish mods to de-water house and shaker chutes, load shed wl BHA, work on rig to camp toms, test mud lines to 4000 psi. OK. Remove BHA and load 1 layer of casing, re-load BHA,cover hole on centrifuge house, get outside water tank circulatiing, Pull mouse hole, trim out opening to fit larger mouse hole, repair derrick lights, shorten operating chain on pipe shed hoist, chip out cellar floor below mouse hole. KURD Remove snow and ice from cuttings 24.00 101.0 101:0 0.00 tank, Off load rolligons, take on fuel,. modify larger mouse hole, Install mouse hole, hook up fuel transfer hose, cont taking on fuel, replace lights in derrick, assist Sperry with RU of wiring, remove handi-berm, set tanks, replace handi-berm, start building mud, I I (weld on 4" outlet on conductor, MU i hanger on landing joint for dummy run. I i i -- - ~ I( Page 6/17 Report Printed: 5/2/2007 • ~ Operations Summary NOATAK 1 ~,~ ~z/1UlLUU% MIRU uu:uu fvlv'vE KUkU LDlandingjointandhanger,continue 14.ut1 1ti1.U 1u1.0 0:00 to build spud mud and ship to active pits 2/10/2007 SURFAC 14:00 DRILL DRLG MU 12-1/4" bit and xo to 4 SWDP, RIH 1.50 101.0 101.0 0.00 tag at 34' 2/101200T SURFAC i 15:30 DRILL DRLG Thaw out mud line in cellar and thaw .6.50 101.0 101.0 0.00 i out out kelly hose 2/10/2007 SURFAC 122:00 DRILL DRLG Break circ check out surf equipment 2.00 101.0 .101.0 0.00 and drill 34' to 6T with firm cement from 46' down 2/11/2007 SURFAC 100:00 DRILL DRLG Drill 6T to 105' Broke out of hard. 4.00 101.0 101.0 0.00 cement at 103' 2/11/2007 SURFAC 04:00 DRILL DRLG Circ out Biozan mud and changeover 1.50 101.0 101.0 0.00 to spud mud !2/11/2007 SURFAC. 105:30 DRILL DRLG Dri11105to156' 0.50 101.0 101.0 0:00 2/11/2007 SURFAC 106:00 DRILL DRLG Cut out grateing on auger cover 0.50 101.0 101.0 0.00 2/11/2007 SURFAC j06:30 DRILL DRLG Drill156' to 230' 3.00 101.0 101.0 0.00 2/11/2007 SURFAC 09:30.. DRILL TRIP Circ and condition, Blow downTD 0.50 101.0 101.0 0.00 12/11/2007 SURFAC 10:00 DRILL TRIP POOH 230 'to bit. Hole swabbing 2.00 101.0 101.0 0.00 !2/11/2007 SURFAC 12:00 DRILL DRLG PU BHA. Change out jets on bit. Plug 6.50 101.0 1.01.0 0.00 into RLL tool and test same 2/11/2007 SURFAC.. 18:30 DRILL DRLG reamfrom 210'-230' check mwd tool 1.00 101.0 101.0 0.00 2/11/2007 SURFAC 19:30 DRILL DRLG Drill 230' to 271' 2.00 101.0 101.0 0.00 2/12/2007 SURFAC 00:00 DRILL DRLG Drill271'to 1228' 19.50 230.0 1,370.0 1,140.00 2/12/2007 SURFAC 19:30 DRILL CIRC Circ hole clean @ 614 gpm w/ 1700psi 0.50 230.0 1,370.0 1,140.00 ~ and 135 rpm and 1500 ft-Ibs tq 2/12/2007 SURFAC 20:00 DRILL DRLG Drill 1228 to 1291' 1.00 230.0 1;370.0 1,140.00 2/12/2007 SURFAC 121:00 DRILL CIRC circ hole clean w 575 gpm @ 1575 psi 0.50 . 230.0 1,870.0 1,140:00 w 135 rpm @ 1500 torq 2/12/2007. SURFAC 21:30 DRILL DRLG Drill 1291'. to 1370' 2.00 230.0 1,370.0 1,140.00 2/13/2007 SURFAC !00:00 DRILL DRLG drlg. 12 1/4" Hole from 1370'to 1417. 1.50 1,370.0 2,435.0 1,065.00 2/13/2007 SURFAC 01:30 DRILL OTHR Adjust torque on top drive-change dies 1.00 1,370.0 2;435.0 1,065.00 in grabber 2!13/2007 SURFAC. 02:30 DRILL DRLG Drlg. from 1417 to 1542'. 2.50 1,370.0 2,435.0 1,065.00 2/13/2007 SURFAC 05:00 DRILL CIRC Circ. hole clean for wiper trip. 1.00 1,370.0 2,435.0 1,065.00 2/13/2007 SURFAC D6:00 DRILL TRIP POH to 460'. (Little Knotty) 2.00 1,370:0 2,435.0 .1,065.00 2/13/2007 SURFAC 08:00 DRILL OTHR Clean Floor & monitorwell. 0.50 1,370.0 2,435.0 1,065.00 2/13/2007 SURFAC 08:30. DRILL TRIP RIH from 460' to 1.542'. No Problems. 1.00 ' .1,370.0 2,435.0 1,065.00 2/13/2007 SURFAC 09:30 DRILL DRLG Drlg. from 1542 to 1671'. 2.50 1,370.0 2,435.0 9,065.00 2/13/2007 SURFAC 12:00 DRILL DRLG Drlg. from 1671'to 2435'. TQ off 12.00 1,370.0 2,435.0 1;065.00 bottom 750# On bottom 3150#UP wt. 78k down wt 78k rot wt 74k. 2/14/2007 SURFAC 00:00 DRILL DRLG Drlg. from 2435'to 2548'. 2.50 2,435.0 3,000.0 . 565.00 2!14/2007 SURFAC 02:30 DRILL OTHR Lost charge pump pressure-stand back 5.50 2,435.0 3,000.0 565.00. stand of pipe & trouble shoot system 2/14/2007 SURFAC 08:00 DRILL OTHR Rig Maintenance & change swivel 1.50 2,435.0 3,000.0 565.00 packing. 2!14/2007 SURFAC 09:30 DRILL DRLG Drlg. from 2548 to 2670'. 2.50 .2,435.0 3,000.0 565.00 2/14/2007 SURFAC 12:00 ~ DRILL DRLG Drlg. from 2670' to 3000'. up wt. 82k do 6.50. 2,435.0 .3,000.0 565.00 wt-88k rot 82k. 580 gpm @ 2150 psi tq 3100 on bottom 1250 off. 2/14/2007 SURFAC 18:30 DRILL CIRC CBU 580 gpm 2100 psi 120 rpm. 1.00 2,435.0 3,000.0 565.00 2/14/2007 SURFAC 19:30 DRILL TRIP POH from 3000'to 2170' (Pulled tight 4.00 2,435.0 3,000.0 565.00 most of way.) - 2/14/2007 SURFAC ! 23:30 ! DRILL CIRC CBU @ 2170'. 0.50 2,435.0 3,000.0 565.00 12/15/2007 ( SURFAC X 00:00 ~ DRILL OTHR Change out grabber dies on top drive. 0.50 3;000.0 3,000.0 0.00 2/15/2007 SURFAC 00:30 DRILL OTHR Continue pumping out of hole from 4.50 3,000.0. 3,000.0 0.00 1671' to 460'. Hole freed up @ 1050 but began swabbing to 460'. ~ Page 7/17 Report Printed. 5/Z/2007 • i ~,v _,~ j i zr15/zuU7 2/15/2007 2/15/2007 2/15/2007 JUt1FAi; SURFAC SURFAC SURFAC 2/15/2007 2/15/2007 2/15/2007 2/15/2007 2/15/2007 2/15/2007 2/15/2007 2/15/2007 2/16/2007 2/16/2007 2/16/2007 2/16/2007 2/16/2007 2/16/2007 2/16/2007 2/16/2007 2/16/2007 2/16/2007 Z/16/2007 2/16/2007 Z/17/2007 J17/2007 Z/17/2007 ?/17/2007 I Z/17/2007 ?/17/2007 J17/2007 SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC: SURFAC ~ Operations Summary NOATAK 1 u5:uo 06:00 07:00 08:30 09:00 10:00 11:00 11:30 12:00 14:00 17:30 21:00 00:00 02:00 03:00 06:00 11:30 12:30 14:00 15:30 19:30 20:30 22:30 23:00 00:00 00:30 37:00 39:00 14:00 15:30 18:30 12/17/2007 iSURFAC 21:30 ~ , i 2/17/2007 SURFAC 22:00 lU MILL IRIP DRILL OTHR DRILL TRIP DRILL CIRC DRILL CIRC. DRILL TRIP DRILL CIRC DRILL TRIP DRILL CIRC DRILL CIRC DRILL TRIP DRILL OTHR DRILL TRIP DRILL OTHR DRILL TRIP DRILL OTHR DRILL OTHR DRILL OTHR CASING SFTY CASING RNCS CASING CIRC CASING RNCS CASING RNCS CASING CIRC CASING RNCS CASING . CIRC CASING OTHR CASING OTHR CASING OTHR CASING CIRC CEMENT ; DISP i CEMENT (TRIP CEMENT. ~DISP ~, - ~. -~~ _:,,,r, , kIH rrom X100' to 1170'. 1.UU 3,Ouv.U 3,uU0.U 0.00 ' Clean floor after wet trip & prepare to 1.00 3,000.0 3,000.0 0.00 pickup 4" drill pipe. Picking up 4" dp & trip in hole to 2205'. 1.50 3,000.0 3,000.0 0.00 Hole tight @ 2205'-Circ. & ream thru 0.50 3,000.0 3,000.0 0.00 tight hoie Circ. hole clean @ 2205'. (550 gpm) 1.00 3,000.0 3,000.0 . 0.00 1685 psi 1500 TQ 115 rpm. RIH from 2205'to 2377. 1.00 3,000.0 3,000.0 0.00 Tight @ 2377. Ream down same. 0.50 3,000.0 3,000.0 0.00 RIH from 237T to 2799'. 0.50 3,000.0 .3,000.0 0.00 Wash & ream from 2799' to 3000'. No 2.00 3,000.0 3,000.0 b.00 Fill Circ. hole clean-Pump 20 bbl. hi vis 3.50 3,000.0 3,000.0 0.00 sweep. Level derrick while circ. hole clean. POH from 3000' to 1059'. Hole in good 3.50 3,000.0 3,000.0 0.00 condition, Continue pumping out of hole from 3.00 3,000.0 3,000.0 0.00 2170' to 1671'. POH, f/1059-368' 2.00 3,000.0 . 3,000.0 0.00 Fix Hydraulic leak on Drawworks 1.00 3,000.0 3,000.0 0.00 Finish POH & lay down HWDP. 3.00 3,000.0 3,000.0 0.00 Lay down BHA -down load sperry tools. 5.50 3,000.0 3,000.0 0.00 Lay down tongs & cleaning mud i~ ice 1.00 3,000.0 3,000.0 0.00 from rig floor. Lay down hydraulic elevators-pick up 1.50 3,000.0 3,000.0 0.00 bail extentions & rig up to run 9 5/8" surface csg. PJSM-Topic=running 9 5/8" csg. (rig up 1.50 3,000.0 3,000:0 0.00 Spider & slips.) Running 9 5/8" csg. to 1300'. 4.00 3,000.0 3,000.0 0.00 CBU @ 5 bpm. 1.00 3,000.0 3,000.0 0.00 Running 9 5/8" csg. from 1300' to 2.00 . 3,000.0 3,000.0 0.00 2300'. Running 9 5/8" csg. Fromm 2300' to 0.50 3,000.0 3,000.0 0.00 2965'. CBU @ 5 bpm. 1.00 3,000.0 3,000.0 0.00 Make up landing jt.-Tag @ 2987. 0.50 3,000.0 3,000.0 0.00 Circ.,condition hole-reciprocate 9 5/8" 6.50 3,000.0. 3,000.0 0.00 csg @ 5 bpm 200 psi. Back out pup jt.-rig down circ. 2.00 3,000.0 3,000.0 0.00 head-Blow down & land w/ 74k csg. wt. Make up stab in sub on 4" dp w/ 5.00 3,000.0. .3,000.0 0.00 centralizer-RIH w/ 4" stab in assembly to 2902'. Space out w/ pups & sting in float 1.50 3,000.0 3,000.0 0.00 collar-Rig up cement head & hoses.. Condition mud &circ. 804 bbls. mud. 3.00 3,000.0 3,000.0 0.00 PJSM-Pressure test cement lines ~ 3.00 3,000.0 . 3,000.0 . 0.00 3000# OK. Pump cement job-50 bbL- CW100-50 bbl. Mud push @ 10.5# followed w/ 167 bbl: arcticset lite 10.7# & 40 bbl. litecrete @ 12#-Chase w/ 24 bbl. mud. Rig down cement lines-lay down pup 0.50 3,000.0 jts. & pull 2 stands 4" dp. Drop wiper plug &circ. 40 bbl. to clean 1.001 3;000.0 drill pipe. ~ ; I ~ _ ~ _ Page 8/17 3;000.0 0.00 3;000.0 0.00 port Printed: 5!2/2007 • • /y - -_,\ ~' I -_ ~. ~~ , Li17fLUU7 5URFAi; z3:uo ~cMENT 12/18/2007 iSURFAC 00:00. CEMENT 2/18/2007 SURFAC 03:00 CEMENT 2!18!2007 SURFAC 03:30 DRILL 2/18/2007 SURFAC 04:00 DRILL (2/18/2007 ;SURFAC 12:00 DRILL 2/1$/2007 SURFAC 2/19/2007 SURFAC 2/19/2007 SURFAC Operations Summary , NOATAK 1 TRIP TRIP OTHR OTHR PULD PULD 19:30 ~ DRILL PULD 00:00 DRILL OTHF 06:00 DRILL OTHF 9/2007 SURFAC 09:00 DRILL OTHR 9/2007 SURFAC 12:00 DRILL OTHR 9/2007 SURFAC 15:00- DRILL OTHR 2/19/2007 2/19/2007 2/19/2007 2/20/2007 2/20/2002 2/20/2007 2/20!2007 SURFAC SURFAC SURFAC INTRM1 INTRMI INTRM1 INTRMI. INTRM1 NTRM1 DRILL 23:00 23:30 00:00 05:00 07:00 DRILL DRILL DRILL DRILL DRILL 10:00 11:00. 14:30 DRILL BRILL BRILL OTHR OTHR OTHR PULD PULD PULD SFTY 'ULD POH w/ 4" dp. 1.uU 6,vuu.u 3,000,0 O.UO POH w/ stab in tool on 4" Drillpipe & 3.00 3,000.0 3,000.0 0.00 Lay down same. Pick up 9 5/8" pup-makeup & back out 0.50 3,000.0 3,000.0 0.00 landing jt. Lay down same. Clean mud & ice off rig floor & lay 0.50 3,000.0 .3,000.0 0:00 down 9 5/8" handling tools. Nipple down diverter system-lay down 8.00 3,000.0 3,000.0 0.00 drlg. nipple & mouse hole. Nipple up wellhead & tbg. 7.50 3,000.0 3,000:0 0.00 spool-problems getting slip on head aIF the way down. Tested to 1000# 10 mins. OK. Nipple up BOPE. 4.50 3,000.0 3,000.0 0.00 Nipple up BOPE-High pressure kill 6.00 3,000.0 3,000.0 0.00 hose-high pressure choke hose @ ext. spool for length. Install rotary table-make up drlg. nipple. Nipple up BOPE-torge all bolts-make 3.00 3,000.0 3,000.0 0.00 up panic line-pick up mouse hole. Make up rotary table hoses. Install floor plate. Pick up tools ~ Equipment in cellar. Hook up accumulator hoses to bope. Make up flow line. Pick up test jt. & test plug-function test 3.00 3,000.0 3,000.0 0.00 bop. (Good) Fill stack & prepare for shell test. Attempt shell test-fix leaks-check test 3.00 3,000.0 3,000.0 0.00 plug-shell test to 3000 psi. Test annular preventer-250-3000 10 6.50 3,000.0 3,000.0 0.00 mins.- Test top pipe rams-blind rams-lower pipe rams-kill line valves-choke line valves-choke manifold valves-check valve-floor valve-dart valve- manual & hydraulic ibop to 250 low ~ 5000 high (NOTE each test held for 10 minutes low & high) Pressure test 9-5/8" surface casing to 1.50 3,000.0 3,000.0 0.00 3000psi for 30 minutes, (held solid}. Rig down test equipment. Set wear ring. Run in lockdown screws. . 0.50 3,000.0 3,000.0 0.00 Lay down landing joint. Rig up elevators. 0.50 3,000.0 3,000.0 0.00 Make up 8-3/4" BHA &MWD. 5.00 .3,000.0 3,000.0 0.00 Plug into MWD to confirm toot 2.00 3,000.0 3,000.0 0.00 communication. Surface test MWD w/ 500gpm: 3.00 3,000.0 3,000.0 0.00 Unsuccessful Troubleshoot and find sensor wire cut. Repair wire. Surface. test again -still no signal. Try surface test again -good signal Conduct PJSM & load radioactive 1.00 3;000.0 3,000.0 0.00 source in MWD. Pick up flex collars, x-over, collars, 3.50 3,000.0 ' 3,000.0 0.00 jars, collars, HWDP. Pick up 3000' x 4" DP out of pipe shed. 7.50 3,000.0 3,000.0 0.00 RIH f/ 2195' to 2794'. ~ Page 9/17 Report Printed: 5/2/2007) _-- _-- /~ ~~ Operations Summary Ire ~ NOATAK 1 l ~/~ul~uur iNTKivfi G[:uv Di-tILL ' 1 RIP Tag cement L Z7a4'. lirculate 1.00 - 3,000.UI _.. 3,uuu.u u.uv bottoms up. 2/20/2007 INTRM1 23:00 DRILL OTHR Break off single joint and rig up to 1.00 3,000.0 3,000.0 0.00 re-pressure test casing. 2/21/2007 INTRM1 00:00 DRILL OWFF Re-pressure test 9-5/8" casing. Pump 1.00 3,000.0 3,576.0 576.00 3.4bb1 and pressure up to 2500psi. Hold pressure 30 minutes. Final pressure 2460psi. Bleed off and get 1.9bb1 back. 2!21/2007 INTRMI 01:00 DRILL CIRC Break circulation at 2794' and wash - 2.00 3,000.0 3,576.0 576.00 down from 2794'-2897. Took weight at 2897 and continue washing down to 2987.. 2/21/2007 , INTRM1 03:00 DRILL DRLG Drill out shoe with 5000ft-Ibs torque. 1.00 3,000.0 3,576.0 576.00 Tag new hole @ 3004'. 2/21/2007 INTRM1 04:00 RIGMNT SVRG Conduct rig service. 0.50 3,000.0 .3,576.0 576.00 2!21/2007 INTRM1 04:30 DRILL ! DRLG Drill new hole from 3004'to 3020'. .0.50 3,000.0 3,576.0 576.00 2/21!2007 INTRM1 05:00 DRILL CIRC Circulate & condition mud for FIT. 3.00 3,000.0 3,576.0 576.00 Circulate 504gpm @ 1790psi. Displace well to 9.7ppg mud and transfer old mud to outside tank. 2/21/2007 INTRM1 08:00 DRILL LOT Conduct FIT. Pump to 1323psi at 1.50 3,000.0 3,576.0 576.00 surface and held for 10 minutes recording bleed off. Final pressure 1176psi. EMW @ 2987 = 18.2ppg. Bleed off remaining pressure. 2/21/2007 INTRM1 09:30 DRILL OWFF With bit @ 3020' obtain slow pump 0.50 3,000.0 3,576.0 576.00 rates: Pump #1: 30spm = 119psi, 50spm 172psi Pump #2: 30spm = 148psi, 50spm = 235psi 2/21/2007 INTRM1 10:00 DRILL RURD Rig up catch can in cellar. 1.00 3,000.0 3,576.0 576.00 2!21!2007 INTRM1 11:00 DRILL DRLG Drill from 3020' to 3076'. 1.00 3,000.0 3,576.0 576.00 At 3050': Up wt: 76k, Down wt: 84k, Rot wt: 76k @ 53rpm, 2500ft-Ibs. 2/21/2007 INTRM1 12:00 DRILL DRLG Drill from 3076' to 3576'. Circulate 8.50 3,000.0 3,576.0 576.00 bottoms up. At 3576': Up wt: 86k, Down wt: 86k, Rot wt: 86k @ 3400ft-Ibs. 2/21!2007 INTRM1 20:30 DRILL TRIP Wiper trip. POOH from 3576' to 3384'. 0.50 3,000.0 3,576.0 576.00 2/21/2007 INTRM1 21:00 RIGMNT OTHR Drilling line backlashed do drum. Slip & 3.00 3,000.0 3,576.0 576.00 cut to remove bad spot in drill line. 2/22/2007 INTRM1 00:00 RIGMNT OTHR Finish slipping & cutting a total of 369' 3.50 3,576.0 4,435.0 859.00 of drill line. 2!22!2007 INTRM1 03:30 DRILL TRIP Break circulation, bring pumps up to 2.00 3,576.0 4,435.0 859.00 500gpm @ 1950psi. Pulled 50k OSW to free pipe. POOH from 3384' to 2888', (inside surface casing): Pulled 50k OSW @ 3270', 3160'. 2/22/2007 INTRM1 05:30 RIGMNT ( OTHR Working on tank farm. 1.50 3,576.0 4,435.0 859.00 2/22/2007 INTRM1 07:00 DRILL S TRIP TIH from 2888'-3516': 1.50 3,576.0 4,435.0 859.00 2/22!2007 INTRM1 08:30 -DRILL ~ REAM Ream from 3516' to 3576'. 0.50 3,576.0 4,435.0 859.00 2/22/2007 ~ INTRM1 09:00 ~ DRILL j DRLG Drilling from 3576' to 3740'. ; 3.00 3,576.0 4,435.0 859.00 Up wt: 95k ~ Dn wt: 97k ~ i j Rot wt: 95k Page 10/17 Report Printed: 5/2/2007 • ,. -_- / ~ ~~ i 'LIZ"Ll0007 I INTKM1 2/23/2007 2/23/2007 2/23!2007 2/23/2007 2/23/2007 2/23/2007 2/23/2007 2/23/2007 2/24/2007 2/24/2007 2/24/2007 2/24/2007 2/25/2007 2/25/2007 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 NTRM1 NTRM1 NTRM1 NTRM1 NTRM1 Operations Summary NOATAK 1 12:UU ~ DRILL DkLG ~, ~~ Unlling trom s/4u' to 4435'.: Up wt: 110k Dn wt: 115k Rot. wt: 115k Rot Torque: 5000ft-Ibs 00:00 DRILL DRLG Drilling from 4435' to 4516'. 01:30 DRILL CIRC Circulate hole clean with 525gpm @ 2350psi, off bottom torque: 600ft-Ibs @ 70rpm). Pump slug, monitor well & blow down top drive. 03:00 DRILL i DRLG Short trip from 4516' to 3832'. Hole tight at 3832' to 3706'. Pulled 40k OSW to get through. Pumped out from 3706' to 3642'. Pulled good, (without pumping) from 3642' to 3574', (last wiper trip performed at 3576'). D5:30 DRILL TRIP TIH from 3574'to 4516'. 07:00 DRILL CIRC Circulate BU. 08:00 DRILL DRLG Drill from 4516' to 4530'. 08:30 DRILL CIRC Circulate well with pump #2 while changing liner gasket on pump #1. 10:30 DRILL DRLG Drill from 4530' to 4576'. Up wt: 120k Dn wt: 125k Rot wt: 120k Rot tq: 3000ft-Ibs 12:00 DRILL DRLG Drill from 4576' to 4677'. 14:30 DRILL CIRC Circulate well with pump #1 while changing swab in pump #2. 15:00 DRILL DRLG Drill from 467T to 4885'. 20:00 DRILL CIRC. Hole packing off, work free. Circulate well while changing shaker screens. 21:00 DRILL DRLG ~ Drill from 4885' to 4981'. Up wt: 122k Dn wt: 128k Rot wt: 120k Rot tq: 3000ft-Ibs 70:00 DRILL DRLG Drill from 4981' to 5113'. )6:00 DRILL DRLG Drill from 5113'to 5335'. Up wt: 125k Dn wt: 130k Rot wt: 127k Tq: 2500ft-Ibs 12:00 RIGMNT OTHR Change shaker screens. Change gasket in pump #1. 12:30 DRILL DRLG Drill from 5335' to 5645'. 18:00 DRILL DRLG Drill from 5645' to 6000': Up wt: 134k Dn wt: 138k Rot wt: 134k Tk: 3000ft-Ibs )0:00 DRILL DRLG Drill from 6000° to 6025'. ~ )0:30_ DRILL ( CIRC Pump sweep around. )2:00. DRILL TRIP Monitor well for flow -none. POOH from 6025' to 5210'. Pump out from 5210' to 4958'. POOH to 4460'. )6:00 I DRILL ~ DRLG RIH from 4460' to 6025'. 12.OU 1.50 1.50 2.50 1.50 1.00 0:50 2.00 1.50 2.50 4,435.0 0.50 4,435.0 5.00 4,435.0 1.00 4,435.0 3.001 4,435.0 6.00 4,981.0 6.00 4,981.0 0.50 5.50 6.00 ~> ,~ ~F 3,57(i.U 4,435.0 4,435.0 4,435.0 4,435.0 4,435.0 4,435.0 4,435.0 4,435.0 4,981.0 6,000.0 4,981.0 6,000.0 4,981.0 6,000.0 6,000.0 6,720.0 6,000.0 6,720.0 6,000.0 6,720.0 I 4,435.0 4,981.0 4,981.0 4,981.0 I 4,981.0 4,981.0 4,981.0 4,981.0 4,981.0 4,981.0 4,981.0 4,981.0 4,981.0 4,981..0 6,000.0 6,000.0 ` - ~ ~~r; i55y.UU' 546.00 546.00 546.00 0.50 1.50 4.00 2.00 546.00 546.00 546.00 546.00 546.00 546.00 546.00 546.00 546.00 546.00 1,019.00 1,019.00 1,019.00 1,019.00 1,019.00 720.00 720.00 720.00 720.00 )8:00- RIGMNT RGRP Circulate well with pump #1 while 0.50 6,000.0 6,720.0 720.00 changing swab in pump #2. Page 11/17 Report Printed: 5/2!2007 • /~ ~\ f 1 ~Y. I 2u[Si0007 iiNTRM1 2!25/2007 INTRM1 2/25/2007 INTRMI 2/25/2007 INTRM1 2/25/2007 1NTRM1 2/25/2007 INTRMI 2/25/2007 I NTRM 1 2/25/2007 II INTRMI 2/25/2007 I I NTRM 1 2/26/2007 INTRM1 2/26/2007 INTRM1 2/26/2007 INTRM1 2/26/2007 INTRMI 2(26/2007 I NTRM 1 2/26/2007 2/27/2007 2/27/2007 2/27/2007 2/27/2007 2/27/2007 2/28/2007 2/28/2007 2/28/2007 2/28/2007 2/28/2007 2/28/2007 2/28/2007 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 ua:3u 10:00 12:00 12:30 13:00 15:00 15:30 21:00 21:30 00:00 05:30 06:30 09:00 09:30 12:00 D0:00 D1:00 D1:30 D3:00 D5:00 14:00 14:30 D0:00 INTRM1 NTRM1 NTRM1 NTRM1 ' NTRM1 NTRM1 ~ 01:00 D2:30 06:00 I 12:00 16:00 Operations Summary NOATAK 1 DiiILL DRLG Dell from euto' to n ivu'. RIGMNT RGRP Repair fan belt on generator #2. I DRILL DRLG .Drill from 6100° to 6150' & get SPRs. 'I DRILL CIRC Circulate well it< condition mud while changing shaker screens. .DRILL DRLG Drill from 6150' to 6275'. DRILL (DRLG Circulate well & condition mud while changing swab on pump #1. DRILL DRLG Dril (from 6275' to 6642'.. DRILL CIRC Circulate well & condition mud while changing swab on pump #2. All 3 swabs have now been changed on pump #2. 1 swab has been changed ~on pump #1. BRILL DRLG Drilllfrom6642'to6720'. Up wt: 140k Dn wt: 144k Rot wt: 142k Rot tq: 5000ft-Ibs DRILL DRLG Drill from 6720' to 7003'. RIGMNT RGRP Circulate well while changing liner in pump #2. DRILL DRLG Drill from 7003' to 7095'. RIGMNT RGRP Circulate well while changing swab in pump #2. DRILL DRLG Drill from 7095' to 7232'. Up wt: 155k Dn wt: 160k Rot wt: 160k Torque: 8000ft-Ibs DRILL TRIP Blew hole in kelly hose. Pull pipe from. 7232' up to 7097'. Rig up head pin & circulation hose. Circulate & condition mud while changing kelly hose. RIGMNT ( RGRP Continue working on kelly hose. DRILL TRIP RIH from 7097 to 7232'. DRILL DRLG Drill from 7232' to 7282'. RIGMNT RGRP Circulate well while changing liner gasket in pump 1. RIGMNT RGRP Trouble shoot mud pump fluid end. Change out fluid end on pump 1. DRILL CIRC. Circulate i~ condition mud while. changing shaker screens. DRILL DRLG Drill from 7282' to 7541'. DRILL CIRC Circulate while changing swab on pump #1 DRILL DRLG Drill f/ 7541' to 7550': Up Wt157k Dwn Wt165k Rot Wt 162k DRILL CIRC Condition Mud and CBU DRILL TRIP Monitor well. POOHfrom7550'to 5360' DRILL TRIP POOH f/ 5360' to 1195'. Tight and swabing @ 3750'. Brk circulation. DRILL S TRIP i POOH f/ 1185' stand back DC DRILL ~ PUCD , Remove MWD source and LD MWD I I BAT Sonic Tool Page 12/17 - 1.50 6,000.0 6,7ZRU 72U.UU 2.00 6,000.0 6,720.0 720.00 0.50 6,000.0 6,720.0 720.00 0.50 6;000.0 6,720.0 720.00 2.00 6,000:0 6,720.0 720.00 0.50 6,000.0 6,720.0 .720.00 5.50 6,000.0 6,720.0 720.00 0.50 ' 6,000.0 6,720.0 720.00 2.50 6,000.0 6,720.0 720.00 5.50 6,720.0 7,232.0 512.00 1.00 6,720.0 7,232.0 512.00 2.50 6,720.0 .7,232.0 512.00 0.50 6,720.0 7,232.0 512.00 2.50 6,720.0 7,232.0 512.00 12.00 6,720.0 7,232.0 512.00 1.00 7,232.0 7,541.0 309.00 0.50 7,232.0 7,541:0 309.00 1.50 .7,232.0 .7,541.0 309.00 2.00 7,232.0 7,541.0 309.00 9.00 7;232.0 7,541.0 309.00 0.50 7,232.0 7,541.0 309.00 9.50 7;232.0 7,541.0 309.00 0.50 7,541.0 7,550.0 9.00 0.50 7,541.0 7,550.0 9.00 1..50. ' 7,541.0 7,550.0 9.00 :3.50 7,541.0 7,550.0 9.00 6.00 7,541.0 _7,550.0 9.00 4.00 7,541.0 7,550.0 9.00 1.50 7,541.0 7,550.0 9.00 Report Printed: 5/2/2007 • • w.-- __ s ` ~~~ 12/28/2007 IINIKM1 11:30 (UKILL PULD MWUUOwnload i.ou 7,p4"i.u /,oou.u - y.uu 12/28/2007 ~INTRM1 19;00 DRILL PULD LLD BHA. Test choke manifold while 3.00 - 7,541.0 7,550.0 9.00 laying down BHA. 2/28/2007 INTRM1 22:00 WELCTL BOPE 1 Pull wear ring, MU test joint 2.00 7,541.0 - 7,550.0 9.00 3/1/2007 INTRM1 00:00 WELCTL BOPE Test annular preventer 250 psi 4.50 7,550.0 7,550.0 0.00 low/3500 psi high for 5 min Test BOPE to 250 psi low/5000 psi high for 5 min Koomey test. 3/1/2007: INTRM1 04:30 WELCTL BOPE Pull test plug, close ann valve, set 1.00 7,550.0 7,550.0 0.00 ( ( (wear ring, RILDS, LD testjoint 3/1/2007 INTRM1 05:30 RIGMNT RGRP Work on service loop. 0.50 7,550.0 7,550.0 0.00 X3/1/2007 INTRM1 06:00 DRILL ,PULD PU BHA, MU bit and MWD. PJSM, 6.00 7,550.0 7,550.0 -0.00 load sources. 13/1/2007 INTRM1 12:00 DRILL TRIP RIH to 1149' 2.50 7,550.0 7,550.0 0.00 3/1/2007 INTRM1 14:30 (DRILL TRIP PU 22jts DP to 1840' 1.00 7,550.0 7,550.0 0.00 3/1/2007 I INTRM1 15:30 DRILL TRIP RIH from 1840' to 2987. Fill pipe 1.50 7,550.0 .7,550.0 0.00 3/1/2007. ~INTRM1 17:00 DRILL TRIP RIH from 2987 to 4000'. Worked.. 2.00 7,550.0 7,550.0 0.00 through 3220' - 3280'. 13/1/2007 INTRM1 19:00. DRILL CIRC Circ and cond mud 1.00 7,550.0 7,550.0 0.00 '3/1/2007 INTRM1 20:00 DRILL TRIP RIH from 4000'to 6400' 3.00 7,550.0 7,550.0 0.00 3/1/2007 INTRM1 23:00 'EVALFM DLOG Circ and cond mud. Start MAD pass 1.00 7,550.0 7,550.0 0.00 6400'. 3/2!2007 INTRMI 00:00 EVALFM DLOG Run MAD logs @300 ft/hr; 480 GPM; 3.00 7,550.0 7,622.0 72.00 90 RPM from 6400' to 6815' 3/2/2007 INTRM1 03:00 RIGMNT RGRP Work on service loop. 0.50 7,550.0 7,622.0 72..00 3/2/2007 INTRM1 03:30 EVALFM DLOG Continue MAD pass from 6815' to 4.50 7,550.0 7,622.0 72.00 7550' 3/2/2007 INTRM1 08:00. DRILL DRLG Drill from 7550'to 7596' 4.00 7,550.0 7,622.0 72.00 i Up wt: 150k Dwn wt: 155k Rot wt: 155k Rot tq: 850 ft-Ibs 3/2/2007 ' 1NTRM1 12:00 DRILL DRLG Drill from 7596' to 7622' 12.00 7,550.0 7,622.0 .72.00 3/3/2007 INTRM1 00:00 DRILL DRLG Drill from 7622' to 7630' 1.00 7,622.0 7,942.0 320.00 3/3/2007. INTRMI 01:00 DRILL CIRC Bit balling up, pump nut plug sweep: 0.50 7,622.0 7,942.0 320.00 3/3/2007 INTRM1 01:30 DRILL ( DRLG Drill from 7630' to 7701' 3.00 7,622.0 7,942.0 320.00 3/3/2007 INTRM1 04:30 DRILL DRLG Drill firom 7701' to 7718': Drilling with 1.50 7,622.0 7,942.0 320.00 #1 pump while working on #2. 3/3/2007 INTRMI 06:00 DRILL ( DRLG Drill from 7718'to 7792' 6.00 7,622.0 7,942.0 320.00 Up wt: 160k Dn wt: 162k Rt wt: 162k Rt tq: 3k 3/3/2007 INTRMI. 12:00 DRILL DRLG Drill 7792' to 7854' 3.50 7,622.0 7,942.0 320.00 3/3/2007 INTRM1 15:30 DRILL CIRC Circulate while tiying in Schlumberger 0.50 7,622.0 7,942.0 320.00 pump: Test lines to 4000 psi. 3/3/2007 INTRM1 16:00 DRILL DRLG Drill from 7854' to 7890'. Bit balling 2.00 7,622.0 7,942.0 320.00 problems, pump nut plug sweep.. 3/3/2007 INTRMI : 18:00 DRILL 1 DRLG Drill 7890' to 7923': Service 5.00 7,622.0 7,942.0 320.00 Schlumberger pump. 3/3/2007 INTRMI 23:00 DRILL. DRLG Drill from 7923' to 7942'. 1.00 7,622.0 7,942.0 320:00 Dn wt: 166k I ' ~ i 1 Up wt: 164k , ' Rt wt: 164k ~ Rt tq: 38k 1 3/4/2007 INTRM1 1 00:00 DRILL DRLG Dril17942°to8029' 4.50 7,942.0 8,100.01 158.00 3/4/2007 INTRM1 1 04:30 DRILL CIRC Circ BU for sam le ' 1.50 7,942.0 8,100.0 1 158.00 3/4!2007 ( INTRMI 06:00 ~ DRILL i DRLG ~ w/ T pump ~ Dri11 8029' to 8084 15.00 7,942A 8,100.0 158.00 Operations Summary NOATAK 1 Yag@ l3/l! rceNun nuncu. ai cicwi~ - ___ . _ __ _. -J • • / ~\ j IN I KM1 3/5/2007 3/5/2007 3/5/2007 3/5/2007 3/5!2007 3!5/2007 3/5/2007 3/5/2007 3/5/2007 3/5/2007 3/5/2007 3/5/2007 3/5/2007 3/6/2007 3/6/2007 3/6/2007 316/2007 3/6/2007 3/6/2007 3/6/2007 3/6/2007 3/7/2007 3/7/2007 3/7/2007 3/7/2007 3/7/2007 3/7/2007 3/7/2007 3/7/2007 INTRM1 INTRMI INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 I NTRM 1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 I NTRM 1 INTRM1 INTRM1 INTRM1 3/7/2007 3/7/2007 Operations Summary NOATAK 1 INTRM1 NTRM1 '1:00 I DRILL 2:30.- DRILL 10:00 ( DRILL X0:30 . DRILL 2:30 DRILL X3:30 DRILL X4:30 DRILL 5:00 DRILL 6:00 DRILL X7:30 DRILL 9:30 DRILL 0:30 DRILL 1:00 DRILL 3:30 DRILL 2:30 DRILL 0:00 DRILL 3:30 DRILL 4:00 DRILL 5:00 DRILL 6:00 DRILL 8:00 DRILL 0:00 WELCTL 1:30 CASING 4:00 CASING 0:00 CASING 0:30 CASING 0:00 CASING 3:00 CASING 4:30 CASING 6:30 CASING 12:00 CASING 14:30 CEMENT 17:00 CEMENT 17:30 CEMENT 19:30 CEMENT 3/8/2007 INTRMI 1,00:00 DRILL F~; -~ ~~~~ ~~ , UKLG ~ drill tsuu4 to t31uu. I ie in Schlumberger 1.50 7,94"L.0 8,100.0 158AU pump CIRC Circ BU for sample 1.50 7,942.0 8,1.00.0 1.58.00. OTHR Circ and run MADD pass 8084 to 8100' 0.50 . 8,100.0 8,148.0 48.00 CIRC Circ for samples 2.00 8,100.0 .8,148.0 48.00 DRLG dri118100'to8113' 1.00 8,100.0 8,148.0 48.00 CIRC- Circ for samples at 8113' 1.00 8,100.0 8,148.0 48.00 DRLG Dril18113'to8116' 0.50 8,100.0 8,148.0 48.00 CIRC Circ for samples at 8116' 1.00 8,100.0 8,148.0 48.00 DRLG Dril18116'to8148' 1.50 . 8,100.0 8,148.0 48.00 CIRC Circ for samples and condition mud 2.00 8,100.0 8,148.0 . 48.00 WPRT POOH 8148 to 7550' 1.00 8,100.0 8,148.0 48.00 WPRT RIH from 7550'to 8148` 0.50 8,100.0 8,148.0 48.00 CIRC Circ and condition mud to run csg. 2.50 8,100.0 8,148.0 48.00 TRIP POOH8148 to470 9.00 8,100.0 .8,148.0 .00 4 TRIP LD BHA , Dn load logging tools 1.50 8,100.0 8,148.0 48.00 TRIP POOH. LD drill collars. 3.50 8,148.0 8,148.0 .0.00 PULD LD MWD Batt sonic tool and remove 0.50 8,148.0 8,148.0 0.00 radioactive source. PULD Download information from MWD: 1..00 8,148.0 8,148.0 0.00. PULD Make breaks and pull TM tool from 1.00 8,148.0 8,148.0 0.00 MWD PULD Finish LD MWD tools 2.00 8,148.0 8,148.0 0.00 OTHR Change rams to 7" for casing job: Pull 2.00 8,148.0 8,148.0 0.00 wear ring BOPS Test Door Seals 250/2500 psi. 1.50 8;148.0. 8,148.0 0.00 RURD RU bail extensions, elevators, casing 2.50 8,148.0 8,148.0 0.00 tongs. RNCS Run 7" 26# L-80 BTCM to 2987. 6.00 8,148.0 8,148:0 0.00 CIRC Break circulation and condition mud 0.50 8,148.0 . 8,148.0 0.00 RNCS Run casing from 2987 to 5492' 3.50 8,1.48.0 8,148.0 . 0.00 RNCS Run 7" casing from 5942' to 7000'. 3.00 8,148.0 8,148.0 0.00 CIRC Circulate and condition mud. 1.50 8,148.0 8,148.0 0.00 RNCS. Run casing from 7000' to 8085'. 2.00 8,148.0 8,148.0 0.00 RNCS Wash to bottom from 8085'to 8148'. 5.50 8,148.0 8,148.0 0.00 Up wE: 194k Dn wt: 188k RNCS. Space out 7" casing. MU casing 2.50 8,148.0 8,148.0 0.00 hanger and make up cementing head. CIRC Circulate and condition mud. 2.50 8,148.0 8,148.0 0.00 DISP ( Batch up cement, test lines to 2500 psi. 0.50 8,148.0 .8.,148.0 0.00 DISP Dowell pumped: 2.00 8;148.0 8,148.0 0.00 10 bbl CW100 ~ Dropped bottom plug i 20 bbl Mud Push. II 37 bbls cement Dropped top blog 20 bbl chase water. The rig pump was used for displacement and the plug bumped on strokes. 8 ' ' 'ULD Wash up and clear rig floor of 2.50 8,148.0 8,148.0 -0.00 cementing equipment. NOC WOC. Drain stack and flush with 2.00 .8,148.0 8,148.0' . 0.00 water. Vac cellar dry. MU running tool and install packoff. ' DTHR FMC Test packoff to 5000 psi for 10 L 1.00 8,148.0 8,148.0 0.00 ~ min. Test OK, Page 14/17 Rep ort Printed : 5/2/2007 • /~ ~\ a i 3/8/200/ IN I RM1 01:00 WELCTL 'OTHR 'Change rams. Remove 7" casing 1.00 8,148.0 8,148.0 .0.01 I rams, install 4" pipe rams. 3/8/2007 INTRM1 02:00 WELCTL BOPE Test top rams, check valve, safety 4.00 : :8;148.0 8,148A 0.0( valve, outside kill, Top drive hyd, HydriL 3/8/2007 INTRM1 '06:00 WELCTL ROPE Test 250/5000 psi, Top drive manual, 2.50 8,148.0 8,148.0 0.0( choke line manual. inside kill, HCR, Dart valve. 13/8/2007 INTRM1 08:30. WELCTL BOPE Repair leak on choke manifold. 1.50 8,148.0 8,148.0 0.0( 3/8/2007 INTRM1 10:00 WELCTL BOPE Test choke manifold valves, blind 2.00 8,148.0 8,148.0 0.0( rams, perform Koomey test. Assist Schlumberger with injection test on annulus. Pull test plug 3/8/2007 INTRM1 112'00 DRILL RURD Set wear ring, LDtestjoint RD 3.00 8,148.0 . $148.0 0.0( Schlumberger testing lines, reinstall I 1 mouse hole. 3/8/2007 PROD1 15:00 DRILL PULD. PU BHA and upload smart tools and 5.00 8,148.0 8,148.0 0.0( ~ Nukes 3/8/2007 PROD1 20:00 DRILL PULD... Trace out ice plug in mud line and top 4.00 8,148.0 :8,148.0 0.0C drive. Thaw. 3/9/2007 PROD1 00:00 DRILL PULD Load MWD radioactive source, test 1.00 8,148.0 8,148.0 O.OC MWD, blow down top drive. 3/9/2007 PROD1 01:00 DRILL PULD PU and RIH w/ flex collars, jars, 4.00 8,148.0 8,148.0 O.OC HWDP. Change elevators. 3/9/2007 PROD1 05:00 DRILL TRIP RIH from 915' to 8033' 6.50 8,148.0 8,148.0 O.OC 3/9/2007 PROD1 11:30 RIGMNT OTHR Lubricate rig 1.50 8,148.0 8,148.0 O:OC 3/9/2007 PROD1 13:00 DRILL CIRC Circulate and condition mud. 1.00 8,148.0 8,148.0 O.OC 3/9/2007 PROD1 14:00 RIGMNT OTHR Blow down, hang blocks, slip and cut 3.00 8,148.0 : ..8,148.0 O.OC 120' of drilling line. 3/9/2007 PROD1 17:00 DRILL OTHR Tesf 7" casing to 2500 psi for 30 min. 1.50 8,148.0 8,148.0 0.00 3/9/2007 PROD1 18:30 RIGMNT RURD Test #2 mud pump afetr installing new 4.50 8,148.0 .8,148.0 0.00 motor. Knocked all three generators off line. 3/9/2007 PROD1 23:00 DRILL DRLG Drill out cement from 8060' (FC) to 1.00 8,148.0 .8,148.0 . 0.00 8074'. Cement was soft. 3/10/2007 PROD1 00:00 DRILL Drill cement from8074'to8143' 1.50 8,148.(1 8,148.0 0.00 3/10/2007. PROD1 01:30. DRILL Test shoe to 500 psi 12.4 ppg EMW: 0.50 8,148.0 8,148.0 0.00 3/10/2007 PROD1 02:00 DRILL CIRC Circulate and condition mud. Swap but 2.00 8,148.0 8,148.0 0.00 mud. 3/10/2007 ~ PROD1 04:00 DRILL DRLG Drill from 8143'to 8191' 5.00 8,148.0 8,148.0 0.00 3/10/2007 ~ PROD1 09:00 DRILL CIRC Monitor well. Fluid loss, mix and pump 2.00 8,148.0 8,148.0 0.00 LCM, build volume. 3/10/2007 PROD1 11:00 DRILL DRLG Drill from 8191' to 8225'. Fluid loss 1.00 8,148.0 8,148.0 0.00 151 bbls. 3/10/2007. PROD1 12:00 DRILL CIRC Condition mud and circulate. Pump 5.00 .8,148.0 8,148.0 0.00 LCM and build volume. 3/10/2007 ' PROD1 ~ 17:00 DRILL DRLG Drill from 8225' to 8287 2.00 8,148.0 8,148.0 0.00 3/10/2007 PROD1 19:00 DRILL CIRC Condition mud. Circulate and build 4.00 8,148.0 8,148.0 0.00 volume. 3/10/2007 PROD1 23:00 DRILL ~ DRLG Drill from 8287 to 8313' 1.00 ..8,148.0 8,148.0 0.00 ~ I Up wt: 120k Dn wt: 126k j Rot wt: 128k - 1 13/11/2007 PROD1 00:00 DRILL CIRC Condition mud and circulate. Build ~ 2.00 8,425.0 8,425.0 0.00 I volume. Losses = 64 bbls/hour 3!11/2007 ~ PROD1 1 02:00 ' DRILL OTHR Daylight saving time adjustment. 1.00 8,425.0 8,425.0 O.OOi 3/11/2007 i PROD1 1 03:00 DRILL ' DRLG ~ Drillfrom8313'to8358°. Circulate out 3.00 8,425.0 8,425.0 O.OOj ~ ~ ~ ( connection gas. Page 15/17 Report Printed: 5/2/2007 Operations Summary NOATAK 1 / ~~ i~ } I 1 i ,~~~_ 3/11/20U/ PRUD1 X06:00 (DRILL 3/11/2007 PROD1 09:30 DRILL 3/11/2007 PROD1 11:00DRILL 3/11/2007 PROD1 13:00 DRILL 3/11/2007 PROD1 14:00 DRILL 3/11/2007 IPROD1 16:00 'DRILL 3/12/2007 'PROD1 00:00 DRILL 3/12/2007 PROD1 X01:00 DRILL 3/12/2007 PROD1 04:00 DRILL 3/12!2007 PROD1 05:30 DRILL 3/12/2007 PROD1 18:00 DRILL 3/12/2007 PROD1 19:30 DRILL 3/12/2007 jPROD1 22:30 DRILL 3/13/2007 PROD1 00:00 EVALFM 3/13/2007 PROD1 04:30. EVALFM 3/13/2007 PROD1 06:00 EVALFM 3/13/2007 PROD1 09:00 EVALFM 3/13/2007 PROD1 10:30 EVALFM 9!13/2007 PROD1 16:30 EVALFM 1/13/2007 PROD1 18:00 EVALFM (/13/2007 PROD1 22:00 DRILL N14/2007 PROD1 00:00 PLUG V14/2007 PROD1 D8:00 PLUG J14/2007 ~PROD1 X09:30 CEMENT DRLG Drill from 8358' to TD at 8425'. CIRC Condition mud and circulate. OTHR MAD pass from 8280' to 8356' CIRC RIH from 8356'to 8410'. Troubleshoot MWD. OTHR MAD pass from 8410' to 8349' CIRC Condition mud and circulate. Build volume. Losses = 30 bbl/hour. CIRC Circ and condition mud. Build mud volume. Losses =38 bbl/hour. CIRC Circulate and condition mud. Continue to build volume. Spot LCM pill OWFF Shut pumps off. Monitor well on trip tank. OK TRIP POOH from 8349' to 70T PULD Lay down jars and flex collars PULD Download MWD, continue LD BHA. RURD Rig up Schlumberger a-line unit. TRIP RIH & perform dipole sonic/gamma ray log. PULD Laydown dipole sonic/GR. Pick up platform express/AIT. TRIP RIH & perform platform express/AIT log. PULD Laydown platform express/AIT. Pickup rotary sidewall core tool. TRIP RIH & take sidewall cores as directed from Anchorage. PULD Laydown logging equipment & clear tools from pipe shed. MOOR Wait on orders. DRIP RIH w/ 7" Baker cement retainer, x-over, 4" DP to 565'. TRIP TIH with retainer from 565' to 8034'. ~THR Set Baker Model K-1 cement retainer at 8034'. Pressure test annulus & retainer to 1500psi -held solid. Test witnessed by Tim Lawlor, BLM. Left the 1500psi on annulus for cementjob. SURD ~ Rig up Schlumberger cement unit.. 3.50 ., 8,425.0 8,4"LS.I) 1,50 8,425.0 .8,425.0 2.00 8,425.0 8,425:0 . 1.00 8,425.0 8,425.0 2.00 8,425.0 8,425.0 8.00 8,425.0 8,425.0 ~ 1.00 . 8,425.0 8,425.0 ~ 3.00 .8,425.0 8;425.0 i 1.50 8,425.0 8;425.0 I 12.50 8,425.0 8;425.0 I 1.50 8,425.0 8,425.0 I 3.00 8,425.0 8,425.0 I 1.50 8, 425.0 .8,425.0 I 4.50 8,425.0 8,425.0 1 1.50 8,425.0 8,425.0 3.00 8,425.0 8,425.0 1.50 8,425.0 8,425.0 6.00 8,425.0 8,425.0 1.50 8,425.0 8,425.0 4.00 8,425.0 8,425.0 2.00 8,425A 8,425.0 C 8.00 8,425.0 8,425.0 1.50 8,425.0 8,425.0 2.50 8,425.0 8,425.0 C ~I Page 16/17 Report Printed: 5/2/2007( Operations Summary NOATAK 1 % ~ ~\ i 3/14/ZUU/ PKVU'I 1L:UU GtIV1tN I (J I HR Pressure test surtace equipment to 4.50 8,4Z5.U ti,4Z5.U U.OI 3500psi. Conduct infectivity test into open hole below retainer. Pump 5bbl fresh water @ 2.Obpm @ 425psi. Mix ' "G" blend cement up at 15.8ppg. Start pumping cement @ 2.2bpm @ 475psi. Pumped 19bb1 cement, finished pumping with 60psi. Switched over & pumped 5.1 bbl fresh water @ 2.2bpm. Shut down and switch over to rig pump. Displace cement with fresh (water @ 2bpm and pumped 76bb1 leaving 4 bbl cement in DP. Sting ouf of retainer, dumping 4bbl/100ft of j cement on top of retainer. POOH & I laydown 7 joints, leaving stinger at 7820' or 214' above retainer. Break circulation. Circulate 2 BU's, (some LCM, very little cement, no gas). Cement job witnessed by Tim Lawlor, i BLM. 3!14/2007 PROD1 16:30 PLUG TRIP POOH laying down DP. 5.00 8,425.0 8,425.0 O.OC 3/14/2007 PROD1 21:30. RIGMNT OTHR Service pipe skate. 1.00 8,425.0 ' 8,425.0 ` O.OC 3/14/2007 PROD1 22:30 PLUG TRIP Continue laying down DP. 1.50 .8,425.0 8,425.0 O.OC 3/15/2007 PROD1 00:00 PLUG TRIP Finish POOH & laying down DP. 3.50 8,425.0 8,425.0 0.00 3/15!2007 PROD1 03:30 PLUG CIRC Pull wear ring. Rig up & pump 26bb1 1.50 8,425.0 8,425.0 0.00 mud down 7" casing. Pump 10bbls high vis pill 3/15/2007 PROD1 05:00 MOVE RURD Clean pits. Rig up to inject & work on 1.00 8,425.0 8,425.0 0.00 clearing floor. 3/15/2007 PROD1 06:00 MOVE RURD Continue cleaning floor, pits, shakers & 6.00 8,425.0 8,425.0 0.00 cellar. Blow down choke, kill line. 3/15/2007 PROD1 12:00 MOVE - RURD Continue cleaning pits. Start rigging 6.00 8,425.0 8,425.0 0,00 down pipe shed. Emptied out all I upright tanks, (tagged bottom of tanks - dry) 3/15/2007 PROD1 18:00 MOVE RURD Inject a total of 795bb1s down 9-5/$" x 6.00 8,425.0 8,425:0 0.00 7" annulus. Finish cleaning pits. 3/16/2007. PROD1 00:00 MOVE RURD Suck out water tank. for cement. 1.00 8;425.0 8,425.0 0.00 3/16/2007' PROD1 01:00 CEMENT PLUG. Mix remainder of "G" blend cement up 2.00 8,425.0. 8,425.0 . 0.00 at 15.9ppg. Start pumping "G" cement @ 2.Obpm @ 825psi. Pumped 21bbls "G" cement down annulus (745' annular length}. Mix up Arctic Set cement @ 15.8ppg. Pump @ 2bpm, 29bbls down annulus, (1028' annular length). Total cement column in 9-5/8" x 7" annulus of 1773ft. Shut down. Rig to pump down 7" intermediate casing. I Mix up Arctic Set cement @ 15.8ppg. i Pump 12bbis cement @ 0.5bpm down 7" intermediate casing until we got ~ cement to surface, (313' cement plug). , , ~ Note: See Wellview Schematic. ~ I j i Rig Release 03:00, 03/16/07 I --i Page 17/17 Report Printed: 5/2/2007( Operations Summary NOATAK 1 Noatak # 1 Well Status As of 4/5/07 Noatak #1 Spudded we112/10/07. Drilled 12-1/4" surface hole to 3000' MD/TVD. Correlation to Kokoda #5 was approx. 150' to 200' deeper than expected. Made wiper trip. Ran 9-5/8" 40 ppf L-80 casing to 2987" MD/TVD. Reciprocated pipe. and conditioned hole for 6:5 hrs. Landed 9-5/8" and RIH with 4" DP for stab-in cement job. Pumped 50 bbl of CWI00 plus 50 bbl of weighted Mud Push followed by 167 bbl of AS LITE plus 40 bbl of LiteCRETE. Full returns throughout job with 10.7 ppg cement back to surface. Cement job observed by BLM representative. Completed testing of the BOPE stack, tested casing to 3000 psi and 2500 psi- OK, drilled shoe track and 20' of new hole to 3020' MD/TVD. Performed FIT to 18.2 ppg EMW. Drilled 8-3/4" hole to 7550'. POOH for rotary BHA. Tested BOPEs. Drilled to 8148' MD/TVD- intermediate casing point just above the Jurassic interval Made wiper trip. Ran and cemented 7".casing to 8146' MD/TVD .with 37 bbls of 15.8 ppg Class G cement with additives. Full returns throughout job with plug bumped on strokes. Tested BOPE's. PU BHA and RIH to 8033' MD/TVD. Tested 7" to 2500 psi for 30 minutes-OK. Drill shoe track to 8143' MD/TVD- tested to 12.4 ppg EMW-OK. Drilled 6-1/8" hole to 8425' MD/TVD- TD. Experienced 30 to 50 bph mud losses starting at 8191.' MD/TVD while drilling. No losses while static, Spotted- 30 ppb LCM pill on bottom. RU SWS. Ran dipole sonic/platform express/rotary sidewalk. RD SWS. P&A'd wellbore per Agencies approvals. Rig released 0300 hrs on 3/16/07. Began 'moving rig to Intrepid. Finished the surface P&A on 3/29/07. REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 1/30/07 RLS AJR Drawn Per K07018ACS NOTES: N 1. COORDINATES OBTAINED BY GPS RAPID STATIC BEAUFORT SEA METHODOLOGY, USING LEICA SERIES 500 RECEIVERS.. Bn~ow •~~ DATA PROCESSED BY NATIONAL GEODETIC SURVEY "ON-LINE POSITIONING USER SERVICE" (OPUS), ~~ RESOLVED FROM THE FOLLOWING BASE STATIONS: ~~'~ HARRisoN BAY A. PBOC (PRUDHOE BAY CORS) T hek uk PRUDHOE BAY . ~~ es B. -FAIR (GILMORE CREEK OBS CORS}' Lake ~' ' ~. C. CENA (CENTRAL ALASKA CORS) o~ P DEADHORSE { - -`'~ 2. HORIZONTAL DATUM (S NAD83, ZONE 5, ALASKA. ~ NPRA W ~~~~ 3. VERTICAL DATUM IS ORTHOMETRIC REFERENCED NoaTAK i ~ `~ TO GEOID 99, ADJUSTED TO B.P.M.S.L. ~ "~ > ~ ANWR ~ 4. ALL DISTANCES ARE TRUE, ec RAJ ~ Colville ~ ° v a, v, c v c 16 15 o 21 22 N ~ U VICINITY MAP NOT TO SCALE N ~~ NOATAK- #1 LOCATED WITHIN PROTR-ACTED SCALE: ag ' E ' N~o " SEC. 22, T 12 N, R 5 W, 1 = 200 UMIAT MERIDIAN. ~~ - 2504' F.N.L., 1932' F.W.L. 1932' TAB ~oP ~, LAT = 70'22'46.895" °~ LONG = 153'0759.007" wa. PT:. `"-`i. Y = 5,989,075.90' X 1,747,038.19'. GROUND ELEVATION = 103.0' oa ~~S ~, ` e ~'"~ R 9 TOP OF RIG -PAD= 103.9' ~: EwS~NG AGE P Ao 0 0 f ~ p E ~~ • ~ ' •~ ~ 2g9 ~. Y 0 I ~ ~ ®, s ~ ;~ : AS STAKED , ~ ....:......... .............:..... ~ h~ VIBRATION POINT e . ~ . LAT = 70'22'46.854" .,........ ... . .... ....... :..... s u+, J., ROOKUS = o i j'? °o ~ LONG = 153'0750-._229" ` 1 s ~ aoa ~ ~r ~ _ 5,989,076.0' Y ' I~~~Fop,.~.~,~Q.~~ `~+i ~ 6a ' ~,. a X = 1,747,338.1 . ~,® tit iw~~°~~o` e 0 SURVEYOR'S CERTIFICATE ~~ I HEREBY CERTIFY .THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND, SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY LOUNSBURY- DONE BY ME OR UNDER MY DIRECT SUPERVISION AND & ASSOC3ATE3 INC. THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT , oxs arrGU+rsx6 PLANNERS AS OF JANUARY 24, 2007. ,~ ll,./ AREA: XX MODULE:XXXX UNIT: M1 oc Philli Co NOATAKI n ps o EXPLORATORY WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD F!!.E N0. LKSO1DSa6 1 2s o7 DRAWING N0: CEA-M1 XX-601 D686 PART: 1 of 1 REV: 1 Halliburton Company Survey Report ( nmpan~ h;noc>Pl~,illips ;laeka Inc. I)atr_ 4!13`007 Ifnu ~)9.5?49 P~i,c: I~icld: ASP Z~~ne 5 (Nf RA Cxpl ~i3tion? ( ~~~-unliuatel~l'.J I:cfcrcnrc: ~,'J-~11 Nodtah~l . Trua NOr(h ~itc: N, a(3k ~ crlical lllU)Rcferrnrc Nu a3k#1 123. 5 V1cll~ fJ ~;iS~:k#1 ti cclimi 151 k~l ircncc' :~~~ i'J.!!(iM i) O OE.~124~!~~~~) 1\cllpaih: N!~2t~+k~1 S urcc} <alculati ou ~lcthod: f~iir,inui[n CUNd IUf? I)h: GrB~'le Field: ASP Zone 5 (NPRA Exploration) Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 5 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level L Geomagnefic Model bg gm2006 ~ - -- _ Well: Noatak#1 _ Slot Name: Well Position: +N/-S 0.00 ft Northing: 5989361.00 ft Latitude: 70 22 48.271 N +E/-W 0.00 ft Easti ng : 60701 9.37 ft Longitude: 153 7 47.440 W Position Uncertainty: 0.00 ft Wellpath: Noatak#1 Drilled From: Well Ref. Point 50279200 1300 Tie-on Depth: 19.50 ft Current Datum: Noatak#1: Height 123.50 ft Above System Datum: Mean Sea Level Magnetic Data: 2/8/2007 Declination: 21.79 deg Field Strength: 57477 nT Mag Dip Angle: 80.50 deg Vertical Section: Depth From (T'VD) +N/-S +E/-W Di rection ft ft ft deg 19.50 0.00 0.00 312.49 r Survey Program for Definitive Wellpath Date: '"2/8/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 132.13 8326.07 Noatak#1 (132.13-8326.07) MWD MWD - Standard Survey ~IJ) lncl ~zini IlU ~}.l~ll \rti' EVE ~iap~ ~lapl: l~uul f. deg deg ft ft ft ft d ft 19.50 0.00 0.00 19.50 -104.00 0.00 0.00 5989361.00. 607019.37. • TIE LINE 132.13 0.06 105.79 132.13 8.63 -0.02 0.06 5989360.98 607019.43 MWD 220.13 0.19 314.99 220.13 96.63 0.07 0.00 5989361.07 607019.37 MWD I 315.13 0.44 340.02 315.13 191.63 0.53 -0.24 5989361.53 607019.12 MWD 407.65 0.50 329.68 407.65 284.15 1.21 -0.56 5989362.20 607018.79 " MWD 528.48 0.40 306.43 528.47 404.97 1.92 -1.17 5989362.90 607018.17 MWD 715.93 0.37 345.63 715.92 592.42 2.89 -1.85 5989363.86 607017.48 MWD 901.75 0.40 13.25 901.73 778.23 4.10 -1.85 5989365.08 607017.47 MWD 1083.08 0.26 338.66 1083.06 959.56 5.10 -1.85 5989366.08 607017.45 MWD 1277.84 0.38 1.66 1277.82 1154.32 6.16 -1.99 5989367.13 60701729 MWD 1461.68 0.31 345.00 1461.65 1338.15 7.25 -2.10 5989368.22. 607017.16 MWD 1650.28 0.56 349.96 1650.25 1526.75 8.65 -2.40 5989369.61 607016.85 MWD 1906.09 0.14 342.00 1906.05 1782.55 10.18 -2.71. 5989371.14 607016.5T' MWD 2041.07 0.09 204.38 2041.03 1917.53 1024 -2.81. 5989371.20 607016.42- MWD 2215.43 0.06 195.79 2215.39 2091.89 10.03 -2.89 5989370.98 6070Y6.34 MWD 2405.08 0.06 89.06 2405.04 2281.54 9.93 -2.81 5989370.89 607016.4T MWD 2595.64 0.06 177.71 2595.60 2472.10 9.83 -2.71 5989370.79 607016.52 MWD 2781.77 0.09 184.48 2781.73 . 2658.23 9.59 -2.72 5989370.55 607016.51 MWD 2920.21 0.14 76.36 2920.17 2796.67 9.52 -2.56 5989370.48 607016.67 MWD 3027.23 0.36 2.82 3027.19 2903.69 9.89 -2.42 5989370.85 607016.81 MWD 3149.85 0.31 357.44 3149.81. 3026.31 10.61 -2.41 5989371.57' 607016.80. MWD 3275.36.. 0.19 358.64 3275.32 3151.82 11.15 -2.43 5989372.12 607016.78 MWD 3400.00 0.20 9.17 3399.96 3276.46 11.57 -2.41 5989372.54 60701.6.80 MWD 3528.15 0.28 24.73 3528.11 3404.61. 12.08 -2.24 5989373.05 607016.96 MWD 3652.89 0.12 20.82 3652.85 3529.35 12.48 -2.06 5989373.45 607017.13 MWD' ~ 3779.36 0.09 54.62 3779.32 3655.82 12.66 -1.94 5989373.63 607017.25. MWD ' 3904.56 0.20 299.16 3904.52 3781.02 12.82 -2.05 5989373.79 607017.14 MWD 4030.38 0.33 292.13 4030.33 3906.83 13.07 -2.57 5989374.03 607016.61 MWD 4154.89 0.51 301.68 4154.84 4031.34 13.49 -3.38 5989374.44 607015.80 MWD 4276.48 0.68 278.80 4276.42 4152.92 13.89 -4.55 5989374.82. 607014.62 MWD Halliburton Company Survey Report <<,~~,,,:~~~~ ~< <~~~~,~n~u;i~~„a~z~~_ai~,.- n:u~: a; T;;~aoo~ r..„~ ~JJ:.`r2.49 r:~~,~: hicl~l: S P ~ n' 5 i NFF:^~. Exp ln[3tionj Cb-~~ nliuatcl~l:i kcfcri~ncc: ~'.'cll: f~o'3f3k41 TfU? North ~itc: ^.n ~3iak ~ crti c;il (CAl)1 k cfcreni-~~: ~J~atak~l 1 23. 5 1~cU: 6J at3k~l ~rcLi nn ~~~~~ Ri~f~ •rcncc: '."Jell i0 ((i~J ~J.O OE 12.49;"1Zii \Fcll~~ath_ fJ~ ~tHk~l ~urc c~ (~alculali on ~IcUuul: ~:1inimum Curva ture I)h_ O~ade tiuiti~~~ \lU Incl ~iim l ~I) ~~~ C~I1 \;ti i.'\1 ~la~iA ~lapl l uol ft ieg d~;g fl a tt ft ft 4404.79 0.86 275.15 4404.72 4281.22 14.09 -6.26 5989375.00 607012.91 MWD 4531.86 0.89 275.46 4531.78 4408.28 14.27 -8.20 5989375.15 607010.97 MWD 4656.13 0.94 278.70 4656.03 4532.53 14.52 -10.16 5989375.37 607009.00 MWD 4782.09 0.99 283.00 4781.97 4658.47 14.92 -12.25 5989375.74 607006.91 MWD 4908.96 1:18 296.19 4908.82 4785.32 15.74 -14:49 5989376.53 607004.66 MWD 5034.65 1.42 284.06 5034.48 4910.98 16.69 -17.16 5989377.44 607001.98 MWD 5158.50 1.53. 281.05 5158.29 5034.79 17.38 -20.27- 5989378.09 606998.86 MWD 5284.87 1.61 286.65 5284.61 5161.11 18.21 -23.63 5989378.87 606995.49 MWD 5410.66 1.44 280.72 5410.36 5286.86 19.01 -26.87 5989379.62 606992.23 MWD 5536.09 1.37 285.42 5535.75 5412.25 19.70 -29.87 5989380.27 606989.23 MWD 5661.02 1.23 290.13 5660.65 5537.15 20.56 -32.56 5989381.09 606986.52 MWD 5787.07 1.20 289.28 . 5786.67 5663.17 21.46 -35:08 5989381.96 .606983.99 MWD 5913.55 1.08. 298.95 5913.12 5789.62 22.48 -37.37 5989382.94 606981.68 MWD 6038.45 1.02 297.50 6038.00 5914.50 23.56 -39.39 5989383.99 606979.65 MWD 6163.84 0.83 307.09 6163.38 6039.88 24.62 -41,10 5989385.03 606977.92 MWD 6288.71 0:50 303.54 6288.24 6164.74 25.47 -42:28 5989385.86: ' 606976.73 MWD 6413.88 0.70 320.94 6413.40 6289.90 26.37 -43.22 5989386.74 606975.78 MWD 6540.03 0.94 323.21 6539.54 6416.04 27.79 -44.32 5989388.15 606974.66 MWD 6668.80 0.66 337.11 6668.30 6544.80 29.32 -45.24 5989389.67 606973.72 ` MWD 6730.74 0.53 343.86 6730.23 6606.73 29.93 -45.46 . 5989390.27 606973.49 MWD 6978.60 0.22 335.98 6978.09 6854.59 31.46 -45.97 5989391.80 606972.96 MWD 7229.96 0.28 19.63 7229.44 7105.94 32.48 -45:96 5989392.82 606972.95 MWD '~, 7482.98 0.20 342.21 7482.46 .7358.96 33.48 -45.89 5989393.82 606973.01 MWD 7608.93 0.57 6.13 7608.41 7484.91 34.32 -45.89 5989394.65 606973.00 MWD 7734.82 0.64 4.16. 7734.29 7610.79 35.64 -45.77 5989395.98. 606973.10 MWD 7923.47 0.67 4.04 7922.93 7799.43 37.79 -45.62 "~ 5989398.13 606973.22 MWD 7986.75 0.62 6.35 ..7986.21 7862.71 38.50 -45.56 5989398.84 606973.27 MWD 8081.08 0.50 8.10 8080.53 7957.03 39.41 -45.44 5989399.76 606973.37 MWD 8198.44 0.31 6.98 8197.89 8074.39 40.24 -45.33 5989400.58 606973.47 MWD 8232.53 0:36 8:67. 8231.98 8108.48 40.43 -45.30 5989400:78. 606973.50 MWD 8326.07 0.31 355.89. 8325.52 8202.02 40.98 -45.28 5989401.32 606973.52 MWD • 8425.00 0.31 355.89 8424.44. 8300.94 41:51 -45.31 5989401.86 606973.47 PROJECTED to TD • ~+C11'1C~~~"~1~~1 Alaska, Inc. Date: April 26, 2007 Subject: Noatak Formation Tops From/Location: Greg Wilson Staff Geologist ConocoPhillips Alaska, Inc. Telephone: 263-4748 To/Location: Noatak Operations File CONFIDENTIAL The following are formation tops for Noatak 1 as picked from MWD and wireline logs: Formation, Marker, or Casing Shoe Measured Depth (MD) Colville Group Formation below surface surficial deposits Base Permafrost (ice-bearing) 870' MD Surface Casing 2987' MD Top Nanushuk Group 1395' MD Top Torok 3566' MD Top HRZ 7389' MD Lower Cretaceous Unconformity (LCU) 7643' MD Top Miluveach 7643' MD Topset Casing 8146' MD Top Jurassic 8131' MD Top Alpine Ss 8187' MD Upper Jurassic Unconformity (UJU) 8323' MD Kingak 8425' MD • ~~Ir1G1C+G~11~~1 S ~' TRANSMITTAL CONFJDENTIAL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`" Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Noatak 1 Permit: 205-042 DATE: 04/09/2007 NPRA, North Slope, Alaska Noatak 1 502792001300 Schlumberger CDROM DSI/Field DLIS/Field PDS/Final PDS; Final LDWG Edit; includes AIT/PEX/MSCT; Log date - 3/13/2007 Job 11628982 Schlumberger color log prints Mechanical Sidewall Coring tool, run 1; 3113/2007, 8173-8306' and PEX: AIT-H-TLD-DNL-GR-Microlog, run 1; 3/13/2007, 8000-8426' and Dipole Sonic Imager; compressional and shear/, run 1; 3/13/2007, 7160-8426' and BestDT* Processed results: Custom Sonic relabeling, processed 3/29/2007; Job 11628981 Please check off each item as received, promptly sign and return the transmittal to address below. To a//data recipients.' AI/data is confidential unti/State ofAlaska date CC: Andy reo CAI Geologist R EG E I VE D Receipt: Date: Alaska Oil & Gas Con ~ ~ i ,~~ SIS-Technical Data Management ~~~,~?hi~ips~,~r~c~orage, Alaska I Ph.' 9D7.26S.6947 Sandra,D,Lemk~Ca~Conoec~ophillips com ~Y"" r ~ Noatak # 1 Well Status As of 4/5/07 ~~ ~" ©~ Noatak #1 Spudded we112/10/07. Drilled 12-1/4" surface hole to 3000' MD/TVD. Correlation to Kokoda #5 was approx. 150' to 200' deeper than expected. Made wiper trip. Ran 9-5/$" 40 ppf L-80 casing to 2987" MD/TVD~Reciprocated pipe and conditioned hole for 6.5 hrs. Landed 9-5/8" and RIH with 4" DP for stab-in cement job. Pumped 50 bbl of CW 100 plus 50 bbl of weighted Mud Push followed by 167 bbl of AS LITE plus 40 bbl of LiteCRETE. Full returns throughout job with 10.7 ppg cement back to surface. Cement job observed by BLM representative. Completed testing of the BOPE stack, tested casing to 3000 psi and 2500 psi- OK, drilled shoe track and 20' of new hole to 3020' MD/TVD. Performed FIT to 18.2 ppg EMW. Drilled 8-3/4" hole to 7550'tPOOH for rotary BHA. Tested BOPEs. Drilled to 8148' MD/TVD- intermediate casing point just above the Jurassic interval. Made wiper trip.f Ran and cemented 7" casing to 8146' MD/TVD with 37 bbls of 15.8 ppg Class G cement with additives. Full returns throughout job with plug bumped on strokes. Tested BOPE's. PU BHA and RIH to 8033' MD/TVD. Tested 7" to 2500 psi for 30 minutes-OK. Drill shoe track to 8143' MD/TVD- tested to 12.4 ppg EMW-OK. Drilled 6-1/8" hole to 8425' MD/TVD- TD. Experienced 30 to 50 bph mud losses starting at 8191' MD/TVD while drilling. No losses while static. Spotted 30 ppb LCM pill on bottom. RU SWS~Ran dipole sonic/platform express/rotary sidewalk. RD SWS. P&A'd wellbore per Agencies approvals. Rig released 0300 hrs on 3/16/07. Began moving rig to Intrepid. Finished the surface P&A on 3/29/07. Re: FW: Noatak/Intrepid Weekly Report Subject: Re: FW: Noatak/Intrepid Weekly Report From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, OS Apr 2007 14:18:52 -0800 To: "Brasfield, Tom J" <TOM.J.Brassfield@canoeophillips.corn> got 3 messages and photos Brasfield, Tom J wrote, On 4/5/2007 2:04 PM: Tom/Greg, you should have received a fatal of 6 photographs? Thanks, Tom «6 Noatak cmt in stub.jpg» «9 Noatak top plugs in place.jpg» -----Original Message---- From: Brassfield, Tom J Sent: Thursday, April 05, 2007 2:00 PM To: tom maunder@admin.state.ak.us; area _noble@ak.blm.gov Cc: Hayden, Philip; Alvord, Chip Subject: F1N: Noatak/Intrepid Weekly Report Well, guess this didn't make it! Will try again. Thanks, Tom -----Original Message---- From: Brassfield, Tom J Sent: Thursday, April 05, 2007 1:54 PM To: tom maunder@adminstate.ak.us; area noble@ak.blm.aov Cc: Hayden, Philip; Alvord, Chip Subject: Noatak/Intrepid Weekly Report aos-o~.~ Tom/Greg, know we have had discussions regarding the Noatak P&A since the last weekly update; but here is our current status this afternoon. Attached are the P&A photographs taken at Noatak. We are still moving bits and pieces from the Noatak location back to 2P Pad, but expect to RD the Canning River camp tomorrow and hopefully complete the demob by Monday 4/9/07. 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AK. 99501 2791433 OPERATOR: CPAI SAMPLE TYPE: DRIES SAMPLES SENT: NOATAK 1 I a, a ''" 120-8425 DATE: MARCH 28, 2007 AIR BILL: ~S CPBV: 07-03-28-09 CHARGE CODE: 10148733 NAME: NOATAK 1 NUMBER OF BOXES: 1 BUNDLE SENTRY: M. McCRACKEN UPON RECEIPT OF THESE SAMPLES. PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: PHILLIPS BAYVIEW GEOLOGICAL FACILITY 619 EAST SHIP CREEK AVE SUITE 102 ANCHORAGE, AK. 99510 ATTN: DAN PRZYWOJSKI ABV100 RECEIVED: ~~(Wh~-~ V f~~dl ~ a ~~ Re: Drill Notification r~ Subject: Re: Drill Notification From: Thomas Maunder <tom_maunder@adlnin.state.ak.us> Date: Thu, 29 Mar 2007 09:31:42 -0800 ~ ~ ~ --~ '~~ '['v: Chip A1~ ord ,_ Chip.Al~~ord(uconocophil~ips.com~- CC: ~~(.)GC(' North Slo~~e O[lice t=-ao~~cc pnidhoc h~i~~r"ri.~adirlin.state.ak.us=. Chip, This confirms. your message that the event is not at the Intrepid location, but at .---~ Noatak #1. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 3/29/2007 8:57 AM: Chip, This confirms your call that there is a drill in progress on Kuukpik 5 at the Intrepid #2 location. The scenario is that a shallow gas kick has occurred. All mud has been blown from the well and the diverter has cut out. One man is down, the rig has been evacuated and preparations are being made to retrieve the missing person. Your man on site is contacting the AOGCC Inspector with the information. Call or message with further information. Tom Maunder, PE AOGCC l of l 4/17/2007 9:09 AM FW: Wellhead removal at Noatak • • Subject: FW: Wellhead removal at Noatak From: "Brasfield, Tom J" <TOM.J.Brasfield@conocophillips.com> t,~ Date: Mon, 26 Mar 2007 10:14:29 -0800 ~® ~~~ `~ To: tom maunder@admin.state.ak.us, greg_noble@k.blm.gov - CC: Tim_Lawlor@ak.blm.gov, "Alvord, Chip" <Chip.Alvord@canocophllips.com>, Kuukpik5 Company man <KUUKSGM@conocophillips.cam> Tom/Greg, per our telephone conversations this date; Winfree is planning to proceed ahead with the surface P&A as indicated below. Any questions or comments, please advise. Thanks, Tom -----Original Message---- From: Kuukpik 5 Company man Sent: Sunday, March 25, 2007 9:12 PM To: Brassfield, Tom J Cc: 2P Pad Co-man; Hayden, Philip; Chambers, Mark A Subject: Wellhead removal at Noatak Tom... Outlined below is the plan for removing the wellhead: Top of ice to top of tundra = 1' 6" Top of tundra to top of cement in cellar bottom = 5' 10" Top of cement cellar bottom to bottom of cellar = 8" Top of tundra to bottom of 4" outlets = 4' • Drill hole in 16" below 4" outlets and check for gas • With torch, cut window in 16" with bottom cut below 4" outlets (+/- 4' below top of tundra) and remove section and cement. • Drill hole in 9-5/8" casing and check for gas. • Cut windows in 9-5/8" casing and remove cement. Leave enough 9-5/8" so it won't collapse. • Drill 7" and check for gas • Finish cutting 9-5/8" and 7" and remove wellhead • Trim casings to same level (+/- 4' below tundra) • Inspect annuli and fill with cement back to surface if required • Take photo of cemented annuli • Weld on abandonment marker and drill 1/4" weep hole in top • Cut cellar box as low as possible (at least as deep as the top of the marker) • Split the cellar box and remove from the cellar • Take photos of marker w/depth reference • Backfill cellar with the original excavated material. Stack fill as high as required to use all the fill material. Make sure the pile is centered over the cellar. • Take photo of final fill 1 of 2 4/6/2007 12:34 PM FW: Wellhead removal at Noatak • The BLM regs say that 3' below grade is sufficient for casing cut off but it doesn't say anything about the cellar box. The BLM also requires a weep hole if a plate is used. It doesn't specify a size of weep hole so we'll use the same size of bit we used to check for gas. The welding truck will be out tomorrow and the welder will be out Tuesday. I left a message on Tim's cell phone saying we91 be doing this on Tuesday but I haven't heard back. Moose said he went back to Anchorage today (Sun). Give me a call if you want to change anything. Also, Nobody has a camera out here so I have to find one between now and Tuesday That's the plan from here Mike 2 of 2 4/6/2007 12:34 PM • ~,4RAYi PALIIN, GOVERAIOR Chip Alvord Exploration Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Exploration NPRA, Noatak # 1 Sundry Number: 307-091 Dear Mr. Alvord: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set .out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this /day of March, ~uu~~ Encl. Sincerely, STATE OF ALASKA ~ 3 97 ALAS~IL AND GAS CONSERVATION ~MIVI~ON MAR 1 4 2007 APPLICATION FOR SUNDRY APPROVALS giaska'Oi1 & Gas Cans. Commission 20 AAC 25.280 _ 1. Type of Request: Abandon^ ' Suspend ^ Operational shutdown ^ Perforate ^ Waiver C orape Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Conoco Phillips Alaska, Inc Development ^ Exploratory ^ , 205-042 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-279-20013-00 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Noatak #1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ALK AA-081839%ADL-AK 5184 21 NPRA Exploration 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8425' - 8425' - 8425' 8425' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 105' 105' 3280 630 Surface 2966' 9.625" 2987' ~ 2987' - 5750 3090 Intermediate 8125' 7.00" 8146' 8146' 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory^ Development ^ Service ^ 15. Estimated Date for 3/14/2007 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^~ Abandoned^ 17. Verbal Approval: Date: 3/14/2007 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder ~ '~ ?!J~/~ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Chip Alvord Title Exploration Team Leader 3/14/2007 Phone 265-6120 Date ~J~¢/~~ Signature ` l ~ G COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ .- Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other. SZ~,E~ ~~j~(`~ ~~SS\`1J~~\ SQ~(C-'~(`G~'C_ ~'S~~~ ~ Q\vC W\~`'I _ I e ~ Subsequent Form Required: ~~ p S' ~~, MAC ~ ~ ~~~7 APPROVED BY ~-~~' d : COMMISSIONER THE COMMISSION Date: A ro ed b pp v y Form 10-403 Revised 06/2006 ~ ~j~~` ~ ~ ~ ~ 3/ / Submit in Duplicate ~ ~ ConQCOP'hitl~ps Post Office Box 100360 Anchorage, Alaska 99510-0360 March 14, 2007 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry approval to Plug and Abandon Conoco Phillips Noatak #1 Surface Location: 2504' FNL, 1932' FWL, Sec. 22, T12N, RSW, UM or ASP4, NAD 27 coordinates of X=607,020 & Y=5,989,360 Target Location: 2504' FNL, 1932' FWL, Sec. 22, T12N, R5W, UM BHL: 2504' FNL, 1932' FWL, Sec. 22, T12N, RSW, UM CONFIDENTIAL Dear Commissioner: ConocoPhillips Alaska, Inc. would like to permanently plug and abandon the Noatak #1 wellbore, located. in the National Petroleum Reserve-Alaska. Kuukpik Rig 5 spud this well on 2/10/07 and TD'd the well on 3/11/07. The attached Sundry and back-up information describes the P&A procedure for the existing wellbore and has been discussed with AOGCC personnel. If you have any questions or require any further information, please contact me at 265-6377 or Chip Alvord at 263-6120. Sin/ce~r ,ly, J Tom Brassfield Sr. Drilling Engineer • Noatak #1 P&A Procedure • CONFIDENTIAL Revised 3/14/07 Noatak #1 Wellbore Status The Noatak #1 drilled to TD @ 8425" MD/TVD on 3/11/07.The 9-5/8" surface casing was set at 2987' MD/TVD and cemented back to surface ~A 7" string was set and cemented at 8146' MD (est TOC at 7000' MD). The rig drilled 6-1/8" hole to a TD of 8425' MD/TVD, ran E-line logs and decisioned to P&A the wellbore. The proposed P&A procedures are as follows. 1. Notify BLM/AOGCC 48 hours in advance of all well P&A operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well suspension operation. RIH with Baker cement retainer on 4" drill pipe. 3. Set retainer at 8050' or higher. (Baker recommends not setting the retainer in a collar or in 7" casing that had cement drilled out) 4. Set retainer and pressure up annulus to apex 1500 psi. Closely monitor annulus pressure throughout cement job. 7" 26# L-80 burst = 7240 psi x 70% = 5068 psi, 7" 26#, L-80 collapse = 5410 psi 5. Establish injection into open hole below retainer. 6. Mix cement. Bleed annulus and unsting from retainer and pump appx 10 bbl water spacer followed by 15.8 ppg cement volumes as follows: Cement volume calculation = 279' x .036 bbl/ft in 6-1/8" hole = 10 bbls in open hole + ~,~ 96' x .0382 bbl/ft in 7" 26# csg = 3.67 bbls in the cased hole below retainer Lay 2 to 3 bbl or 50' of cement on top of retainer 7. Displace cement down drill pipe with appx 10 bb/s of water followed by 10 ppg mud. Sting back into retainer as spacer water nears retainer. Pressure up annulus to appx 1500 psi and monitor while cement is being pumped below retainer. 8. With 2 to 3 bbls of cement still above retainer; stop pumping and bleed annulus. Unsting and allow remaining 2 to 3 bbls to dump on top of retainer. 9. POOH approx. 3 stands, circulate until drill pipe is clean. POOH. 10. RU to pump down the 9-5/8" x 7" annulus. Pump 100 bbls of water to flush annulus and verify infectivity, note rate and pressures. Bullhead 28 bbls or 1000' of Arctic Set 1 cement into the annulus. Annulus cement volume calculations = 1000' x 0.0282 bbl/ft (7" x 9-5/8" 40#) = 28 bbls TJB 3/14/07 • Noatak #1 P&A Procedure • CONFIDENTIAL Revised 3/14/07 11. POOH to 561' MD. Spot a 10 bbl high visc pill from 561' MD to 300' MD. Spot a . f 300' plug (11.5 bbl) of 15.7 ppg Arctic Set I cement plug from 300' to surface in the 7" 26# casing. 12. RD and move out rig. 13. Cut off wellhead and all casing strings at 3 feet below ground level. Verify cement is at surface in all strings. Send casing head with stub to Materials for repair/redressing. 14. Weld %4" thick cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top. Drill 1/8" weep hole in cover plate. • Conoco Phillips Alaska, Inc. • Noatak #1 • PTD# 205-042 • API# 50-279-20013-00 15. Remove cellar. Back fill cellar with gravel as needed. Clear ice pad location and demob all materials/equipment. Call agencies for final inspection. TJB 3/14/07 Noatak #1 P&A ~ 16" 65# H-40 @ +/- 105' MD Depths are based on rig RKB Surface csg. 9-5/8" 40.0# L-80 BTC (+/- 2987' MD / TVD) 3/14/07 300' cement plug to surface inside the 7" casing or approx. 11.5 bbls of AS1 J Intermediate csg. 7" 26.0# L-80 BTCM (+/- 8146' MD / TVD) 1000' of cement in the 9-5/8" x 7" annulus to surface or approx. 28 bbls of AS1 Estimated TOC @ 7000' MD/TVD Retainer set at 8050' MD w/96' of 7" + rathole (279') of cement below & 50' of cement above TD @ 8425' MD/TVD or 279' of 6-1/8" hole i TJB 3/14/07 Re: Noatak #1 P&A Subject: Re: Noatak #1 P&A From: Thomas Maunder <tommaunder(~r~admin.state.ak.us% Date: Wed, 14 Mar 2007 14:52:40 -0800 To: "Brasfield, Tome J " - ~C)M.J.Brasstield mconocoph i I I i i~.com> I agree. Thanks for the quick response. Tom Brasfield, Tom J wrote, On 3/14/2007 2:49 PM: • Tom, the depth of the 6~ermafrost at Noatak was called at 860' iViD {see attached report}. The 1000' of cement should be sufficient. Thanks, Tom -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin,state.ak.us] Sent: Wednesday, March 14, 2007 2:39 PM To: Brasfield, Tom J Subject: Re: Noatak #1 P&A Tom, One thought that has come to mind. How deep is the permafrost at the Noatak location? On the 9-5/8" x 7" annulus, it is probably best to pump sufficient cement to have cement throughout the permafrost interval. Message back with depth please. Tom Maunder, PE AOGCC Brasfield, Tom J wrote, On 3/14/2007 2:19 PM: Trm, Y~- Tim Lawlor is on location. Thanks, Tom -----Original Message----- From: Thomas Maunder maiito:tom maunderadmin,state.ak.us] Sent: Wednesday, March 14, 2007 12:31 PM To: Brasfield, Tom J Subject: Re: Noatak #1 P&A ', ', Tom, '' We will look forward to receiving the documents. Your plan meets the regulatory requirements and you have "verbal" approval to proceed. Is Tim from the BLM out there to witness the plugs? Tom Maunder, PE ', AOGCC 1 of 2 3/14/2007 2:53 PM Re: Noatak #1 P&A Brasfield, Tom J wrote, On 3/14/2007 11:51 AM: ', Tom, the following documents will be sent over today! Currently getting ready to set 7" cement retainer and pump cement! Thanks, Tom «Noatak #1 P&A AOGCC cover 3 14 07.rtf» «Noatak #1 P&A 10-403.x1s» «Noatak #1 PA Procedures FINAL TJB 3 14 07.rtf» «Noatak #1 P&A Word Schematic 3 14 07.doc» 2 of 2 3/14/2007 2:53 PM ~~hi l l i ~ iC onc~ t a ~ o • ~ • ~ • ~ Date: 2/22/07 Report # 13 Field: NOATAK NE NPRA API No: 50-279-20013-00 RTE/KBE 125'AMSL G~OIOgIStS: Dick Owens Planned TD: 8,925 LastGasi ng Shoe ` 5 8" @ 2G8~, Present Depth (md) - 6:00 am: 3,576 Prev ious Depth (md): 3,020 Foota a last 24 hrs: 556 Presertt De (sstvd ; -3,451 Formation. Present De Present Activi Short tripping at 2885' and Plan Ahead Finish short trip, drill ahead Q Sum ma 06:00 - 10:00 Displace mud to 9.7ppg 10:00 - 12:00 Perform FIT to 18.2ppg EMW 12:00 - 21:00 Drill to 3576' and 21:00 - 06:00 Short trip to shoe, cut and slip drill line Last Su Type Measured Depth Inclination Azimuth TVD SSTVD North/South East/West VS Dog Leg/100 MWD: - Sfiow 3000' - 3576' MD 70% claystone, 20% siltstone, 10% sand Mud Gas Gas Type Depth Tot Gas % C1 p m C2 ppm C3 ppm iC4 ppm nC4 ppm iC5 ppm nC5 ppm gG 30U 5000 50 FG = F Gas BU =Bottoms U d Ga BG =B k CG m Gas Peak =Connection G TG =Trip aa Gas, WTG =Wiper Trip Gas , p groun s, ac , Comments , 6WD Offset s Tool Offsets to bit Bit - GR Bit -Res Bit -MWD Bit - NPHI PWD BAT -Sonic ALD ACAL LWD Initialisations/Battery Life T i, 1fiau~s S eism d•tM ed F T fn lwtd t To /Marker/Fault MD- ro Hosts TVD- ro SSTVD- r o Error Bar MD actual TVD actual VDSS actu i- to Prognos Comment Base Permafrost 875 875 750 +/- 50' 860 860 735 :15:00 Nanushuk 1,325 1,325 1,200 .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . +/- 100' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,405 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,405 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,280 80.00 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Torok Formation 3,225 3,225 3,100 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . +/- 100' . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . HRZ 7,525 7,525 7,400 . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . +/- 100' . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miluveach/LCU 7,755 7,755 7,630 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . +/- 100' . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Jurassic Alp; Equiv Sands 8.275 8.275 8,150 +/- 100' UJU/Base Sands 8,405 8,405 8,280 +/- 100' TD 8,925 8,925 8,800 RE: Noatak P&A or Suspension • Subject: RE: Noatak P&A or Suspension From: "Brassfield, Tom J" <TOM.J.Brassfield@conocophillips.com> Date: Fri, 09 Mar 2007 15:42:03 -0900 To: Thomas Maunder <tom maunder@admn.state.ak.us> any word on 'n`ection permit for N~#afCTThe rig is asking: Thanks, Tom -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 09, 2007 2:55 PM To: Brassfield, Tom J Cc: greg_noble@ak.blm.gov; Alvord, Chip; Kuukpik 5 Company man Subject: Re: Noatak P&A or Suspension ~~5-~~~~ Tom, Your proposals look similar to proposals for other wells out there. Interesting regarding Baker's recommendation about the retainer. I had not heard that before. If the suspend route is chosen, please refer to 20 AAC 25.110 regarding justification of suspending the well. 25.110(d)(2) has been waived for prior wells, under the discretion in 25.112(1) but reasoning/justification will need to be given. Good luck with the forward operations. Call or message with any questions. Tom Maunder, PE AOGCC Brassfield, Tom J wrote, On 3/9/2007 2:39 PM: Tom/Greg, know this is somewhat premature; but we should be making this decision early next week. At this time, we see two possible outcomes- 1) P&A or 2) Suspension so we can come back at a later date. In either case we would P&A the Jurassic interval. In the suspension scenario, would run a 3-1 /2" circulating string to approx. 3500' and freeze protect tubing and all annuli to 1500'. There are always other possible outcomes- but these are the most likely! The timing to get to Intrepid will be very tight and next week will be a blur! Please call with any comments? Thanks, Tom «Noatak #1 P&A Word Schematic 3 9 07.doc» «Noatak #1 PA Procedures TJB 3 9 07.rtf» «Noatak Suspension Word Schematic 3 9 07.doc» 1 of 1 4/6/2007 12:35 PM - SARAH PALIN, GOVERPIOR ~~ ~ ~ ®~ 333 W. 7th AVENUE, SUITE 100 ~r 1~T~+ ~p~7~a +~+a 1~ 1~T ~+®1®s7~j i~it~~®1~ C®1.11•~-7-7i®17 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Exploration Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99510-0360 Re: NPRA Exploration, Noatak # 1 Sundry Number: 307-086 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of March, 2006 Encl. t ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ~~~~~~~~~~~~~~ Telephone 907-276-1215 March 8, 2007 I~ECEIVEa MAR Q $ 2001 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Alaska ail & Ga3 Cions. CO1111T11SSIOi1 Anchorage, Alaska 99501-3539 At1GhOf8Q@ _.... ,~ Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on Noatak Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that Noatak be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations at Noatak approximately March 9~`. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells-NA 10. List of wells on the Noatak pad and the lateral distance from the surface casing shoe-NA 11. Additional information regarding wells within'/4 mile radius-NA 12. Copy of previous authorization for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations- NA The initial annular LOT (13.9 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.2 ppg FIT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Tom Brasfield at 265-6377; Chip Alvord can also be reached by calling 265-6120. Sincerely, ~~~ Tom Brasfield Sr. Drilling Engineer cc: Noatak Well File Chip Alvord ATO-1570 Sharon Allsup-Drake ATO-1530 ~ ~ - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~CEIVED MAR 0 8 2007 ANNULAR DISPOSAL APPLICATION plalska pit & Gas Cons. Ctxnmissian 20 AAC 25.080 AnrhnFaoB 1. Operator 3. Permit to Drill Name: Number: 205-042 ConocoPhillips Alaska 4. API Number: 50-279-20013-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska Noatak #1 6. Field: NPRA Exploration 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: None Torok formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below in the lower Torok formation None c) Confinement: The Lower Nanushuk formation provides an upper barrier and the siltstones/mudstones of the Miluveach formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 870' MD /TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 73. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2839 PSI 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup 9-Mar-07 fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ^ FIT Records w/LOT Graph 0 Surf. Casing Cementing Data ~ Other ^ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ ~- Title: -- Exploration Team Leader Printed Name: Chip Alvord Phone Number: 265-6120 Date: 3~~(Z~' ~ Commission Use Only Conditions of approval: ~4a''~~~~G~v~ ~ ~ „t7~~ LOT review and approval: ~7 .. `> ` "~ al number: w ~~ VV~I A Subsequent form required: pprov /~ APPROVED BY Approved by: ~~ COMMISSIONER THE COMMISSION Date: Q r I:~ ~. ~A ~-~ ~--' 4 R I G 1 NA ~ Form 10-403RD Rev. 6/2004 ~ . II~~CTIONS ON REVERSE bmit in Dtapl'icate /'~'t~~ 3.~.Ea Annulus Disposal Transmittal Fi AOGCC Regulations, 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: Noatak 1 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers local to the Noatak area (none present. below permafrost). Estimated base of Permafrost is about ' 870' MD, based on Noatak 1 log response and correlation to the Kokoda 5 well (base permafrost 940' MD) about three miles awa . 3 A stratigraphic description of the interval exposed to the open The surface casing shoe is set in the marine mudstones of the annulus and other information sufficient to support a Lower Nanushuk Formation, providing a thick impermeable commission finding that the waste will be confined and will upper barrier. The stratigraphy open to the annulus will not come to the surface or contaminate freshwater. include about 4000' of the Torok Formation (consisting predominantly of slope mudstone with minor siltstone and turbiditic sandstones), HRZ and Pebble shales, and about 500' of the Miluveach Formation (consisting of siltstone grading downward to mudstone), with the Miluveach as the lower 4 A list of all publicly recorded wells within one-quarter mile N/A and all publicly recorded water wells within one mile of the well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud pit rinse fluid generated by rinsing tanks waste under (h)(3) of this section. and equipement after producing drilling completion fluid.. 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2839 psi. See attached calculation calculations showin how this value was determined. awe. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or Noatak 1 will be enerated. 15 If the operator proposes not to com~with a limitation N/A ' established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Well Noatak Date 2/28/2007 on a .~ U Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection tluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.3952 psi/ft F[eader Pressure (tor wells on gas lift) 0 psi '''•h''' Maximum Fluid Density to avoid Burst of Surface C: t _ ~'' Pburst85% - PI lydrostatic +PApplied - PFormation ~n N 3,000 TVD ' MWmax = 30.1 PPg Surface Casing Strin Size 9.625 in Weight 40 ppf Grade L 80 rbursclooi 5.750 Psi Pburst85/ 4,888 psi Depth of Shoe 3,000 ft F1T/LOT a Shoe 18.2 ppg or 2,839 psi FIT/LOT for Annulus 15.1 ppg Max Surf. Pressure 1,500 psi TOC Est.. 6,500' MD 7 6.500' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PI Ipdroslatic +PApplied - PGasGradie nt - Plieader 4,599 = ( 6,500 * 0.052 * M W,,,a„ ) + 1,500 - ( 0.3952 * 6,500) - 0 MWmax = 16.8 PPg 3.5 "Tubing 2nd Casing String Size 7 in 8,225 TVD Weight 26 ppf Grade L 80 1'collapse100% 5,410 Psl Pcollapse85% 4,599 pst Top of Cement 6,500 ft Gas Gradient 0.3952 psi/ft Max Surf. Pressure 1,500 psi Pleader Press 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe F[T/LOT Pmax allowable = ( 3,000 * .052 * 18.2 ) Pmax allowable - 2,839 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". Version L0 - Jan'OS 4,888 = ( 3,000 * 0.052 * M W,,,~ ) + 1500 - ( 0.4337 * 3,000 ) Noatak Surface Injection Pressures with gauge at disposal wellhead and using annulus friction of 50 MW Injection Pressure si MW Injection Pressure si MW ( Injection Pressure si 6.8 1,828 8.8 1,516 10.E 1,204 6.9 1,813 S.9 1,501 10.9 1,189 7.0 1,797 9.0 1,485 1 1.0 1,173 7.1 1,782 91 1,470 1 1.1 1,158 7.2 1,766 9.2 1,454 N .2 1,142 7. ~ 1,750 9.3 1,438 1 l . ~ 1,126 7.4 1,735 9.4 1,423 1 1.4 1,111 7.5 1,719 9.5 1,407 11.5'' 1,095 7.6 1,704 9.6 1,392 11.6 1,080 7.7 1,688 9.7 1,376 11.7 1,064 7. ~ 1,672 9. ~ 1,360 1 1. ~ 1,048 7.9 1,657 9.9 1,345 1.1.9 1,033 8.0 1,641 10.0 1,329 l ? .0 1,017 S.1 1,626 10.1 1,314 1?.1 1,002 8.2 1,610 10.? 1,298 ] ? .? 986 8.3` 1,594 10.3: 1,282 12. ~ 970 8.4 1,579 10.4 1,267 12.4 955 8.5 1,563 10.5` 1,251 12.5 939 $.6 1,548 10.6 1,236 12.6 924 ~.7 1,532 10.7 1,220 1.2.7 908 Well Noatak Date 2/28/2007 CASING/TUBING DESCRIPTION ENTER VALUES in the YELLOW CELLS Version 1.0 - Jan'OS Collapse Bursting Size Wt. Grade PSI PSI Surf. 9.625 40.000 L 80 3090.00 5750.00 Next String 7.000 26.000 L 80 5410.00 7240.00 Tubing 3.500 Fluid in Tubing/Casing Annulus diesel Surface Casing TVD 3000 ft Drilled Mud Weight 10 ppg Pore Pressure @ Shoe 0.434 psi/ft Shoe FIT/LOT 18.2 ppg Annuluar FIT/LOT 15.1 ppg Pburst @ 85% 4,888 Max Injected MW 12 ppg Max Surface Pressure 1,500 psi Distance from Pump to Well 350 ft Diameter of Pump Line 1.75 inches TVD Estimated TOC Estimated TOC Gas/Fluid Gradient in tubing/casing annulus Header Pressure (for wells on gas lift) Pcollapse @ 85% 8,225 ft 6,500 MD ft 6,500 TVD ft 0.3952 psi/ft 0 psi 4,599 (suggest fresh water gradient) (suggest 0.06 - 0.07 psi/ft) Security Level: Noatak Daily Drilling Report NOATAK 1 Report Number: 32 ..• Rig: KUUKPIK 5 Report Date: 2/17/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) NOATAK 1 Exploration NPRA TIGHT HOLE 2/10/2007 7.08 3,000.0 3,000.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10148733 3,010.00 61,000.00 194,703.00 1,368,366.00 22,296,681.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,987.OftK6 Ops and Depth @ Morning Report 24hr Forecast Nipple up BOPE POH w/ stab in assembly-niplle down diverter & nipple up BOPE-Test same. Last 24hr Summary Land 9 5/8" csg. circ. hole clean-rih w/ 4" stab in assembly -condition mud & cement well. General Remarks Weather Head Count No Accidents No Spills WC-46 Temp -29 Wind-SSW 6 mph 58.0 - _- Supervisor Title Ray Springer Rig Supervisor Ted Peter Tool Pushers Tom Brassfield Drilling Engineer Dink Heim Rig Supervisor Rusty Watson Ice Road Supervisor Time Lo Start ~~ Time End Time 0 Dur (hrs) Phase Time Qp Code OpSub Co '. P-N-T Trbl Code ~~ Trbl Class Depth. Start Depth End l (ftKB) ' (ftKB) Cornm/Operation ' 00: 0 0.50 SURFAC CASING RNCS P 3,000.0 3,000.0 . Make up landing jt.-Tag @ 2987 00:30 07:00 6.50 SURFAC CASING CIRC P 3,000.0 3,000.0 Circ.,condition hole-reciprocate 9 5/8" csg @ 5 bpm 200 psi. 07:00 09:00 2.00 SURFAC CASING OTHR P 3,000.0 3,000.0 Back out pup jt.-rig down circ. head-Blow down & land w/ 74k csg. wt. 09:00 14:00 5.00 SURFAC CASING OTHR P 3,000.0 3,000.0 Make up stab in sub on 4" dp w/ centralizer-RIH w/ 4" stab in assembly to 2902'. 14:00 15:30 1.50 SURFAC CASING OTHR P 3,000.0 3,000.0 Space out w/ pups & sting in float collar-Rig up cement head & hoses.. 15:30 18:30 3.00 SURFAC CASING CIRC P 3,000.0 3,000.0 Condition mud &circ. 804 bbls. mud. 18:30 21:30 3.00 SURFAC CEMENT DISP P 3,000.0 3,000.0 PJSM-Pressure test cement lines 3000# OK. Pump cement job-50 bbl. CW100-50 bbl. Mud push @ 10.5# followed w/ 167 bbl. arcticset lite @ 10.7# & 40 bbl. litecrete @ 12#-Chase w/ 24 bbl: mud. 21:30 22:00 0.50 SURFAC CEMENT TRIP P 3,000.0 3,000.0 Rig down cement lines-lay down pup jts. & pull 2 stands 4" dp. 22:00 23:00 1.00 SURFAC CEMENT DISP P 3,000.0 3,000.0 Drop wiper plug &circ. 40 bbl. to clean drill pipe. 23:00 00:00 1.00 SURFAC CEMENT TRIP P 3,000.0 3,000.0 POH w/ 4" dp. Wellbores Wellbore Name i Wellbore API/UWI NOATAK 1 5027920013 ~ End Dale SeCtipn ', Size (in) - - PROD1 -- 61/8' Start Date Act To(i(ftK6) Act Btm (ftKB) - ~- _. 3/1/2007 COND1 24 0.0 101.0 1 /17/2007 1 /17/2007 SURFAC 12 1/4 100.0 3,000.0 2/12/2007 2/14/2007 INTRM1 8 1/2 3,000.0 7,541.0 2/21/2007 Stnn s C~Descnption Run Date OD (in) Wt (Ibs/ft) Grade~Set Depth (ftKB Comment - __ - - __ 2/17/2007 Surface 9 5/8 40.00' L-80 2,987.0 Cement Surface Casin Cement -Started 2/17/2007 Type Wellbore String Cement Evaluation Results casing NOATAK 1 Surface, 2,987.OftK6 Good cement job -no losses. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casin Cement g 0 5 230.0 0.0 2,987 -- Class A Fluid ~ Est Top (ftKB) _ _ Est Btm (ftKB) mount (sacks) V (bbl) Density (16/gal) Yield(fN/sack) Surface Cement G 132 10.70 4.43 0.0 2,902.0 Latest BOP Test Data _ _ _... _ ... _ Date ~ _. Comment Page 1/1 Report Printed: 3/8/2007 Security Level: Noatak Daily Drilling Report NOATAK 1 Report Number: 36 Rig: KUUKPIK 5 Report Date: 2/21/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) NOATAK 1 Exploration NPRA TIGHT HOLE 2/10/2007 .11.08 3,000.0 3,576.0 576.00 AFE / RFE / Maint.# Daily Mud Cost Cum mulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10148733 3,010.00 73,040.00 139,522.00 17,627,401.00 22,296,681.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,987.OftKB Ops and Depth @ Morning Report 24hr Forecast Working on tank farm Work on tank farm. Drill ahead. Last 24hr Summary Pressure tested casing. Drilled out shoe. Drilled 30' new hole, circulated over to 9.7ppg mud @ performed FIT to 18.2ppg EMW. Drill ahead to 3576'. Slip & cut drill line. General Remarks Weather Head Count No Accidents No Spills WC -61 Temp -40 Wind-NE 7mph 57.0 Supervisor '~ Title Donnie Lutrick Rig Supervisor Ted Peter Tool Pushers Tom Brassfield Drilling Engineer Dink Heim Rig Supervisor Rusty Watson Ice Road Supervisor Justin MacDonald Drilling Engineer Time Log_ Start End Dur '. I ~ Time Depth Start Depth End Time Time Ihrs) '~ Phase ~ Op Code QpSub Go ' P-tJ-T Trbl Code Tr_bl _Class (ftKB) (ftKB) Comm/Operation 00:00 01:00 1.00 INTRM1 DRILL OWFF P 3,000.0 3,000.0 Re-pressure test 9-5/8" casing. Pump 3.4bb1 and pressure up to 2500psi. Hold pressure 30 minutes. Final pressure 2460psi. Bleed off and get 1.9bb1 back. 01:00 03:00 2.00 INTRMI DRILL CIRC P 2,794.0 2,987.0 Break circulation at 2794' and wash down from 2794'-2897'. Took weight at 2897' and continue washing down to 2987. 03:00 04:00 1.00 INTRM1 DRILL DRLG P 2,987.0 3,004.0 Drill out shoe with 5000ft-Ibs torque. Tag new hole @ 3004'. 04:00 04:30 0.50 INTRM1 RIGMNT SVRG P 3,004.0 3,004.0 Conduct rig service. 04:30 05:00 0.50 INTRM1 DRILL DRLG P 3,004.0 3,020.0 Drill new hole from 3004' to 3020'. 05:00 08:00 3.00 INTRM1 DRILL CIRC P 3,020.0 3,020.0 Circulate & condition mud for FIT. Circulate 504gpm @ 1790psi. Displace well to 9.7ppg mud and transfer old mud to outside tank. 08:00 09:30 1.50 INTRM1 DRILL LOT P 3,020.0 3,020.0 Conduct FIT. Pump to 1323psi at surface and held for 10 minutes recording bleed off. Final pressure 1176psi. EMW @ 2987' = 18.2ppg. Bleed off remaining pressure. 09:30 10:00 0.50 INTRM1 DRILL OWFF P 3,020.0 3,020.0 With bit @ 3020' obtain slow pump rates: Pump #1: 30spm = 119psi, 50spm = 172psi Pump #2: 30spm = 148psi, 50spm = 235psi 10:00 11:00 1.00 INTRM1 DRILL RURD P 3,020.0 3,020.0 Rig up catch can in cellar. 11:00 12:00 1.00 INTRM1 DRILL DRLG P 3,020.0 3,076.0 Drill from 3020' to 3076'. At 3050': Up wt: 76k, Down wt: 84k, Rot wt: 76k @ 53rpm, 2500ft-Ibs. 12:00 20:30 8.50 INTRM1 DRILL DRLG P 3,076.0 3,576.0 Drill from 3076' to 3576'. Circulate bottoms up. At 3576': Up wt: 86k, Down wt: 86k, Rot wt: 86k @ 3400ft-Ibs. 20:30 21:00 0.50 INTRMI DRILL TRIP P 3,576.0 3,576.0 Wiper trip. POOH from 3576' to 3384'. 21:00 00:00 3.00 INTRM1 RIGMNT OTHR NP 3,576.0 3,576.0 Drilling line backlashed on drum. Slip & cut to remove bad spot in drill line. Drill Strin s: BHA No. 3 - Intermediate #1 /Bit Run No . 3 - 8 3/4in, Reed-H Gala , DS70FNPV , 208648 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in ') Nozzl es (l32") IA DC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 3,000.0 8,100.0 1.04 15/15/15/15115 1-1-CT-A-X-O-ER-BHA 71 0 0 Drill Strin Com onents -- Jts - ', ~ Ilem Description - - _ _ _ _ - OD (m) _ i ID (In) Top Conn Sz (in) '., Top Thread Cum Len (ft) - - 22 HWDP 4 2.750 3 1/2 HT-38 677.97 1 Weatherford XO 6.2 2.250 3 1/2 HT-38 679.64 6 Drill Collar 6 1/2 2.500 4 1/2 H 90 860.30 Latest BOP Test Data Date -.~ .. __- - -- _- Comment _ _ -. __. - Page 1/2 Report Printed: 3/8/2007 Security Level: Noatak Daily Drilling Report NOATAK 1 Report Number: 36 ... . Report Date: 2/21/2007 Rig: KUUKPIK 5 Drill String Components Item Description Jts Op (in) ID (in) ~ Top Conn Sz (n) Top Thread Cu m Len (ft) 1 ~ Drilling Jars -Hydraulic _ -. 6 1/2 2.250 4 1/2 H 90 892.00 2 Drill Collar 6 1/2 2.500 4 1/2 H 90 952.22 1 RIG XO Sub 6 1/2 3.125 4 1/2 H 90 954.21 1 Drill Collar -Flex Non Mag 6.8 2.875 4 1/2 IF 985.07 1 Drill Collar- Flex Non Mag 6.85 2.875. 4 1/2 IF 1,016.17 1 Drill Collar -Flex Non Mag 6.82 2.813 4 1/2 IF 1,047.28 1 MWD Batt 7.1 2.000 4 1/2 IF 1,069.42 1 MWD Telemetry HOC 6.74 2.000 4 1/2 IF 1,079.25 1 MWD Directional HOC 6.77 2.000 4 1/2 IF 1,088.45 1 MWD Density/Neutron 6.99 2.000 4 1/2 IF 1,118.47 1 MWD GR/RES/PWD 7 2.000 4 1/2 IF 1,146.49 1 Stabilizer IB NM 6.76 2.813 4 1/2 IF 1,152.11 1 Drill Collar- Flex Non Mag 6 1/2 2.875 4 1/2 IF 1,167.00 1 Float Sub 6.57 3.813 4 1/2 IF 1,169.24 1 Motor with Stabilizer 7.01 3.000 4 1/2 IF 1,194.55 ameterS Dnllm Pa I _ _ ~ ' Cum Drill 0 (fl Sliding Hrs T h ' ow) FPM ~ m) (r PU HL ~ Rot HL 10001bf) (10001bf) i ( SO HL (10001bf) ~ Off Btm Tq ~ Drill Tq p ) ( ) ime ( rs) (gp '. End ftKB ( ) Cum De th (ft Start (ftKB) 00 0 50 0 0 001 20 020 3 p m) WOB (Ibf) 0 50 500 2 SPP (ps ) _ 84 80 1 800 0 84 200.0 2,000.0 . . , . 3,000.0 3,020.0. 3,074.0'. 0.00' 74.00 1.00 . 525' 100 , . . 1,900.0 86 80 84, 250.0 2,000.0 3,074.Oi 3,576.00.00 576.00 6.0~ 550 4~100~ 2,200.0 88 80 8~ 300.0. 2,000.0 Wellbores T Wellbore Name Well bore APIIUWI NOATAK 1 ~ 5027920013 Section _ Size (n) Z PROD1 - - 6 1/8 Act Top (ftKB) - Act Btm (ftKB) --- Start 3/1/2007 Date -End Da - te COND1 24 0.0 101.0 1 /17/2007 1 /17/2007 SURFAC 12 1/4 100.0 3,000.0 2/12/2007 2/14/2007 INTRM1 8 1/2 3,000.0 7,541.0 2/21/2007 Surv~Data ° MD (ftKB) Ipcl (°) Azm (°) 1 1 ~ ND (ftKB) VS (ft) ~ NS (ft) EW (ft) DLS - /10Qft) ( 2.82 0.36 3,027.23 3,027.20 8.24 8.24 -1.84 0.32 3,149.85 0.26 357.44 3,149.82 8.91 8.91 -1.83 0.08 3,275.36 0.15 358.64 3,275.33 9.36 9.36 -1.85 0.09 3,400.00 0.19 9.17 3,399.97 9.72 9.72 -1.82 0.04 3,528.15 0.23 24.73 3,528.12 10.17 10.17 -1.68 0.05 Page 2/2 Report Printed: 3/8/2007 PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: Noatak #1 Rig: Kuukpik #5 Date: 2/21/2007 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: Don Lutrick Pump used: ' #1 Mud Pump ~ Strokes ~ 0.0472 Bbls/strk ~ 11.0' strk/min ~ ~ Type of Test: Casing Shoe Test LoT/Frr ~ Pumping down ,annulus and ~P. ~ Casin Test Pressure In te ri Test Hole Size: 8-3/4" ~ Casin Shoe Depth Hole De th Pum in Shu t-in Pum in Shut-in 9 Ft RKB-CHF: 16 987 Ft-TVD 987 Ft-MD 2 2 020 Ft-TVD 3,020 Ft-MD 3, Strks si Min si Strks si Min si _ , , . Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 2559 0 0 0 1323 Casin Test Pressure Inte rit Test 6 105 1 2541 6 -~ 252 0.25 1300 0 ppg Mud Weight: 9.7 ppg ht: 10 Mud Wei 11 357 2 2531 12 536 0.5 1291 . g 0 Lb/100 Ft2 Mud 10 min Gel: 11 Mud 10 min Gel: 11.0 Lb/100 Ft2 17 563 3 2522 18 774 1 1282 . T t P 2 500 si Rotating Weight 85 Lbs 23 783 4 2513 24 1126 1.5 12 "' es ressure. p Rotating Weight: 85 Lbs Blocks/Top Drive Weight: 20 Lbs Blocks/Top Drive Weight: 20 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 2.1 bbls Estimates for Test: 1289 psi 1.1 bbls - -- - -~ EMW =Leak-off Pressure + Mud Weight = 1323 + 9 7 PIT 15 Second 0.052 x TVD 0.052 x 2987; Shut-in Pressure, si EMW at 2987 Ft-MD (2987 Ft-TVD) = 18.2 ~-~ 1300 3000 - - - (~~t 78 psi during test, held 97% of - - ~~'"test pressure. ~T ~ 2500 2000 W d' N 1500 W d' a looo 500 ;~~. 29 993 5 25 2 1 33 1218 6 25 2.5 1245 39 1437 7 25. 3 1241 44 1657 8 25( 3.5 1231 50 1868 9 25: 4 1227 55 2078 10 24 4.5 1222 61 2260 15 24! 5 1218 66 2449 20 24 5.5 1213 72 2559 25 24 6 1213 30 2~? 6.5 1208 ~ ~ 2 3 40 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~~CASING TEST BLEAK-OFF TEST O PIT Point Casing Test Noatak #1 3500 ' ' 3000 ' . 2500 , W 2000 ~ ~ to ~ ~ d 1500 1000 0000058 bbl/bbl/psi tem Com ressibilit = 0 A S 500 p . y verage ys ~ •. ~ •: 0 0 2 q 6 8 Barrels ~~CASING TEST - - - • Minimum Compressibility - - - - - - Maximum Compressibility ~ 'Required Test Pressure - ~ ~ Best Slope Fit s 1500 1000 W 0' N W 0_' a 500 Pressure Integrity Test Noatak #1 ,_ i / / / ~~Casing Test _ / - - -Theoretical Minimum Volume i Anticipated Leak-off Pressure ---~-Leak-off Test - - - - Theoretical Maximum Volume / O FIT Point ,_ / / - -Maximum Pressure / / - - / _`_ . / / / / _. / / / - / / 0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 Barrels Security Level: Noatak Daily Drilling Report NOATAK 1 .-. .• Report Number: 50 Rig : KUUKPIK 5 Report Date: 3/7/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) NOATAK 1 Exploration NPRA TIGHT HOLE 2/10/2007 25.08 8,148.0 8,148.0 0.00 AFE / RFE / Maint.# Dai ly Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10148733 110,935.00 137,784.00 20,303,769.86 22,296,681.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 8,146.7ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE BOP test. Annular LOT. PU BHA Drill production interval. Last 24hr Summary Run 7" casing and CIP. General Remarks Weather Head Count No Accidents WC -50 Temp -20 Wind NE 20mph 57.0 _ __. _. _. - Supernsor -.. _ Title Tom Brassfield Drilling Engineer Ray Springer Rig Supervisor Jerry Otto Tool Pushers Bobby Riddle Ice Road Supervisor Mike Winfree Jr. Drilling Engineer Ttme Log _ _ _ _ ~ ~ Start End Dur Time ~ ' De th Start De th End p P Phase OpSub-Co_ R-N-T Op Code Trbl Code Trbl Class. ~ (ftKB) (ftKB) _ Comm/Operation __ _ 00:00 03!00 3A0 INTRM1 CASING RNCS P 5,492.0 5,942.0 Run 7" casing from 5942' to 7000'. 03:00 04:30 1.50 INTRMI CASING CIRC P 5,942.0 7,000.0 Circulate and condition mud. 04:30 06:30 2.00 INTRM1 CASING RNCS P 7,000.0 8,085.0 Run casing from 7000' to 8085'. 06:30 12:00 5.50 INTRM1 CASING RNCS P 8,085.0 8,148.0 Wash to bottom from 8085' to 8148'. Up wt: 194k Dn wt: 188k 12:00 14:30 2.50 INTRM1 CASING RNCS P 8,148.0 8,148.0 Space out 7" casing. MU casing hanger and make up cementing head. 14:30 17:00 2.50 INTRMI CEMENT CIRC P 8,148.0 8,148.0 Circulate and condition mud. 17:00 17:30 0.50 INTRM1 CEMENT DISP P 8,148.0 8,148.0 Batch up cement, test lines to 2500 psi. 17:30 19:30 2.00 INTRM1 CEMENT DISP P 8,148.0 8,148.0 Dowell pumped: 10 bbl CW100 Dropped bottom plug 20 bbl Mud Push II 37 bbls cement Dropped top blog 20 bbl chase water. The rig pump was used for displacement and the plug bumped on strokes. 19:30 22:00 2.50 INTRM1 CEMENT PULD P 8,148.0 8,148.0 Wash up and clear rig floor of cementing equipment. 22:00 00:00 2.00 INTRM1 CEMENT WOC P 8,148.0 WOC. Drain stack and flush with water. Vac cellar dry. MU running tool and install packoff. Wellbores Wellbore Name Wellbore API/UWI NOATAK 1 5027920013 Section PROD 1 Size (in) _ 6 1 /8 Act Top (ftKB) Act Btm (ftKB) ~ Start Date - ' End Date 3/1 /2007 COND1 24 0.0 101.0 1 /17/2007 1 /17/2007 SURFAC 12 1/4 100.0 3,000.0 2/12/2007 2/14/2007 INTRM1 8 1/2 3,000.0 7,541.0 2/21/2007 Castng Strin s ~ - ~ Casing Description Run Date OD (in) Wt QbSlft) ' Grade ~ Set Depth (ftKB) ~ _ Comment Intermediate 3/7/2007 7 26.00 L-80 8,146.7 Latest BOP Test Data -. '~, Date ~ Comment - Page 1/1 'Report Printed: 3/8/2007 PRESSURE INTEGRITY TEST Well Name: Noatak 1 Rig: KUUKPIK 5 Date: 2/8/2007 Volume Input Pum Rate: Drilling Supervisor: Ray Springer Pump used: ~ Cement unit ~ T e of Test: 'I A l L k off T t f Di l Ad ~ P i d l ~ Barrels ~ Bbls/Strk ~ ' Strk/min ~ yp nnu us ea es or sposa equacy ump ng own annu us. Casin Test Pressure In te rit Test Hole Size: $-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 20.5 Ft 2987.0 Ft-MD 2987.0 Ft-TVD 7000.0 Ft-MD 7000.0 Ft-TVD Bbls si Min si Bbls si Min si Casing Size and Description: 19-5/s" 4o#/Ft L-so BTC ~ 0 0 0 0 0 0 0.00 350 2 0.5 310 0.50 310 Enter outer casing shoe test results in comments Mud Weight: 11.0 ppg 4 1 357 1.00 298 Casing description references outer casing string. Inner casing OD: 7.0 In. 6 1.5 390 1.50 293 Hole Size is that drilled below outer casing. 0.0 8 2 450 2.00 Use estimated TOC for Hole Depth. 0.0 10 2.5 435 2.50 Enter inner casing OD at right. Desired PIT EMW: 14.0 ppg 12 3 412 3.00 284 Estimates for Test: 46~si 0.3 bbls 14 3.5 421 3.50 279 ~ 16 4 421 4.00 279 EMW =Leak-off Pressure + Mud Weight = 450 + 11 PIT 15 Second 18 4.5 426 4.50 275 0.052 x TVD \ 2987 / Shut-in Pressure, si 20 5 430 5.00 275 EMW at 2987 Ft-MD (2987 Ft-TVD) = 13.9 / 310 24 5.5 450 5.50 270 soo - - - 28 6 430 6.00 270 °A, 32 G.5 439 6.50 270 ~ ~S 36 7.00 270 40 7 50 266 ~ (o ~ ~ ~ 43 . 8.00 266 8.50 261 w ~ 9.00 261 - ~ 9.50 261 ~ "~- ` t 10.00 2-S 1 W I .J o ~ ~ ! ~ 0 5 10 1 5 20 2 5 3 0 35 4 0 45 50 0 5 1 0 15 2 ~ 0 2 5 30 ~~CASING TE Barrel ST s -LEAK-OFF Shut-I TEST O PI n tim T Poin e, Mi t nute s Volume PUm ed Volume Bled Back Volume Pum ed Volume Bled Back S S S S Comments: Test to for injection of fluid and to freeze protect the IA 9 5/8" X 7" 9-5/8" shoe FIT @ 18.2 ppg EMW IV Vr1I/i r~ 1 /iIV IV ULUJ LV I rrom Klg Uy I JCS 3 Ui3 U/.XIS Summary Pressure Integrity Test Noatak 1 1500 -- i- I i '~'+~~Casing Test - - -Theoretical Minimum Volume ~~ Anticipated Leak-off Pressure ---~-Leak-off Test 1000 - - - - - - -Theoretical Maximum Volume O FIT Point -Maximum Pressure W N W a 500 i - - ~ I -I-- - - 0 0.0 5.0 10.0 15.0 20.0 25.0 30.0 35.0 40.0 45.0 50.0 Barrels • rvUH I Hf< ~ HNNUt_U5 LOT from Rig by TJB 3 08 07.x1s PIT Plot --~ Cement Summary ', NOATAK 1 ,, Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10148733 1/17/2007 2/10/2007 ATAK 1 N O _ _ _ _ - --- - _ Wellbore Name Profile Type Kick Off Depth (ftKB) i Vertical Section Direction (°) NOATF~K 1 0.00 ~ctlo~ S re ilr--) '~ Act Tcp tf;KB) ' Act 6fm (ftKB( COND1 24 0.0 101.0 SURFAC 12 1/4 100.0 3,000.0 INTRM1 8 1/2 3,000.0 7,541.0 - - - Type Install Date uescripiion iwa~~ce moaei vvr ,psi) aernce oiv i _.._ --_._ _. __._._. _ _. ---- - ---._______. _.. - __.. --- - --- (Conductor, 101.OftKB - - - - - ~casmg Descnpaon weupore stun Date Set Deptn (tttcts) sncK up (ttK6) set renswn (Krps) Conductor NOATAK 1 2/22/2007 101.0 0.0 0.0 Centralizers Scratchers None None Teo C^nn ~ S ~ Jts It-m De~ - ~r~tion 2~Casing Joints nD ii) 16 ~ ID (i~ Wt !~ ~ ~ ~ 15.2501 ) ~ Jt~~'i (i ~_'..^ in) ~H-40 Too TF~r a 1 -_ , Buttress Lan it) 101.00 Top (fIKB) ~ L'tm 0.0~~ ftKB) 101.0 ', i 1 Thread Surface, 2,987AftKB _ _ - -- Casing Description Wellbore Run Date Set Depth (ftKB) Stick Up ( ftKB) _ Set Tension (kips) Surface NOATAK 1 2/17/2007 2,987.0 0.1 0.0 Centralizers Scratchers 21 Bow springs 0 .',Top Conn Sz '. - --- Jts (tam Doscripben OD (ir) ID (in) W((I bJfl) Grade ~ (gin) Top rhraad Lc-n (ft) I op tftKB) Btm (ftKB) 0 Casing Joint 9 5/8 8.835 40.00 L-80 0.00 -0.1 -0.1 1 Landing Jt 9 5/8 8.835 40.00 L-80 22.05 -0.1 22.0 1 Casing Hgr 9 5/8 8.835 40.00 L-80 4.00 22.0 26.0 68 Casing Joint 9 5/8 8.835 40.00 L-80 2,875.12 26.0 2,901.1 1 Stabin Float Clr 9 5/8 8.835 40.00 L-80 1.87 2,901.1 2,903.0 2 Casing Joint 9 5/8 8.835 40.00 L-80 82.35 2,903.0 2,985.3 1 Float Shoe 9 5/8 8.835 40.00 L-80 1.70 2,985.3 2,987.0 ~ Intermediate, 8,14_6.7_ ftKB Casing Description Wellbore _ _ Run Date Set Depth (ftKB) - --- Stick Up (ftKB) _ Set Tension (kips) Intermediate NOATAK 1 3/7/2007 8,146.7 -1.3 Centralizers Scratchers _ 10 Bow springs 0 Tep Conn Sz - Jts ~~ Item Dasanption 'i ~ ~ OD (in) ID pn> ~ Wt (I bslft) Grade ~~~~) Top Thread Len (ft) Top (ftKB) Btm (ftKB) 1 RKB 7 6.276 26.00 L-80 Buttress 19.60 1.3 20.9 Thread 1 Mandrel hanger Pup 7 6.276 26.00 L-80 7 Buttress 1.75 20.9 22.7 Thread 190 Casing Joints 7 6.276 26.00 L-80 7 Buttress 8,037.14 22.7 8,059.8 Thread 1 Float Collar 7 6.276 26.00 L-80 7 Buttress 1.36 8,059.8 8,061.2 Thread 2 Casing Joints 7 6.276 26.00 L-80 7 Buttress 84.05 8,061.2 8,145.2 Thread 1 Float Shoe PIP in collar on shoe 7 6.276 26.00 L-80 7 Buttress 1.47 8,145.2 8,146.7 joint Thread <Description?>, <Tj!Pe?>, <Start Date?> - 'Cementing Start Date Cementing End Date Wellbore NOATAK 1 Evaluation Method Cement Evaluation Results Comment Cement Summary NOATAK 1 Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (bbl) Top Plug"! tioaom rrug No No No Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl) Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft'/sack) Mix H2O Ratio (gal/sack) Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) _ _ __ - _ _- Cement Fluid Additives -- Fldd Type Conc Conductor Cement, casin , 1/22/2007 00:30 Cementing Start Date Cementing End Date Wellbore 1/22/2007 1/22/2007 NOATAK 1 Evaluation Method Cement Evaluation Results Returns to Surface Comment Pumped Schlumberger ArcticSet 1 D816. Cement u-tubed into conduct casing. Tagged with rope @ ~25'GL. Waited for cement to set and then pumped more cement to get cement at surface. 9, 0.0-101.OftKB _ _ _ _ Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (bbl) Top Plug? Bottom Plug? 0.0 101.0 No No No Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl) Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft'/sack) Mix H2O Ratio (gal/sack) Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) __ _- - - Cement Fluid Additives __ __ _ _ - _ ndd Ty,pV ,one __ - - _ _ __ __ _ - _ __ --- __ - --- __ _ - ,Surface Casing Gement, casing., 2/17/2007 00:00 - - Cementing Start Date Cementing End Date Wellbore 2/17/2007 2/17/2007 NOATAK 1 Evaluation Method Cement Evaluation Results Returns to Surface Good cement job -no losses. Comment Pumped 50 bbl cw100-50 bbl mudpush @ 10.5# -167 bbl. arcticset lite @ 10.7# & 35 bbl. litecrete @ 12.#. Good returns to surface. No Loss . __ - _ 1, 0.0-2,987.OftKB _ _ _- __ __ Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (bbl) Top Plug? Bottom Plug? 0.0 2,987.0 Yes No No Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 5 5 5 230.0 0.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Cement Summary NOATAK 1 - - - - - - - - - I Rnrfaca Camwnt - _ _ - -- Fluid Type Surface Cement Fluid Description Amount (sacks) 132 Class G volume rumpeu tuuii Estimated Top (ftK6) 0.0 Estimated Bottom (ftKB) 2,902.0 Percent Excess Pumped (%) 28.0 Yield (ft'/sack) 4.43 Mix H2O Ratio (gal/sack) 20.60 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 10.70 _ _ - __ Cement Fluid Additives - ---- Add _. - -- - Type __ - _ Conc - - - _ - Noatak #1 ~ 3/8/07 Intermediate csg. 7" 26.0# L-80 BTCM (+/- 8146' MD / TVD) TJB 3/8/07 Kokoda Review-Petrophysics Kokoda #1 Shallow Data -Salinity Formation Temp vs. RW(Apparent) Crossplot Well: KOKODA_1 Filter: VSH<.25 0 to 20 w W 30 A ... 40 a 50 ,~ 60 ~ ~o 0 w so 90 Zoo N • ~ r . N ^r ~ ®• '~' ~, O • T • ~: c • "c r a .~, . _. Temperature Correction for 15 Kppm Data Regre ion o RWA (OHMM) 0 Color: VSHALE Sands with VSH < 25~ Source for Data Regression (Black Line) 0 ConocoPhillips ~. Alaska, Inc. Shallow Data was acquired ~~ to satisfy the regulatory need to detect potential H,a shallow aquifers. Techniques to determine water salinity are spelled out in EPA documentation and require a porosity and resistivity logs. 1 Below the permafrost ~s4o° md), water salinity in cleaner sands center on a value of 15 Kppm TDS. • Note to File Noatak #1 (205-042...307-086) NPRA Exploration ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. The volume of cement returned was not reported. The Rig Supervisor when the casing was cemented was contacted and confirmed that cement was circulated. Cementing using the DP allows tight volume control to help reduce .waste production at the remote exploration well. The pumped volume was 26% in excess of the calculated volume. -- On the initial leak off test, the pressure rises smoothly to 18.2 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 17.2 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully. cemented. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 13.9 EMW. Pressures range from 13.9 to 13.6 EMW while pumping. During the observation period, the pressure declined to 12.7 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --There are no wells within % mile of Noatak #1 Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Tom Maunder, PE Sr. Petroleum Engineer March 9, 2007 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\070309--Noatak #l.doc • Note to File NOATAK 1 (PTD 2050420) March 9, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well Colville River Unit Noatak 1 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of Noatak 1. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set at 3,000' measured depth ("MD") and about 2,838' true vertical depth subsea ("TVDSS"), near the base of a series of six upward-coarsening sediment cycles, each of which begins with a basal claystone that grades upward to siltstone and then to silty sandstone. The aggregate thickness of these claystone intervals exceeds 200 feet. These claystone intervals will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of Noatak 1 to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick and persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 95' from the wellbore. Discussion CPAI's application was reviewed along with records from wells Kokoda No. 5 ("Kokoda 5") and Kokoda No. 1 ("Kokoda 1"), which ocated roughly along depositional strike about 3 miles and 6-1/2 miles away, respectively. The discussion that follows is based on well and mud logs from these wells. An index map is provided, below. The proposed injection interval in Noatak 1 lies in the Torok formation in the southern portion of Section 22, T12N, RS W, UM. The 9-5/8" surface casing shoe of Noatak 1 lies at a depth of about 2,838' TVDSS, a series of six upward coarsening sedimentary intervals (see Figure 2, below). These intervals range from 35 to 130 feet thick. Lithology ranges from claystone at the base of each interval, coarsening upward to siltstone, and then to fine to medium-grained sandstone. The basal claystone portions of these intervals range from 20 to 60 feet thick. These claystone intervals have an aggregate thickness of more than 200 feet, and they will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to be at about 6,338 feet TVDSS. The most likely portions of the open annulus that will accept injected waste are five thin layers interval of silty sandstone and sandstone that lie between 3,025 and 3,225 feet MD (2,863 and 3,063 feet TVDSS; see • Noatak No. 1 Note to File • March 9, 2007 Page 2 of 5 Figure 3, below). These thin beds have an aggregate thickness of about 30 feet. Two additional thin sandstone layers (each seven feet thick) that lie between 3,430 and 3,490 feet MD may also accept some of the injected fluids. The aggregate thickness of all of these potential injection zones is about 45 feet. These potential injection zones are separated and underlain by numerous claystone/ siltstone intervals that will provide lower confinement for any injected wastes. Figure 1. Index Map The operator's application reports the base of permafrost occurs at about 705 feet TVDSS in this area, which is more than 2,150 feet above the top of the proposed injection intervals. The shallow geologic section in the area surrounding Noatak 1 likely contains methane gas. Mud logging records from Kokoda 5 and Kokoda 1 indicate that traces of methane were first measured at 277 and about 50 feet TVDSS, respectively. In both Kokoda 5 and Kokoda 1, heavier gasses (C2 through C4) first appear between 1,135 and 1,415 feet TVDSS. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (range: 9.8 to 10.0 pounds per gallon). The shallowest occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 738 and 215 feet TVDSS, respectively. So, the entire proposed disposal zone likely contains methane gas. Within porous sands, resistivity measurements all fall below l0nhm-meters., and no significant hydrocarbon zones are evident on the Noatak 1 well log. Supporting documentation to ConocoPhillips' annular disposal application states: '`There are no USDW aquifers local to the Noatak area." This is correct. Calculations within five clean sands between 1,610 and 2,300 feet TVDSS all exceeded 10,000 ppm TDS. • • Noatak No. 1 March 9, 2007 Note to File Page 3 of 5 Figure 2. Offset well Kokoda No. 5 -Correlative Upper Confinement Zones and Potential Receiving Zones • • Noatak No. 1 Note to File Figure 3. Noatak No. 1 -Potential Receiving Zones and Lower Confining Zones March 9, 2007 Page 4 of 5 Noatak No. 1 Note to File March 9, 2007 Page 5 of 5 No mud log is currently available from Noatak 1, but the shallowest oil show in nearby well Kokoda 5 occurs at about 6,300 feet MD (6,135 feet TVDSS), well below the likely injection zones for any waste injected into the annulus of Noatak 1. The operator reported no shows within the proposed Noatak 1 injection interval or confining zones. The following chart provides an estimate of the affected area surrounding the Noatak 1 wellbore. Assuming a 30-foot thick injection zone with 25% porosity and a maximum of 35,000 barrels of injected waste, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 95 feet from the wellbore. Injected Fluid vs Affected Distance from Noatak No. 1 Wellbore (assumes 30-foot thick zone having 25% porosity) 150 - I i i d ~ d 0 100 { a 3 E V _ .~--__ C l° ~~'_ w ~+"' #, '" d 50 ~~ , d A~~' Q • . i 0 +'/ ___ _ ____ 0 5,000 10,000 15,000 20,000 25,000 Amount of Injected Fluid (barrels) 30,000 35,000 Figure 4. Noatak No. I -Radius of Potentially Affected Injection Zone The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 700 feet of permafrost, and is bounded above and below by continuous layers of claystone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations. The proposed injection zone well away from any external property lines, so correlative rights will not be a concern. I recommend approva of this annular disposal project. Steve Davies Senior Petroleum Geologist • AOGCC.jpg (JPEG Image, 889x694 pixels) • NOATAK 1 ~ £~ so~~szoal~aa~ ao~ ~y ~ ~~n~~~~Ph i I ~I p TLGAS o ion PI~LIEf f . SZ~4 1 ~ RXt? 1 _ ---- ----- -- - M ~ 0 Q9 -_ ". 1.au~oni t ~ ~ - `d PHITotal YSRM LOG 'd RH~B - - ~-,.~ - _ - ~ ~ , b V'; 0 .1 10 ~ ~ 65 G, C3 2.65 - - ==~7Shale: ' ° ' ' PHIEf f . RT 1 ~~~ NPHI o ®~ ~~~ C VV ~ .6 V'; V' 0 ~-~~C•n MAi 1~0 ~~ __ __ `.`......... 71 Q Q (~ .....w 710 0 --- - - _ - - _ _ ... i c ~f - -z::~ - - - - _ -- - ------ - - ______ ______ ~1...- - ~ s r - - - - - ~; ..... 72QQ - - ___.. 7200 --- ~ ......... ____ 73ao • 7300 -r:= 3/6/2007 7:49 AM RE: Noatak#1 (205-042) • Subject: RE: Noatak #1 (205-042) -From: "Brasfield, Tom J" <TOM.J.Brasfield@conocophillips.com> Date: Fri, 09 Mar 2007 11:38:31 -0900 To: Thomas Maunder <tom maunder@admn.state.ak.us> CC: Kuukpk 5 Company man <KUUKSCM@conocophllps.com> Tom, 1. The sack count (per Dowell) for the surface job is 80 sks of LiteCRETE tail (approx 500' +500) and 220 sks of ARCTICSET Lite lead. The original design did not include plans for a stab-in job which accounts for the lesser volumes. Because of the remote operations this year we wanted to keep the cement returns to a minimum. 2. Discussed with Ray (who was on the job) and we did not get an estimate of the volume circulated to surface. Just that we had good cement returns to surface without any losses. The excess was handled by the super sucker on location. Tim Lawlor with the BLM was on site for the surface job as a witness. Thanks, Tom -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, March 09, 2007 10:29 AM To: Brasfield, Tom J Subject: Noatak #1 (205-042) Tom, We are evaluating the annular disposal request submitted yesterday. I have a couple of questions. 1. Do you have the sack # for the lead and tail? Volumes are given, but I's like the sack numbers if you have them. It appears comparing with the volumes calculated for the permit application that less cement was pumped, but that is a moot point since cement was circulated. 2. How much cement was circulated? I thought you had provided that information. previously, however I am not able to find it. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Re: Noatak #1 Weekly Status & 7" cement pla~ Subject: Re: Noatak #1 Weekly Status & 7" cement plan From: Stephen F Davies <steve_davies@admin.state.ak.us> Date: Mon, OS Mar 2007 17:43:55 -0900 To: "Brassfield, T©m J" <TOM.J.Brassfield@conocophillips.com> ~S `C~ y CC: tam_maunder@admin.state.ak.us, greg_noble@ak.bim.gov, "Campaign, Wayne" <Wayne.Campaign@conocophllips,com>, "Alvord, Chip" <Chp.Alvord@conocophillips.com> Tom, I concur with Wayne's analysis. The turidite sand encountered by the Noatak 1 well between 7210 and 7245' MD is poor quality and has elevated water saturation. The planned top of cement at 7000' MD will adequately isolate this sand. Please call me if you have any questions. Steve Davies AOGCC ~~~-1224 (work) ----- Original Message ----- From: "Brassfield, Tom J" <TOM.J.Brassfield@conocophillips.com> Date: Monday, March 5, 2007 2:48 pm Subject: Noatak #1 Weekly Status & 7" cement plan To: tom maunder@admin.state.ak.us, greg noble@ak.blm.gov Cc: steve davies@admin.state.ak.us, "Campaign, Wayne" <Ptayne.Campaign@conocophillips.com>, "Alvord, Chip" <Chip.Alvord@conocophillips.com> Tom/Greg, attached is the weekly status of the Noatak #1 well. Also, the plan for the 7" cement volume is to pump a calculated amount to bring TOC to 7000' MD/TVD or approx. 180 sks at 1.16 cuft/sk. See attached email from Wayne Campaign. Thanks, Tom «Noatak #1 Well Status as of 3 5 07.doc» «Cement in Noatak» Cement in Noatak Subject: Cement in Noatak From: "Campaign, Wayne" <Wayne.Campaign@conocophillips.com> Date: Mon, 5 Mar 2007 10:35:00 -0900 To: "Brassfieid, Tarn J" <TOMJ.Brasfield@onocophillps.eom>, "Snyder,:-Frank C" <Frank.C. Snyder@conocophillips.com> CC: "Wilson,. Gregory C" <Gregory.C.Wilson@conocophllips.com> ~v~ -O`~~ «AOGCC.jpg» To Steve Davies, AOGCC Enclosed is the evaluation of the turbidite interval (7210-7245 from the subject well. We contend this is not a significant HC interval and should not need cement to cover. Maximum total porosity is 14.4% while mean total porosity is 11.7%. Mean water saturation is 65%. Mean perm is < 0.2 and and maximum perm is 0.46 md. I have used the Nanuq correlation for this calculation as it is the closest analog, and was confirmed by the Kokoda results. If you would like to discuss further, feel free to contact me. We do request that this confidential information not be disclosed beyond those with aneed-to-know. Thank you. Wayne Noatak #1 Well Status as of 3 5 07.doc Cement in Noatak.eml AOGCC.jpg Re: Noatak (205-042) BOPE Test Extension • Subject: Re: Noatak (205-042) BOPS Test Extension From: Thomas Maunder <tom_maunder cr admin.state.ak.us> Date: Tue, 27 Feb 2007 11:53:19 -0900 To: "Brassrield, Torn J" ~-TOM.J.Brassfieldic~~conuco}~hillips.com C'C: "_~1~ord. Chid" ~'-C'hi~.Al~ord u~conocuphillips.com=~, Kuukpik ~ Compatw man <K[JUK~C'\la,conocophillil7s.com> Tom, Didn't mean to jinx you all. It is acceptable to test when you get out of the hole. Tom Maunder, PE AOGCC Brasfield, Tom J wrote, On 2/27/2007 1 I :12 AM: Tom, we have had another delay in our program. After repairing the kelfy hose we drilled 50' to 7282' and found a crack in one of the 1 mud pump pots. Currently effecting repairs and hope to be drilling around noon, Thanks, Tom -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin,state.ak.us] Sent: Monday, February 26, 2007 2:46 PM To: Brasfield, Tom J Cc: Alvord, Chip; Kuukpik 5 Company man; AOGCC North Slope Office Subject: Re: Noatak (205-042) BOPE Test Extension Tom, et al, It is acceptable to continue as you propose. If the rig is delayed in getting out of the hole, please advise. Tom Maunder, PE AOGCC Brasfield, Tom J wrote, On 2/26/2007 2:29 PM: Tom, per out telephone conversation this date; CPAI would like to request an extension to the 7 day BOPE test requirement at Noatak. The initial BOPE test was conducted on 2/19/07. The current plan is to drill to the base of the HRZ (which could be as deep as 7650' MD/TVD) and POOH for a rotary BHA to pick 7" casing point. The BOPE test would be conducted at this time. Should reach this projected depth on or before report time tomorrow. Current depth is 7232' MD/TVD with a kelly hose change-out in progress. Thanks, Tom 1 of 1 2/27/2007 1:43 PM Re: Noatak # 1 Surface Casing Setting Depth -~ • Subject: Re: Noatak #1 Surface Casing Setting Depth From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 13 Feb 2007 15:02:10 -0900 'To: "Brassticld, hoi1~ J" ~~:TOM..I.Brassti~ld«1conocohhillips.com- CC: Kuukpik ~ Corz~pany man ~~K[IL'K~C1~~1'u'con~~cophillips.com~=, "_~l~~ord. Chip~~ °-C.hip..<~lvorcl(~!conocc~phillips.com~- Tom, ~~-~ ~- As we discussed. The ultimate casing depth will be based on your correlation and the new information from drilling. Good luck on the well. Tom Maunder, PE AOGCC Brasfield, Tom J wrote, On 2/13/2007 2:58 PM: Tom, per our telephone discussion; CPAI would like to request a deeper setting depth for the 9-5/8" casing shoe. The current PTD specifies 2600' MD; however based on the Geologist's correlation with the Kokoda #5 & #1 wells we may need to drill to 2800'-2850' to get some small sand stringers behind pipe. Thanks, Tom 1 of l 2/13/2007 3:02 PM Page 1 of 1 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder@admin.state.ak.usJ ~ 0 S ~ a ~„~~., Sent: Monday, January 08, 2007 3:26 PM To: Brassfield, Tom J Subject: Re: Noatak Change in Rigs Thanks Tom. I will put a copy of the information in the file. Tom Brassfield, Tom J wrote, On 1/5/2007 1:07 PM: Tom, per our phone messages CPAI is planning to utilize Kuukpik Rig 5 instead of Doyon 141 to drill the Noatak #1 well (PTD #205-042). The Rig info for Kuukpik Rig 5 was submitted recently with the Intrepid #2 PTD, but is also included in this email. We are hoping to spud Noatak #1 around 2/7/07. Thanks, Tam «11 inch bop elevation 8 31 06.pdh> «11 inch BOP Nov 2006.pdfi> «20 Inch Diverter Nov. 2006.pdf» «Kuukpik Rig 5 BOP Schematic 1 5 07.doc» «Kuukpik Rig 5 Choke Manifold.pdf» «Kuukpik Rig 5 Diverter Schematic 1 5 07.doc» «Modified Mud System Drawing 2 by LR 11 13 06.pdf» «Mods Kuukpik Drilling Rig 5 by TJB 8 21 06.pdfi> 7/18/2007 Noatak Change in Rigs 'Content-Description: Kuukpik Rig 5 Diverter Schematic 1 5 07.doc Kuukpik Rig 5 Diverter Schematic 1 5 07.doc Content-Type: application/msword Content-Encoding: base64 Modified Mud System ', Content-Description: Drawing 2 by LR 11 13 Modified Mud System Drawing 2 by LR 11 13 06.pdf ; 06.pdf '; Content-Type: application octet-stream Content-Encoding: base64 Content-Description: Mods Kuukpik Drilling Rig 5 by TJB 8 21 06.pdf Mods Kuukpik Drilling Rig 5 by TJB 8 21 06.pdf Content-Type: application/octet-stream Content-Encoding: base64 2 oft 1/8/2007 3:03 PM - CD ~ G N N N O ~ - 005'Ol N 7 O C ,~ O - O ~ ~ M f'M O N N Q' Cn N ~ ~ O Y U w ~ d N 7 ~ d Q t O m y CO L ~ ~ 1n l6 O ~ m ~ `Q ,~ t_O u~ fh Y fC O L ~ - - U ~ ~ N a o, s m N ; ~ f6 U 7 O ~+ - 000'Sl ~ v ~ X~ xl I ~ a CJ ~ m _ v . ; ~ io II IV ;,I h g ~I ,i 11" BOP Stack Kuukpik Drilling Rig 5 11/22/08 Rig Floor r Line Opening 20" DIVERTER KUUKPIK DRILLING RIG 5 11/22/06 ~J 11" 5000 psi BOP Stack Kuukpik Rig 5 NPRA Exploration Accumulator Caoacitv Test 1. Check and fill accumulator reservoir to proper level with hydraulic 6 Fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then dose all units simultaneously and record the time and pressure remaining after all units are Gosed with the charging pump off. 4. Record on the IADC report The acceptable lower limit is 45 seconds dosing time and 1200 psi remaining pressure. 5 Kill Line Choke Line Check Hyd Man 4 Man Hyd BOPStad<Test 1. OP sfadc and manifold with water. 2. Check that all holddown screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed bads to zero psi. 5. Open annular preventer and manual kill and choke line valves. 2 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi low for 5 minutes and 5000 psi high for 10 minutes. )~QI pressure test any choke that is not a full dosing ,~ positive seal choke. 8. Open top pipe rams and dose bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Bad<off runningjaint and pull out of hole. Close blind rams and test to 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure man"rfold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP l0 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart Sign and send to drilling engineer. 14. Perform BOPE test a) when initially installed , b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 7 day intervals. Functionalty operate BOPE daily . 15. Pit drills are to be conductled weekly for each drilling crew . 1. 16" Starting Head 2. 11"5000 psi Through Bore System Wellhead 3. 11"5000 psi Shaffer LWS Gate (pipe rams), 4-1/16" 5000 psi Side Outlets w/ Manual Locks 4. 11"5000 psi Drilling Spool with Choke and Kill Lines , 2 Choke valves -one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate 2 Kill valves -one 2" 5000 psi Hydraulic gate and one 2" 5000 psi Manua{ gate 1 Chedc valve in Kill Line - 5000 psi 5. 11"5000 psi Shaffer LWS Double Ram (pipe rams on top, blind on bottom), 4-1/16" 5000 psi Side Outlets w/ Manual Locks 6. 11"5000 psi Hydril GK Annular Preventer, Flange Connection TJB 12/22/06 M! 14 To Shaker 3" Panic To Gasbuster 3 118" 2 1 J15,1R ~,, C'e `.«.. =5.... ` y -, \ 2 1 / 15„ 2 1110„ anual Choke ~ ~~~ ~ '~ Automatic Choke 2 1110° Inlet Pressure Sensor „ 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RECD _ 1118°' 5.000 PSI VALVES A D LI ES BLUE = 2 1110" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold Drawn By: L Ross Date: 8/1 /04 i~ 21-1/4" DIVERTER SCHEMATIC Kuukpik Rig 5 NPRA Exploration To Accumulator From Accumulator Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer /open the valve in the event that an influx of wellbore fluids or gas is detected . DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 21 -1 /4"Diverter Spool with API 21 -1 /4" 2000 psi Flanges 5. 21 -1 /4" x 21-1/4" 2000 psi, Double Studded Adapter Flange (Optional ) 6. 21-1/4" Hydril MSP 2000 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer 8. 16" Diverter Line TJB 12/22/06 Mud Tanks Nfith Tank Cortpartments and Agitators Shaker Tank Voume Tank Suciion Tank Agitators Td~Tank Shaker Tank ~. '. ' 30 BL5 160 BBLS 'i Degasser Te~lk CenUi/uge Tank Voume Tank Suction Tank Pip ~ank 70 BBLS '- 130 BBLS ~ 80 BBLS 80 BBLS 30 BLS 100 BBI '~ 175 BBL Underllow Tenk 9 Pre Mix Tenk 1 m $ m __ 225 BBL ~ Pre Miz tank 2 3 520 BBLS Active Volume 30 BBLS Tdp Tenk 30 BBLS Ppl Tenk 100 BBL prc rNx 100 BBL undertow 200 BBL waste 2 Derdck 2000 Shaken 1 Demck Shaker Upper Building 1/~Fth Sdids Equipment Vaccum Degaaaer 1 ~ Centdtuge ~J Sweco 516 I ~__~r-~L Underllow Pump ~b ---~ ~ ~ UN. Chemical BBI 1 U Jet Hopper Mizlfransfer Pumpa I '_J~ I _. _ _ Shear Hopper Mix?ransfer Pump Rig 5 mud system with modifications Kuukpik Drilling Rig 5 Modified Mud Tankage and Sdids Equipment Drawn ey: L Ross Date 2115/05 • • Kuukpik Drilling Rig 5 Inventory ConocoPhillips NS Exploration 8/15/06 Rig 5 is a winterized 400,000 pound rated Telescopic Double that is containerized except for the substructure and derrick package. Capacity: • 11,500' rated depth (Capable of standing back 9,500' of 4 %z" drill pipe with 6'/z" tool joints plus HW and BHA) or (12,000' of 3 1/2"' or 4" with 5 '/4" tool joints plus BHA.) Drawworks: • Tesco Hydraulic Single Drum Drawworks, Lebus grooved for 1 1/8" drill line. The Drawworks is equipped with two 50" disk brakes, two calipers for the working brake. The hydraulic system is used as the dynamic brake. Rig Power (hydraulic): • Two Series DDEC IV Detroit Diesel. Maximum continuous power 600 kw (800 HP); maximum power 634 kw (850 HP) each. • Each engine driving 6 Linde HPV 130 hydraulic pumps. • Total rig hydraulic power 1,200 kw (1,600 HP). • These units provide power for the Drawworks, top drive and one mud pump. Mast: • Tesco 102' double telescoping, freestanding. • 400,000-pound maximum static hook load, with 8 lines. • Certified and built to API 4H specs. • Winterization around the racking board to include a warm up house for the derrick man. Substructure: • Tesco Swing Up 20' high x 12' wide x 40' long (land use).. • KB (rotary) to ground 20'6", Usable BOP height is 15'. • Casing capacity 400,000 pounds simultaneous with 200,000 pounds setback. • One set of hydraulic cylinders mounted horizontally under the floor for lifting the BOP stack for setting slips, etc, or for moving the BOPs on or off the BOP dolly. Crown Block: Tesco maximum static load 400,000 pounds with 4 sheaves, split block. • Traveling Block/Hook: • Tesco 400,000 pounds split block. Swivel: • Tesco integrated swivel with top drive. Top Drive: • Tesco Mode1250 HMI Top Drive (250 ton). • Maximum Torque 20,600 ft-Ibs, Maximum Speed 175 rpm. • Includes all standard Tesco pipe handling and safety features. • 3" x 55' rotary hose. Rotary Table: • TSM 17.5" opening -hydraulic driven Pump #1 and Pump #2 • #1 Pump: One each Ellis Williams WH 1000 A Triplex: 6" x 10" stroke. • Powered by a Hagglund Hydraulic motors producing 746 kw (1000 HP). • Equipped with PD 45-5000 pulsation dampener. • Operating Range - 0 spm to 150 spm. • Maximum Allowables: (90% of manufacturer's specifications). • #2 Pump: One each TSM 1000 HP triplex pump • Powered by one each 1000 hp AC electric drive motor • Equipped with PD 45-5000 pulsation dampener. • Operating range - 0 spm to 120 spm. • Maximum Allowables: (90 % of manufacturer's specifications). Mud System: • Three tanks, 8' wide x 6'9" high x 20' long: six compartments. • -Active capacity 520 bbls. • -Trip tank 30 bbls. • -Pill tank 30 bbls. • 5 each 7.5 HP agitators. • Mixing room with 3 Mission 5 x 6 centrifugal pumps @ 3600 rpm powered by 2 x 22.5 kw (30HP) and 1 x 30 kw (40HP) electric motors. • Harrisburg mixing hopper. • Two each Derrick Flowline Cleaner Shale Shakers. • One each Swaco 518 centrifuge. • One mud mixing building 34' long and 8' wide with two each overhead doors to allow for two pallets of mud at one time. A 2"d shear hopper and mix pump would be located in this building. 2 • • Two each 200 bbl pre mix tanks, (400 bbl total} complete with agitation and upper buildings with heat and lights, located by the mud mix building. The centrifugal pump and shear hopper referenced above would provide mixing capabilities for these tanks as well as transferring fluids to the active system. Cuttings Drying System/ Injection/Waste System: The cuttings drying system consists of one shaker, two augers, lights, heat, 4 each forklift style cuttings buckets and a 100 bbl underflow tank with pump. The cuttings will come from the rig shakers into an auger that will deposit them on the dewatering shaker. The liquids will fall through the shaker screen into the insulated underflow tank which then could be disposed of or pumped back to the active system. The solids will go into a reversible auger to the forklift cuttings buckets. The injection/waste fluid tank will consist of one each 175 bbl insulated tank with 2 each agitators a vertical transfer pump and line capable of rolling the mud. In the tank enclosure building located above will have heat and lights and house the 2nd 518 centrifuge. Well Control System: Accumulator: • Control Technology 5 Station Accumulator • 170 gallon reservoir • 12 each 15 gallon bottles • Nitrogen backup system • Complete with pneumatic pumps and electric triplex pump Choke Manifold: • 5,000-psi choke manifold mounted in a separate container located next to the substructure. • One Willis 2" manual choke, one Master Flow 2" Hydraulic Remote Choke. • Choke line valves consist of one manual and one Hydraulic valve. • Kill line valves consist of two each manual valves. • One each 5,000 psi upper Kelly valve. • Two each 5,000 psi lower Kelly /Stab in safety valves. • One each 2 1/16" 5,000 psi rated check valve for kill line. Mud Gas Separator: • (Gas buster) located in a separate building beside the sub/shaker building. • • • 30" diameter x 16' high; 3" inlet; 8" outlet. And 10" vent line. Vacuum Degasser: • One each Derrick vacuum degasser. B.O.P.s: (Rental) • One each 11" 5,000 psi Annular • One each 11" 5,000 psi Double Gate • One each 11" 5,000 psi Single Gate • One each 11" 5,000 psi Mud Cross with 3"outlets • One each 11" 5,000 psi spacer spool 3' long • One each Flow Nipple • Ram Blocks included: a. Two sets 4" b. Two sets 4 '/z" c. One set 7" d. One set 3 '/2" e. Two sets Blinds f. One set 2 7/8" to 5 '/2" VBR's Diverter System: • One each 13 5/8" diverter system complete with a 13 5/8" annular and diverter spool with one each 16" flanged outlet. • One each 16" hydraulic operated knife valve • 100' of 16" diverter line complete with flanges, bolts and gaskets. BOP Test Pump: • One each triplex test pump electrically driven, rated at 4.6 gpm at 5,000 psi • Complete with pressure gauges, hoses, and valuing. Instrumentation: • Weight Indicator -PLC controlled. • Pason Electronic Drilling Recorder • Survey Tool - Totco 7 degree wire line drift indicator. • Sierra Monitor (digital) fixed system gas detector for H2S and Methane gas. 3 station. Sensors located at the rig floor, bell nipple and shakers. • Two each GasTech Genesis portable hand held gas detectors. • Pason (Pit Bull Model) Pit Volume Totalizer Tankage: • 700 bbl of rig water storage consisting of one rented 570 bbl Tankco tank and the existing 150 bbl rig water tank. 4 • • 1140 bbls of heated water storage consisting of two each rented 570 bbl Tankco tanks with steam coils. • 7,500 gallon fuel day tank • Two each rental 570 bbl (1140 bbl total) Tankco tanks for fuel storage complete with suction standpipes, and a fuel transfer pump. Portable Vacuum System: • One each 85 gallon portable vacuum system • One 8' x 20' spill contained winterized building to house the vacuum system. Light Plant Generators: • Three each 14 L Detroit Diesel Series 60 (600 HP each) generators. • These provide AC for the rig and power the #2 Pump. • The system is designed to be able to operate all three generators at one time, although two generators are able to operate the rig, with one being a backup. Hydraulic jacking system/Welding unit: • One each 75 KW generator to power the portable hydraulic unit used to raise/lower the sub and derrick. This generator also is designed to provide power to an electric welding machine mounted in the building. Boilers: • Two each 80 HP Volcano Boilers complete with a hotwell tank and a blow down tank. • Approximately 20 steam heaters located around the rig. Rotary Equipment: • Spinner Hawk hydraulic pipe spinner. • Cavins Air Slips 2 3/8" to 5 %" • 2 Sets 4 '/2" Drill Pipe Elevators • 2 Sets hand slips for 4 %" Drill Pipe • 1 Set 6 %" Drill Collar Slips • 1 Drill Collar Clamp • 2 Sets of Rig tongs • 2 Sets of 8' Elevator Bails Drill String: • 11,000' of 4 ''/z" drill pipe, Grade TSS 95 • 16.60 #/ft with TCS-8000 or equal hardfacing • NC-46 (4 ''/z" XH) tool joints 6 3/8" OD x 3 '/4" ID • 600' of 4 '/z" Heavy-Wate DP, 41 #/ft with NC-46 connections • 6 3/8" OD x 2 7/8" ID • 12 each 6'/2" OD x 2 7/16" ID Drill Collars with 4'/2" H90 Connections • Crossovers to be provided: a. Saver subs, 2 each NC-46 Pin down for Top Drive b. HW x DC x-overs, 2 each NC-46 box x 4 ''/z" H-90 Pin c. Bit subs, 2 each 4 ''/2" H-90 Box x 4 '/2" reg Box bored for float d. 2 each upper IBOP (top drive) valves - NC-46 Connections e. 2 each lower IBOP (top drive) valves - NC-46 Connections f. 2 each Full Opening floor safety valves - NC-46 Connections g. 1 each Dart Valve with NC-46 Connections h. 6 each Lift Subs for 6 ''/2" Drill Collars that fit 4 ''/z" Elevators Forklift: • One each 2002 Caterpillar IT62G complete with bucket, forks and material handling stinger. • One each Hyster model no. H360H with 36,000 # of lifting capacity to a height of 21.9'. This unit will be used mainly for rig up of the rig. Casing House: One each casing house consisting of 5 each 9' wide x 56' long buildings. When assembled together, the casing house will be 45' wide x 56' long, capable of holding 10,000' of 7" casing. These 5 buildings can be moved in 6 loads of appx. 40,000# each. Complete with lights and spill containment. One each hydraulic pipe handling machine to move the tubulars from the casing house to the rig floor. One each Scissor lift to index the tubulars from the pipe racks to the catwalk. Rig Shop: The rig shop will consist of 8 buildings that, when assembled, will make a 19' wide x 38' long shop with an 18' high x 14' wide door. This building will be easily assembled with the Hyster loader. In additions to the shop, there will be appx. 3 each 8' x 20' parts house buildings to hold rig parts, etc. Complete with lights and heat. Hot Air Heaters: • Two each diesel fired Hot Air heaters, one for the Casing House, and one for the Substructure. The one for the casing 6 ~ i house is a 2 million BTU and the one for the Substructure is a 1 million BTU. Complete with heat ducting. One each 600,000 BTU portable trailer mounted diesel heater for use during rig up. Portable Light Stands: • 4 each portable generators with light towers to use around the location during rig up and operating. • Ample lighting around the outside of the rig to provide a lighted area while operating. Rig Mats: • Ample rig mats (appx. 40) to use under the Rig, shop, fuel and water tanks. Pickups:. • Two each Crew Cab pickups 7 r ~ ~ ~ a °~ ALA-5SA OIL A11TI) GAS COI~TSERQA'TIO1~T COMI~II5SIOIQ Paul Mazzolini Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchoraga, Alaska 99510-0360 Re: Noatak #1 l~J ;~ FRANK N. MURKOWSKI, GOVERNOR J J 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 ConocoPhillips Alaska, Inc. Permit No: 205-042 Surface Location: 2503' FNL, 1932' FWL, SEC. 22, T12N, RSW, UM Bottomhole Location: 2503' FNL, 1932' FWL, SEC. 22, T12N, RSW, UM Dear Mr. Mazzolini: 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. 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 10-403RD prior to the approval of disposal operations. 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. In your application, you indicate that testing will likely not be possible due to time constraints. However if testing does become part of the plan, a Sundry Application (Form 403) detailing the planned activities should be submitted for approval. 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 ~ r result in the revocation or suspension of the permit. hours notice for a representative of the Commission Commission's petroleum field inspector at (907) 659- ~i ~_ DATED this -Ida of March, 2005 Y • provide at least twenty-four (24) ass any required test. Contact the ;er). cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 REC~IV p~~~ MAR 1 7 20G5 A~w~L~ A:1 A n 1a. Type of Work: Drill ^/ Redrill Re-entry ^ 1b. Current Well Class: Exploratory / Development Oil Ip Stratigraphic Test ^ Service ^ Development Gas ^ Afl~hO!'le Zone Q 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: Noatak #1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9000' TVD: 9000' 12. Field/Pool(s): NPRA Exploration 4a. Location of Well (Governmental Section): Surface: 2503' FNL, 1932' FWL, Sec. 22, T12N, R5W, UM 7. Property Designation: ALK AA-081839 ~ Top of Productive Horizon: 2503' FNL, 1932' FWL, Sec. 22, T12N, R5W, UM 8. Land Use Permit: ADL AK-5184 13. Approximate Spud Date: April 5, 2005 Total Depth: 2503' FNL, 1932' FWL, Sec. 22, T12N, R5W, UM 9. Acres in Property: 5756 14. Distance to Nearest Property: 1932' ~ TD 4b. Location of Well (State Base Plane Coordinates): Surface: x- 607019 y- 5989361 Zone- 5 10. KB Elevation (Height above GL): 28' RKB & GL 134' 15. Distance to Nearest Well within Pool:Kokoda #1 , 6.5 miles 16. Deviated wells: Kickoff depth: 0 ft. Maximum Hole Angle: 0° 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 4306 psig /Max. Surface Pressure: 3297 psig 18. Casing Program Setting Depth Quantity of Cement Size S ecifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16'" 63# B PEB 8Q' Surface Surf. 108' 108' 190 sx AS I 32.25" 9.525" 40# L-80 BTC 2572' Surf. Surf. 2600' 2600' ~ 370 sx ASLite, 160 sx DeepCRETE 8.5" 7" 2"n# L-8G` BTCM 8284' Surf. Surf. 8312' 8312' 180 sx Class G + additives 6.125 4-112" 12.6# ~-80 iaT->L1 838` 8162' 8162' 9000 9000 120sx Class G + additives 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD {ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program ^/ Time v. Depth Plot / Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact TOm erassfield 265-6377 Printed Na a Paul Maz lini Title Drilling Team Leader Signature Phone Date~~ ~; ~, Tom Brasfield 5-6 77 Commission Use Only Permit to Drill Number: ~~~~--L~~ API Number: 50- ~~~-- ~~~~~ Permit Approval Date: See cover letter for other requirements Conditions of approval : Samples required ®Yes ^ No Mud log required ®Yes ^ No ydrogen sulfide measures ~ Yes ^ No Directional survey required ^Yes ~ Nod 50 s 3 P ~cs~. ~--0` ~j~o.>.~'1" c~.s~r~wci~ve~ Pic- OOASAC~ 5 ,03~ `~ `~ ~.i~< Other: C t APPROVED BY , n~j J Approved ,A.,, ' ) ~~ 4 THE COMMISSION Date: V v Form 10-401 R d 06/2004 / Submi ~n duplicate ~3~ r ConocoPhillips Box 100360 Alaska 99510-0360 March 16, 2005 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location Dear Commissioner: ~~ ~~~~ -~ `~ 2005 piaslca i.iu ~x Gas Dons. Commissian Anchorage Noatak #1 (Exploratory Test) 2503' FSL, 1932' FWL, Sec 22, T12N-R5W X=607,019 & Y=5,989,361 ASPS NAD27 2503' FSL, 1932' FWL, Sec 22, T12N-R5 2503' FSL, 1932' FWL, Sec 22, T12N-R5W ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve -Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling an 8-1/2" wellbore to the top of the objective with a LWD logging suite for - evaluation. A 7" intermediate casing will be run in order to case off potentially sensitive shales and drilled out with a 6-1/8" bit. Only a minimal amount of hole (<1') will be drilled before POOH to pick-up a coring assembly. At least one 60' core will be cut through the objective zone beginning immediately below the 7"shoe if time allows. The well will then be drilled to TD and depending on the logs either a 4- 1/2" liner will be run and the well completed or the well will be P&A'd. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" intermediate casing, a 4-1/2" production liner and either 4-1/2" or 3-1/2" tubing. There is a possibility that CPAI could request authorization for the disposal of drilling waste via the annulus by filing with the AOGCC a 10-403 supplement with additional information as required under 20 AAC 25.080. Please find attached information as required by 20 AAC 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 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2)- straight hole. r ~ 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as required by 20 AAC 25.035 (a) (1) and (b) have been submitted previously. 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a). (Previously submitted- on record) 8) ConocoPhillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 9) Complete logging, coring, and mud logging operations are planned and descriptions are attached. The following are Conoco Phillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 2) Geologic Data and Logs Greg Wilson, Geologist (20 AAC 25.071) 263-4748 The anticipated spud date for this well is April 5, 2005. If you have any questions or require further information, please contact Tom Brasfield at (907) 265-6377 or Paul Mazzolini at (907) 263-4603 Sincerely, Tom Brassfield Senior Drilling E gineer cc: CONFIDENTIAL -Noatak #1 Well File Paul Mazzolini ATO-1570 Bill Smalstig ATO-1380 Conoco Phillips Alaska, Inc. Drill and Case Plan for Noatak #1 General Procedure: 1. MIRU Doyon 141 over pre-installed 16" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 1/4" hole to the surface casing point at 2600' MD/2600' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. ` ^ Employ lightweight permafrost cement lead slurry and Dowell DeepCRETE high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. __---~ 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 ~/2" bit and BHA and RIH to top of float equipment ^ Pressure test casing to 3000 psi for 30 minutes ^ Record results and fax to town 8. Drill float equipment and approximately 20' of new hole ^ Perform LOT (or FIT if gradient reaches 16 ppg equivalent) ^ Record results and fax to town 9. Drill 8~/z" hole to top of Jurassic at approx. +8312' MD/±8312' T~/D. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. Will trip to pick-up rotary BHA, placing GR/Resistivity as close to bit as possible to assist in picking casing point. 10. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 8312' MD / 8312' TVD). Cement casing to bring cement +1000' above 7" shoe. 11. Make up 6 1/8"mill tooth bit and BHA and RIH to top of float equipment ^ Pressure test casing to 3000 psi for 30 minutes ^ Record results and fax to town 12. Drill float equipment, circulate & condition mud, displace to coring fluid and TOOH. (LOT is not planned for this casing string -see attached explanation). ~--~-~-~ __----- 13. PU core barrel (if time permits), RIH and core at least one 60' core. TOOH, LD core barrel and PU 6- 1/8" bit and drilling assembly and TIH. 14. Drill 6 1/8" hole to ±9000' MD / +9000' TVD. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. ^ Condition hole and mud for a-line logs. 15. Log 6-1/8" wellbore as necessary. 16. Run and cement 4 ~/z" 12.6# L80 IBT-M Liner 17. Make a cleanout run with bit and scrapers ^ Displace to filtered seawater or brine- depending on formation pressure. ^ Pressure test well to 3000 psi for 30 minutes (perform low pressure test on liner lap). ^ Record results and fax to town 18. Run and land 3-1/2" or 4 ~/2" tubing with gas lift completion 19. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 20. Secure well, release rig. Conoco Phillips Alaska, Inc. 21. Upon completion or if the well is not completed, plug and abandon the well, or temporarily shutdown per applicable regulations. Thoroughly clean location and block off further ice road access to location. Conoco Phillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Noatak #1 Drilling Fluid Prouerties: Spud to surface casing point Drill Out Production Hole Intermediate hole (Intermediate shoe to TD Density 9.5 - 10.2 ppg 9.5 - 11.3 ppg 9.8 - 9.9 ppg PV 16-26 6-20 15-25 YP 25-35 5-20 14-24 Funnel Vis 50 - 100 35 - 50 50 - 70 Initial Gel 10 - 20 2 - 6 3 - 6 lOMinuteGel 15-40 14-20 3-8 API Filtrate 7 - 15 < 6 below 7000' <10 pH 9.5-10 9.0-10 9.0-12.0 Solids t 10% < 11% < 8% Drilling Fluid System: Equipment list for Doyon 141 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticiaated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size Casing Settin De th Fracture Gradient Pore Pressure Gradient Pore Pressure MASP Drillin 16" 108' MD / 108' TVD 11.0 8.33 47 NA 9-5/8" 2600' MD / 2600' TVD 13.5 8.33 1126 50 si 7" 8312' MD / 8312' TVD 17.6 9.8 4236 1539 si 4-1/2"" 9000' MD / 9000' TVD 18 9.2+ 4306 3297 si Expected Maximum Mud Weights: 12-1/4" surface hole to 2600' MD / 2600' TVD: 10.2 ppg ' 8-1/2"Intermediate hole to 8312' MD / 8312' TVD: 11.3 ppg (for shale stabilization) 6-1/8" Production Hole to 9000' MD / 9000' TVD: 9.9 ppg ' Conoco Phillips Alaska, Inc. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the 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: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP =Maximum Anticipated Surface Pressure FG =Fracture Gradient at the casing seat in Ib/gal 0.052 =Conversion factor from Ib/gal to psi/ft 0.11 =Gas Gradient in psi/ft (above 10,000' TVD) D =True vertical depth to casing seat in ft from RKB OR 2) MASP =FPP - (0.11 x D) Where: FPP =Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D _ [(11.o x o.052) - 0.11] x 108' = 50 psi OR MASP =FPP - (0.11 x D) = 1126 - (0.11 x 2600') = 840 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(13.5 x 0.052) - 0.11] x 2600' MASP = 1539 psi OR MASP =FPP - (0.11 x D) = 4236 - (0.11 x 8312') = 3322 psi 3. Drilling below 7"Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(17.6 x 0.052) - 0.11] x 8312' MASP = 6693 psi OR MASP =FPP - (0.11 x D) = 4287 - (0.11 x 9000 = 3297 psi Conoco Phillips Alaska, Inc. Casing Design Pertormance Properties Size Weight Grade Connection Internal Yield Collapse Tensile Strength 16" 63 f B PEB Conductor Casin Joint Body 9-5/8" 40 f L-80 BTC 5750 si 3090 979 M 916 M 7" 26 f L-80 BTC-M 7240 si 5410 667 M 519 M 4-1/2" 12.6 f L-80 BTC 8430 si 7500 si 304 M 267 M Casing Setting Depth Rational: 16" @ 108' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8" @ 2600' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8-1/2" hole to top of reservoir. 7" @ 8312' MD RKB Intermediate casing is set strictly to provide isolation of potentially troublesome shales. The shoe of this casing will be set immediately into the top of the objective with a planned core to be taken immediately below the 7" shoe if time allows. A LOT would require 20' of additional hole to be drilled and would jeopardize targeted core recovery. Bottom hole pressures are available from offset data in the area. Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Noatak #1 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached mud weight versus depth graph for the offset well Kokoda #1 and the offset wells listed in the pore pressure analysis report dated 11/20/04. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. Note that cement rinseate will not be infected down the dedicated disposal well but will be recycled or held for an open annulus.) The Noatak #1 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. PAI may request approval to inject or dispose of fluids in the Noatak #1 9-5/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 AAC 25.080. Conoco Phillips Alaska, Inc. Geolo4v• Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID TYPE EST. PORE PRESSURE si Permafrost 910' 200' 412 Nanushuk 1130' 200' 489 Torok 3210' 200' 1390 Brookian 6680' 200' 2893 H RZ 7320' 200' 3171 LCU 7590' 200' 3868 Top Jurassic UJU/J4 8150' 200' Probable Oil and/or Gas 3890 TD 8838' 4228 Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 -Surface Casing setting depth) LWD: GR/Res ' 8-1/2"Intermediate Hole (Surface Casing setting depth to Top J4/UJU) LWD: GR/Res/Density/Neutron/PWD ' 6-1/8" Production Hole (7" Shoe to TD) LWD: GR/Res/Density/Neutron/PWD Wireline: GR/Res/CMR/MDT/VSP (Contingency: PEX/RSWC/Dipole Sonic) II. Coring- if time allows Full Diameter 2.5" Core in Upper Jurassic (1- 2, 60' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful II. Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TD. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and HZS detection Thirty to sixty-foot (30'-60~ wet and dry samples will be collected from surface to surface casing setting depth. . Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to well TD and ten-foot (10') wet and dry samples, or continuous, collected across any hydrocarbon . intervals. s Conoco Phillips Alaska, Inc. III. Flow Testing End of Winter drilling season will not allow enough time to test this year. Conoco Philli s Alaska Inc. p , Noatak #1 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12-1/4" Hole / 9-5/8" Casina Interval Event Risk Level Miti ation Strate Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud tem eratures Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted swee s, reduce fluid viscosi control ROP. Abnormal Pressure in Low ~ Diverter drills, increased mud weight Surface Formations Lost Circulation Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled runnin seeds. 8-1/2" & 6-1/8" Hole Event Risk Level Miti ation Strate Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- lanned LCM ills, lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, wei hted swee s. Directional Control Medium BHA design, on-sight geologic review and advisement of otential slum blocks. Sloughing Shale, Tight High Increased mud density and fluid Hole `~ composition according to plan, controlled tri seeds, swee s, ECD monitorin . Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contin encies for to set casin strin . Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scaven ers 1000' 2000' 3000' 4000' 5000' 3000' 7000' 8000' 9000' Well: Noatak #~ TVD/M D ~ Est. Doyon 141 RKB @ 28' ss to ND is estimated @134' Permafrost @ 910' Field: NPRA Exploration Nanushuk @ 1292' 9-5/8" Csg Pt @ 2600' Torok @ 3372' Brookian @ 6842' H RZ @ 7482' LCU @ 7752' Top Jurassic & 7" Csg Pt @ 8312' TD @ 9000' 0 Vertical Section Estimated Surface Location: 2503' FNL, 1932' FWL Sec.22, T12N,R5W,UM -- DRILLING TIME AND MUD WEIGHT CURVE -•--Depth 16" set @ 108 ~-Mud Wei ht Kokoda #1 9_ 0 ~-r-T - I - ~ --, --r r- ,- , I T - -r---r , , r --~ 12 --I--+--I-- -J--~-+--I-- --I__L_J-. _I-- __I__L_J__L_ __I-. L_-I_-L- - L 1--I--L__.__L_J_-I--+----L-J--L-1___-1.-.-,_--~_J__ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I _ I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I 1 -i F-i--I-- --I--r--1--I-- --I--r--1--r- --I--+--I--r- --r-+--I--+- --F--i--I--+----r-1--r--f----+--I--f-~-- I Drill 12-1/4"Hole I ! ' ' ! J ' ' ! ' ' ' = ' ! ' ! ' ! ' ! ' ' ! ' ' ' ! 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I I I ~. -- 1- .~- ~-~ _ ~- 1-_ ._ _. - ~--,- 0 5 10 15 20 25 30 35 40 45 Spud Well @ 2015 hrs 2/16/05 TIME TO DRILL (DAYS) Release Rig @ 0400 hrs 3/6/05 prepared by TJB 3/10/05 ... CemCADE Preliminary Job :Design 9 5/8" Surface re imnary o agn based on unite input data. r estimate purposes onty. Rig: Doyon 141 Location: Exploration Client: CPAI. Revision Date: 3/16/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 108' MD < Base of Permafrost at 910' MD (910' ND) < Top of Tail at 1,800' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 2,600' MD (2,600' TVD) S~lu~~er~r Volume Calculations and Cement Systems Volumes are based on 350% excess in the permafrost and 45% excess below the permafrost. The top of the tail slurry is designed to be at 1,800' MD. Lead Slurry Minimum pump time: 180 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.7632 ft3/ft x (108') x 1.00 (no excess) = 82.4 ft3 0.3132 ft3/ft x (910' - 108') x 4.50 (350% excess) = 1130.3 ft3 0.3132 ft3/ft x (1800' - 910') x 1.45 (45% excess) = 404.2 ft3 82.4 ft3 + 1130.3 ft3+ 404.2 ft3 = 1616.9 ft3 1616.9 ft3 / 4.45 ft3/sk = 363.3 sks Round up to 370 sks Have 300 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3132 ft31ft x (2600' - 1800') x 1.45 (45% excess) = 363.3 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 363.3 ft3 + 34.1 ft3 = 397.4 ft3 397.4 ft3/ 2.52 ft3/sk = 157.7 sks Round up to 160 sks BHST = 62°F, Estimated BHCT = 71°F. (BHST calculated using a gradient of 2.2°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL III 6.0 288.0 48.0 81.3 LiteCRETE 6.0 70.8 11.8 93.1 Drop top plug 0.0 0.0 5.0 98.1 Mud 7.0 176.1 25.2 123.3 Slow & bump plug 3.0 15.0 5.0 128.3 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, Ty ? 20-25 Centralizers: 1 every other joint thru tail slurry Mark of Schlumberger CemCADE~ Preliminary Job Design. 7" Intermediate Casing re urinary ob sgn ase on mit input ale. r estimate purposes on . Rig: Doyon 141 Location: Exploration Client: CPAI Revision Date: 3/11/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2656205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 9 5/8", 40.0# casing at 2,500' MD < Top of Tail at 7,312' MD < 7", 26.0# casing in 8 1/2" OFI TD at 8,312' MD (8,312' TVD) ~ t1 ~ 1 ~t ~ I { i r Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail slurry is designed for 1000' MD annular length Tail Slurry Minimum thickening time: 160 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.03%B155, 0.4% D167 - 1.16 ft3/sk 0.1268 ft3/ft x 1000' x 1.50 (50% excess) = 190.2 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 190,2 ft3 + 17.2 ft3 = 207.4 ft3 207.4 ft3/ 1.16 ft3/sk = 178.8 sks Round up to 180 sks BHST = 188°F, Estimated BHCT = 140°F. (BHST calculated using a gradient of 2.2°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll Iminl CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 20.0 4,0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 MUDPUSH II 6.0 30.0 5.0 26.0 Intermediate 6.0 36.9 6.2 32.2 Drop top plug 0.0 0.0 5.0 37.2 Mud 7.0 300.0 42.9 80.1 Slow & bump plug 3.0 15.0 5.0 85.1 MUD REMOVAL Recommended Mud Properties: 11.3 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH" II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1 every 2 joints throughout the cement column. 8dilen~ger 41/2" Liner Rig: Doyon 141 Location: Exploration Client: CPAI Revision Date: 3/11/2005 Prepared by: Mike Martin location: Anchorage, AK Phone: (907) 265.6205 Mobile: (907) 229-6266 email: martin13@slb.com Top of Tail at < 7,962' MD < Liner Top at 8,162' MD Previous Csg. 7", 26.0# casing ,~' at 8,312' MD < 4 1/2", 12.6# casing in 6 1/8" OH TD at 9,000' MD (9,000' TVD) Volume Calculations and Cement Systems Volumes are based on 40% excess. Displacement is calculated with a 4.0"- 14.0# drill string. Tail Slurry Minimum thickening time: 120 min. (pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.08%6155, 0.4% D167 - 1.16 ft3/sk Liner Ca3p: 3 0.1276 ft /ft x 200' x 1.00 (no excess) = 25.5 ft Liner Lap: 0.1044 ft3/ft x (8312' - 8162') x 1.00 (no excess) = 15.7 ft3 Annular Vdume: 0.0942 ft3/ft x (9000' - 8312') x 1.40 (40% excess) = 90.7 ft3 Shoe Volume: 0.0854 ft3/ft x 80' x 1.00 (no excess) = 6.8 ft3 Totals: 25.5 ft3+15.7ft3+90.7ft3+6.8ft3= 138.7 ft3 138.7 ft3/ 1.16 ft3/sk = ~ 119.6 sks Round up to 120 sks BHST = 203°F, Estimated BHCT = 150°F. (BHST calculated using a gradient of 2.2°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Stage Time Cumulative Volume Time /bb11 (min) (mini CW100 4.0 10.0 2.5 2.5 Pressure test lines 0.0 0.0 5.0 7.5 CW100 4.0 10.0 2.5 10.0 MUDPUSH II 4.0 20.0 5.0 15.0 Line 4.0 24.7 6.2 21.2 Drop dart 0.0 0.0 5.0 26.2 Mud 5.0 85.0 17.0 43.2 Slow, latch plug, bum lu 2.0 15.0 7.5 50.7 MUD REMOVAL Recommended Mud Properties: 9.9 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1 perjoint from 8162' MD to TD for proper cement placement. Mark of Schlumberger Noatak #1 Proposed Completion Schematic Depths are based on est rig RKB Surface csg. 9-5/8" 40.0# L-80 BTC (+!- 2600' MD / 2600' TVD) Intermediate csg. 7" 26.0# L-80 BTCM (+/- 8312' MD / 8312' TVD) Production Liner 4-1 /2" 12.6# L-80 IBT-M (+/- 9000' MD/9000' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" 9.3# L-80 EUE8rd pin down 3-1/2" 9.3# L-80 EUE8rd Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8rd Tubing to Surface 3-1/2" Camco `DS' nipple w/ 2.875" profile set at +/- 500' MD. 3-1/2" x 6' L- 80 EUE8rd pup installed above and below 3-1/2" 9.3# L-80 EUE8rd tubing to landing nipple 3-1/2" x 1" Camco'KBUG' mandrels w/ DV's and RK latch, 6' L-80 handling pups installed above and below. Spaced out w/3-1/2", 9.3#/ft L-80 EUE8rd tubing as needed. 3-1/2" x 1"Camco'KBUG' mandrel w/ latch & dummy, 6' L-80 handling pups installed above and below. 2 joints 3-1/2" 9.3# L-80 EUE8rd tubing 3-1/2" x 1" Camco'KBUG' mandrel w/ latch & dummy, 6' L-80 handling pups installed above and below. 1 joint 3-1/2" 9.3# L-80 EUE8rd tubing 3-1/2" CAMCO "DS" nipple w/ 2.813" No-Go profile 1 jt 3-1 /2" 9.3# L-80 EUE8rd tubing Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly w/ 12' stroke, 3-1/2" L-80 EUE8rd box up Liner Assembly (run on drilloioe). Baker 7" x 4-1/2"'ZXP' Liner Top Isolation Packer with C-2 profile & 12' PBR Baker 7" x 4-1/2"'HMC' Liner Hanger 4-1/2" 12.6# L-80 IBT-M liner as needed 4-1/2" Baker Landing Collar 1 jt4-1 /2" 12.6# L-80 IBT-M tubing 4-1 /2" Baker Float Collar 2 jts 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Shoe 4-'/2' 12.6 ppf L-80 IBT-M may be substituted for the 3-'/z' TJB 3/10!05 v1 Text Box 0 ConOCOPI'lillips Text Box ROP Rig = AFE D8V5= #VALUE! 0 ' Actual Davs = 0.00 0 hours I I I I ~ I ~/. I I I , I I I I I I I I I I I I Spud = I ' ' ' ~ ' I I I I ' ' I ~ I I I ' ' I I I I I Release = ' I, I I I ~ I I ~ I I I I I I I AFE #= I I I ~1 I I I I I I I I I 1 I I I I I I I I I I I AFE $= I I I I ~I I ~ I I I I ' I I I I I I Actual Total S= $0 1,000 I I ,I ---I---,---r---~ I --I--+,---r---r- --I---,---r---r-- Intan ible$= $0 I I I ~ I ~ I I I I I I I ' ' t ~ I I ' ' ' ' ' ' Non-Planned $ _ $0 I I I I ~ I I I I I I I I I I ~ I , I I I I I I I Change of Scope $_ $0 I I I I, I I I I I I I I I ti I I I I I I I I I Scope Trouble $_ $0 ' ' ' ' ~ I ~ ' ' ' ' ' ~ Trouble $ _ $0 2000 e I I I I ~ I I ---r---r~- --- --- I I I I ' ~ ' ' I---7~ --r---r- I I I I ' ' ' --I---~---r---r-- Mud $ _ $0 i i I I I I I I ~ Planned Time = 0 hours I I ~ I I I 1 I I I I I I~ I, . I I I I I Non-Planned Time = 0 hours I I I '. ~ I I I I , ~ , , I I I I , I I Scope Change Time = 0.0 hours ' ' ' ' I I I I . ~ ' I I I I ' ' I I I I Scope Trouble Time = 0.0 hours I I I , I I` I I I I I ~ Trouble Time = 0.0 hours 3,000 I ~ I I 1 I ---I---~---t---r-r ---~---*---~- • •.. I I I I --~---y---t---~-- . f. I I I TotaICPF= #NUM! I I I I I I I I I I' ~ I I . I I I Intangible CPF = #NUM! I I I I I , I I I I , I I I I I I I I I ` I I I Planned CPF = #NUM! I I I I I I ' ~ I I . I I I Non-Planned CPF = #NUM! I , I , , , I , ~ , , I ~ ~ ~ ~ ~ ~ ' I I ; ~ ; ; II Scope Change CPF = #NUM! ' ' ' ' ' ' ' ' ' ~' ' e Trouble CPF = #NUM! Sco 4 000 I---~---+---~- --~---~--- *- ~- I---1---*---~- p , I I I I ~ I I I ~ I '' ' I Trouble CPF = #NUM! I I I I I I I ~ I ~ I I I I I I I I I I I I I Mud CPF = #NUM! I I I 1 I I '~. I I ' I I I I I I I I ~ I I I~ I I MIRU = 0 hours I I I I I I I , I I I I h I I I I I I• I I Planned Days/lOK #VALU w I I I I I , , , I I u I , I I I I~ I I I , , Actual Days/lOK #NUM! w 5,000 ---I---~---+---~- --I----+---~'--- - --I---~-`--+---~-- Planned TD = ft Q~ I I , I I I 1 1 I I ~ , , °~ Q ' ' ' ' I I I I ' ' ' ~ I I I I ' ' ~ ' I I I I Actual TD = #NUM! ft I I I I I I 1 1 I I I ~ I I Drlg. Foreman = I I I I I I I' I ~, I I I I I I I I I I I I Drlg. Engineer = I I I I I I I ~ I I ~ I ~ I I 1 I I I I I I I I ~ I I I I I I I , I I I I I I 6 000 ---I---~---+---~- --~---~---+-~-~ __~_J1-__4.__ --I- _I_ _ _-I---+___~ _ __I___J___+_ _ _I-___ , I I I I I I I , I I I 'I I I I I I I I I I I I I ~ I I I I I I I ~ I I I I I I I ~ I I I I I I I I I I I I I I I I I f I I I I I I I I I I 1 1 1 I I I I y I I II I I I I I I I I I I I I I I I I I I I I I I I I I . I I I. I I I I I I I I I I I I I I I I I I I I , I I I I I I I, I ~ I I I I I I I I I I I I I I I I I I I I I I 1 I I I ~ I I I I• I I I I I I I I I 7,000 ___I___J___1___L_ I I I I __I___J___1__,L_ I I I I __ ___~,__~__ __ II I I _I___J___1___~___I___J___1___t____ I I I I I I I I I I I 1 I I 1 u I I I • I I I I I I I I I I I I I I I I I 1 ~ I I 1 I I I I ~ I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I ~ I I I , I I I I 1 I I I I I I I I I I I ` I I ~ I I I 1 I I I I I I I I 1 I I I ~~ I I I I I ~ I I I I I I I I I I I I AFE Est. vs. Actual ' ' ~ ' ' ' ' ' ' ' ' ' ' 000 8 _1___~_ __I __~___~__~~__ _I___~___1___~___I___~___~___~___ , I I~ I I I I I I I I I I I I sa,ooo,ooo ------- I I, ------ I I ~ I .I _ I I I' I ~ I I I I I I I 'I' 'I'• I I I I I I I I I I I I I s~,ooo,ooo - - - - - - - - - - I . I I ~ I I I I ` I . I I • I I I I 1 I $6,O~Q,000 - --- I I ------ I I I I I I I I I I I I I I I I ~ I I I I I $5,000,000 - --- ------ ' ' ` I • I I I I I I I I I I i • I I I I I I I 9 000 sa,ooo,ooo - --- ------ -1---~- '--- --'---~--~ 1- -1- -~--- -~- ----~--- - -~- -'-- , I I _ I I - I- _ _ . `• I- ,- T - 1- _ ___ $3,000,000 ______ I I I I I I ~ I I I I I I I $2,000,000 - --- ------ I I I I I I I I I I I I ~ I I I I I I I I I I I I I I $I 000 QQO _ - ___ i I I I I I I I I I I I I I I I I I I I I I I I $Q I I I I I I I I I I I I I I Planned Actual i I i I I I I I ~ I I I I I I I I I I I I I I I I 10,000 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 Days -O-Actual ~ ~ ~ Low Mean ~ ~ ~ High • • ,, _., ,._. . 1098 ,; SHARON K. ALLSUP-DRAKE ~ s CONOCOPHILLIPS ~ ~ s2-ialsi~ A701530 DATe 700 G ST. ^~ ANCHORAGE AK 99501 ~ ~~tr~ ~ /~• w PAY TO THE. ~ p~,, ;,F °~ ORDER OF /' ~_ /K~ ~~ p ILARS LJ ~ °"9kk. 6 '. ./~ ~.~ri °(F' " A~ Valid Up To 5000 Dollars '~ CHASE Chase Manhattan Bank USA, r 200 White CIay.Cenl¢r Dr., N¢wark. DE 19711 __.. MEMO ' x:03 L L00 L44~: 2 L847 L9079 2?611' L098 J" • • • T'R.ANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PAR.AGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /V ~ ~~ / PTD# ~~ "~~~ Development Exploration Service ~ Stratigraphic CHECK WFlAT ADD-OHS "CLUE"• APPLIES OPTION • MULTI ~ The permit is for a new wellbore segment of LATERAL. existing weU Permit No, ~ API No. (li• API number Production, should continue to be reported as . last two. (2) digits a lunciion'of the original API somber stated are between 60-69) above. PILOT L10LE In accordance with ~ 20 AAC 25.005(n, all (PIS records, data and logs acquired. for the pilot • bole must be clearly diffei•eatisted 'in both name (name on permit plus PII) and API number (50 ?0/80) lrom records, data and logs acquired • for well (name on permit). SPACING The permit is approved subject •to full EXCEPTION compliance with 20 AAC 25.055: Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ~Comaanv Hamel assumes ibe liability of any • protest to the spacing .esception that may occur. DRY DITCH AU dry ditch sample sets submiried to the SAMPLE Commission must be in ao greater than 30' ~ /~ sample intervals from below the permafrost ~/ or from where samples are firm caught and . ] 0' sample intervals through target zones. • ~ 00 ~~~ • ~ o: ~oM ~ o -, n N w~.Y ~ ma a f0 D: ~ ~ p, ~ G ~ ~ ~ ~ ~ ~ L ~ ~ ~' ~ ~~ N. ~ W' ~ ~ O ~ a ~ U. O C p CD ~O ' L Q ~ ~ ~ ~ ~ ~ ~ ~ Q. ~ ~ M ' ' C -- ~ ~ vi; E 0 .~ '~ Y 3 c ~n e ~ N, ~ ~ a . ~ ° ~: p ..:. ~ a~ O : : : ~ ~~ °, o ~ a ~ a ~, ~ a' o aci; ~' o E o n N ~ c ~ ~ >' . o a ~ a, m. a~ y, a 0 5 a u~ a p' C c a C~ , y, f~ N M N , ~ ~ ~ ~ ~ m. ~ N. ~ ~~ ~: ~ m. ~~ ~ ~ ~ Q ~ a ~ ~ ~ O. ~ ~~ U, N' ~ ~ O O~ y ~ ti cp t . ~ ~ ~ ~ O ~ a. O' ~ ~ ~, ~ ~ O' ~ N' y N L ' Q O ~ N N N f/1 ~ N' ~ N Q, a. 3 ~ d7 ; ~ , y 3 a; f6 m ~ O ~ ~ ~ ~ ~ ~ : ~ ~: 1 , •3 ~ ~ o ~ N: o o ~ ~ ~ 3 ~ ~, o f o ~ ~w rn ~ MO y' ~ Q- ' a a~ m ~ o O ~ y a a rn a ~ ~ ~ 4 ~' m, m 'm rn : ~, w c. m. - ~ a: Oo, ~ E. Z. ~ ~ ~ n : a~ c. ~, a Q: i ~, ~; ~ a ~ a , 3 ~ ~' os a' ' c; ~ ~ ~ 3' N' vii ~ •~ ~ ~ ~ ~ ~ w m ~ ~ a .E, ~, o ~ ~ a~ ° ~ : a y, v. o ~ m, ~ U c o 4 ~ ~ ar ~ ~, N, D o a a o ~ ~ c , . . , . O Q Z ~ ~ a ~ y `y O T (6 O : ~ ~ ~ ~~ ~ ~ ~ ~ C N: ~ O: ~ N ~ O ~ 7. y: .D O).p O. _ V ~ O' N O ~, ~ d y' `' Y U O y : ~ ~ ~, ~ ~ c a o: ~ ~ m c' a m ~ rn Q O: N' ~ ~ ~ ~ ~ ~ 0: f4~ N~ O' ~, ~ ~: ~ ~ ~ N: 3: -y0: ~ ~: J+ O y Q i ~: O. i a. ~ ~~ ~ ~ ~ ~ ~ ~ ~, U. O. ~~ O ~ y: ~ L ~: ~ ~ M• O: L ~~ ~ N p l9 N t6 ~. C a a . ~ ~ , : • O N d' ~, y' ~ ~ o. ~ D. ~' ~ a. ~ y, a~: ~ ~, ~~ a: ~ a~ ~ H _ d o, ~ c' d ~ i o, ~, a, c' o' N m ° o ~ y, x, N' ~ ~~ ~ ~ ~ ~ O' O' ~ (0• v ~ ~ y: ~ f6• ~ ~ ~ N' d X L• ~ , O C O a w; w. Z'. ~; Z' Z' y ~' ~; Z; ~' ; _; w. ~' '; ~ ~ U ~ . a i . x , w y: y~ N, N, y~ y f/b N, Q, N, N, ul: N, Q y uT VA v)~ N N N N y N ; Q Q Q Q VD (d~ f/A O N N N y~ N fp tlD ~ N N Q y, N y~ uD N N y, ul~ y N N N y O Q N ~ y, O N Q Q N T ~ ~ ~, Z, ~', ~', , ~, Z, , , , , ~', ~', ~, ~, ~ , , , , Z, Z, Z, Z, , , , , }. }, }, Z, , }, , , , }, ~', Z: , ~', , , }, ~': , , , y'. }, ~', , , , ~", Z. Z. , , Z. }, , , Z. Z. O' ~~ ~ E 3, ~ , a~i °~ O ~ ~° N ~ ~ ~ , ~ ~ ~, _ a o ;; ~ v 3. . ~, a~ o Z, Z` , ~: a y y y > o y , ~~ ~ ~ ~ ~ j. c: O. N, ~ ~ ~ ~ ~ a ~ c6, ~ ~ ~ ~ ~ J, a~' ~ a' -O y' c' OY : ~ ~ 7. N, 3 ~ ~ "' ~ ~ c' >, ". f6 .N, G a, y ~ W ~ y' O: 7. y O' ~ ~ N C ~ C: ~ ~ N ~ C. ~ >~ ~ N. a : , O) ~ ~ ~ p. O' N: . ~ ~' U, N. , O, - ~ ~ p: ar, . N: ' , ~ _: L' ~ ~ ~: • m ~ 3, ~ m ~' c, rn L, c, y, o o- ~' ~' Q y' y' ar .. Z ~, o c. a' c: o a~' a ° m: a ~ ~ o. c. °, m. a o. rn ° d L c ~ ~, ~ y . Y m, ° °. ~; ~ -a ~ ~ m N o o T o' ° m ~, V '4 a 4 ~ ~ ~ o. ui, n. ' 3, °- ~ o > m' ~ ' g ~ °o ~ ~ ~ ~, a >; o > > ° a; ~ m. c Y ~ O' o: o °, m. o, ~ ~ ~ ~ ~: Q: 3 % ~ ~n, T o rn o; ~ !~ . ~' c ' ~' ~ .p' o' a a~ c m' -' •~' Z' w' .., ' ~' ' o' o' a~' L m' 3' ~' ~ m: ' c, a, m. a ~ a -o a, ~ ' a~ ' c: y, M. ~: y s ~ ° y: O. .~, ~ 3 >r o w o a a a: ~, y: ti; ~: °, a' ~, 3. 3. ~ ~ ~ ~: .. a, ~ ~ Y o: ~ ~, ~, ~ o' N: a 'Q ~ ~ o, , o .c, Z' U O J d a O f0 N, a' a~ ' N O: , N. O ~~ ~, ' U. ' O N' ~' ~' O' ' U' V' O: .y.' O. O. ' Y~ ~ ~~ ~~ y' a' ~' ' ~ y' ~: ' ' ~ Q1 ~~ ~' ~~ O_ ' ' y: tp/l: O' J N 4 , a 4Y N N a a ~ N p 7 d a a c N d ~ p y - a N ~ ~ ~ f0 ~ OS O U " ~3 N 7 C ~ d L m' o' , m: ~, o, o. ~ 3. : vA y. ~: ~ y, !~ a m . W-~ t' ~: c o. _ . . . . d ~ ~ ~? ~, ~ °: (6' ~ N' y' ~, ~, N' ~ a : c: m -a ~ ~ . ~, _' c' N, O ' N O • : a ~, C, a fl. N: vi >: y ~ ~ O . 3 a ~ m ~ ~ > vi C L 6 a i a ' O ~ _ U O U a N ~ y w ~ ~ `°' ~' ° E -' a' ~°' ~°' ar «?: .m., u3' o' ~ m, .o: ~ . ~ c' o, o, r, c c . O ~, a' 'v a? •~, ~ c: O d ;~' •y. a a c~ ~ ° , o °, . .m y ~' o _ N 3; ~' ,v_' ~ , y, . ~ -, c ,oa ~ °, , o' o: ~ io: , c' c a~ m c, ~i Z c c~' c~' c~' o o c~' v~ v a~ o; o. v % °- ~ m c °, ~, a OI O' d d °: o, >: , ~ a , o, ~~ N: a , p U > > 3' m: , ~ 7 N m, O ~ N. ~ , v W. W Y, y, y, L, a . '~ N w Y >, €, af0i ~~ °~ °~ ° ' ~, ~ 4 4 ai ai m ~ 3: ~ U o; ~; ~, ~', ~, m v; so a. ~ '' O, O t; °' °' ~ a~, m; 'a . af6i D U c a, -~ , ~, ~; ~; ~ cn: °--; O, O, a; d; U ~ ¢, ~- Q. V: ~ U. U. U: w V, ¢ - Q. "_ 0 m: m. U. ~, `-~, ~, o-: 0, ~, ~, "-`• W a n'1 = O T N M I tA_(O f~ 00 O N ~ O M ~ ~~ (O f~ ~ OD O O ~ N N N N M V' tp N N N t0 N 1~ O N N O O N M M N M Q M M M ~ (O M M f~ 00 M_M U U _ _. _ F-- O .. C C C r+ N w ++ N V O N O . ~ ~ ~ ~ O ~ ~ 0~ ~ O) y ~n W o O. ~ N 6 W _ M ~ '~ _ M T _ M o /' ~~ V] o,( J ,C a o ~ ' a ~ ° c a o U ' a ¢ a ¢ ~- ~ a~ w a a w ~- ~ a w a~ S. Well I-iistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. -~ ConocoPhillips Upstream Technology Data Report Noatak #1 North Slope, Alaska ~ January, 2008 ~~~~ ~t Albert Holba ~o~--~~a a ConocoPhillips Basin Analysis 2008 Geochemical Data Report • Geochemical Analytical Results: Noatak 1 Well National Petroleum Reserve, North Slope, Alaska By Albert G. Holba and Debbie Stuart ConocoPhillips Upstream Technology, Data Report January 2008 Geochemical analytical data for mud gas and rock extract samples from the 2007 Noatak 1 well drilled in the National Petroleum Reserve-Alaska (NPRA) is reported here. Analyses of rock samples were performed by Baseline Resolution Inc. (143 Vision Park Blvd., Shenandoah, TX, 77384). Gas analyses were performed at Isotech Laboratories, (1308 Parkland Court, Champaign, Illinois, 61821). Noatak 1 samples are referenced to Baseline project code 07-247-A or Isotech job number 8250. Sidewall cores, SWC, were frozen on site and shipped in an insulated container directly to Baseline Resolution Inc. for immediate analysis. Prior to samples being forwarded for porosity and permeability analysis, rock samples were extracted in two steps: (1) soak and (2) Soxhlet extractions. Soak extraction entails soaking the intact SWC sample in methylene chloride for five days to extract fluid on the surface and in large pores or fractures. Subsequently, the rinsed core plug is semi-quantitatively extracted in a Soxhlet extractor with refluxing methylene chloride. Gas chromatographic analysis was done on both the soak &Soxhlet extracts using a whole oil method. Both extracts were found to be acceptable for analyses and any subsequent analysis was done on the combine extracts. Gas compositions and isotopic ratios (carbon and deuterium) for mud-gas bags are provided in the section, Miscellaneous Vendor Data. This section also contains results from (1) extraction yields of Sidewall cores; (2) SARA fractions, medium pressure liquid chromatography (MPLC) separation of fractions [saturate hydrocarbons, aromatic hydrocarbons, resin (polar or NSO) nonhydrocarbons, and asphaltene nonhydrocarbons fractions]; and (3) and carbon isotopes of SARA fractions. Based on WGC and extract yields, selected samples were further analyzed for biomarkers using GCMS. Gas chromatograms (WGC), .and gas chromatography/mass chromatograms; GC/MS (saturate and aromatic fractions) and GC/MS/MS (saturate) are provided in subsequent sections. Data in this report was generated under the following Technical Work Agreement code: ~• WNT.161908.IB. ConocoPhillips Analysis 2008 Geochemical Analysis ConocoPhillips Table of Report Cont ents Gas Chromatograms and n umerical data fo r Whole Oil (WGC): Raw Data File Number of Sample ID Number Depth (ft.) Formation Pages Noatak #1 US138720 G6070420.D 8211 3 Soak Extract US138720 G6070397.D 8211 3 Soxhlet Extract US138721 G6070398.D 8216 3 Soak Extract US138721 G6070399.D 8216 3 Soxhlet Extract US138722 G6070423.D 8227 3 Soak Extract US138722 G6070401.D 8227 3 Soxhlet Extract US138723 G6070354.D 8241 3 Soak Extract US138723 G6070350.D 8241 3 Soxhlet Extract US138724 G6070402.D 8248 3 Soak Extract US138724 G6070421.D 8248 3 Soxhlet Extract US138725 G6070404.D 8255 3 Soak Extract US138725 G6070405.D 8255 3 Soxhlet Extract US138726 G6070406.D 8265 3 Soak Extract US138726 G6070422.D 8265 3 Soxhlet Extract US138727 G6070417.D 8273 3 Soak Extract US138727 G6070409.D 8273 3 Soxhlet Extract US138728 G6070353.D 8287 3 Soak Extract US138728 G6070352.D 8287 3 Soxhlet Extract US138728 G6070395.D 8287 3 Repeat of Soxhlet Extract US138729 G6070418.D 8290 3 Soxhlet Extract US138730 G6070411.D 8297 3 Combined US138731 G6070412.D 8299 3 Combined US138732 G6070413.D 8301 3 Combined US138733 G6070415.D 8304 3 Combined US138733 G6070416.D 8304 3 Replicate of Combined US138734 G6070349.D 8306 3 Soak Extract US138734 G6070348.D 8306 3 Soxhlet Extract US138820 G6070388.D 3 Drilling US138822 G6070389.D 3 Soltex US138822 G6070389.D 3 Soltex drilling mud additive Gas Chromatograms and numerical data for Whole Oil GCMS: Raw Data File Number of Sample ID Number Depth (ft.) Formation Pages Noatak #1 {• US138734 M2071024.D 8306 2 Page 1 ConocoPhillips Analysis Gas Chromatographv/Mass Spectrometry (GC/MS) Saturate hydrocarbon chromatograms and numerical data; Raw Data File Number of Sample ID Number Depth (ft.) Formation Pages Noatak #1 US138734 M2071032.D 8306 5 Gas Chromatographv/Mass Spectrometry (GC/MS) Aromatic hydrocarbon chromatograms and numerical data; Raw Data File Number of Sample ID Number Depth (fit.) Formation Pages Noatak #1 US138734 M1070970.D 8306 6 Miscellaneous (Vendor Data) Gas Data Isotech Mudgas Data Job #8250 1 Isotech Mudgas Data Job #8272 1 Extracts. Fractions. & Isotopes SOXHLET 1 Geochemical Log 1 Kerogen Quality 1 Kerogen Type Determination 1 Kerogen Type 1 Kerogen Type and Maturity 2 Kerogen Conversion and Maturity 2 Distribution List: Albert Holba (COP/SsT) 1 copy State of Alaska 1 copy ConocoPhillips -Alaska (Greg Wilson) 4 copies ConocoPhillips Records, Houston 1 copy 2008 Geochemical Analysis • • • Page 2 • BASELINE RESOLUTIQN, INC. WHOLE OIL GC .. Company: CONOCOPHILLIPS Client ID: US138720 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282488 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8211 FT Longitude: Bottom Depth: FT G6070420.D ;;• Pristane/Phytane 2.39 A. BZ/nCe Pristane/nC~~ 0.45 B. TOL/nC~ 2.97 Phytane/nC1B 0.23 C. (nC®+nC~)/(CH+MCH) 1.30 n C18/n Ct9 1.14 I. Isoheptane Value nC~~/nC28 90.19 F. nG7/MCH 1.30 CPI Marzi4 1.06 U. CH/MCP Normal Paraffins 42.2 R. n C~/2MH Isoprenoids 7.3 S. nC~/22DMB Cycloparaffins 0.0 F~. Heptane Value 56.55 Branched (iso-) Paraffins MCH/n C7 0.77 BTX'aromatics 0:0 mpXYUnCe 0.25 Resolved unknowns 50.2 1Thompsory K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG Bull.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. :.ompany: CONOCOPHILLIPS Client ID: US138720 Nell Name: NOATAK-1 Project #: 07-247-A depth: 8211 - FT Lab ID: CP282488 3amplin Point: File Name: G6070397.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane ' 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane. C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP10 Isoprenoid C10 NC10 Normal Alkane C10 IP11 {soprenoid C14 NC11 Normal Alkane C11 NC12 Normal Alkane C12 IP13 Isoprenoid C13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 IP15 Isoprenoid C15 NC14 Normal Alkane C14 IP16 Isoprenoid C16 NC15 Normal Alkane C15 21.051 153 41 26.635 4470 1584 27.937 1554 505 31.896 68962 22924 36.823 137316 44123 37.551 28119 7860 40:305 41.428 23470 162556 7545 ' 50055 44:855 32169 9812 45.753 150742 45956 48.394 55030 13478 49.829 138909 39421 • • Company: CONOCOPHILLIPS Client ID: US138720 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8211 - FT Lab ID: CP282488 Samplin Point: File Name: G6070420.D NC16 Normal Alkane C16 53.671 106909 31808 IP18 Isoprenoid C18 55.597 34994 7528 NC17 Normal Alkane C17 57.322 98222 28533 IP19 Isoprenoid C19 (Pristane) 57.676 44129 8470 PHEN Phenanthrene 58.713 5056 1181 NC18 Normal Alkane C18 60.789 80640 23574 IP20 Isoprenoid C20 (Phytane) 61.237 18473 3343 NC19 Normal Alkane C19 64.093 70896 20426 NC20 Normal Alkane C20 67.246 60564 17154 NC21 Normal Alkane C21 70.254 49850 14222 C25H61 Highly Branch Isoprenoid C25 70.504 1965 471 NC22 Normal Alkane C22 73.137 42953 12237 NC23 Normal Alkane C23 75.896 35928 10202 NC24 Normal Alkane C24 78.549 29016 8104 NC25 Normal Alkane C25 81.096 24681 6867 NC26 Normal Alkane C26 83.551 19215 5232 NC27 Normal Alkane C27 85.912 15221 4222 NC28 Normal Alkane C2$ 88.190 10914 2940 NC29 Normal Alkane C29 90.398 9635 2493 NC30 Normal Alkane C30 92.531 6279 1628 NC31 Normal Alkane C31 94.588 4774 1215 NC32 Normal Alkane C32 96.585 3581 855 NC33 Normal Alkane C33 98.526 3726 719 NC34 Normal Alkane C34 100.408 2018 453 NC35 Normal Alkane C35 102.245 1987 375 NC36 Normal Alkane C36 104.199 1280 229 NC37 Normal Alkane C37 106.394 861 147 NC38 Normal Alkane C38 108.880 720 106 NC39 Normal Alkane C39 111.745 645 79 NC40 Normal Alkane C40 115.128 1146 72 NC41 Normal Alkane C41 118.927 565 45 • C: BASELINE RESOLUTION, IIVC_ WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138720 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282488 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8211 FT Longitude: Bottom Depth: FT G6070420.D U z • Pristane/Phytane 2:39 A. BZJn CB Pristane/n C17 0.45 B. TOUn C7 2.97 Phytane/nCte 0.23 C. (nC®+nC~)/(CH+MCH) 1.30 nC~~/nC19 1.14 I. Isoheptane Value nC17/nC29 10.19 F. nC~/MCH 1.30 CPI Marzi4 1.06 U. CH/MCP Normal Paraffins 42.2 R. n C7/2MH Isoprenoids 7.3 S. nC~/22DM6 Cycloparaffins OA F~. Heptane Value 56.55 Branched (iso-) Paraffins MCH/nC~ 0.77 BTX aromatics 0.0 mpXYUn C8 0.25 Resolved unknowns 50.2 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPGBulL: V.79, p.801. °Mazzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138720 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8211 - FT Lab ID: CP282488 Samplin Point: File Name: G6070420.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1 C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 10.229 190 69 ISTD Internal Standard MCH Methylcyclohexane 11.075 146 41 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.778 564 183 NC8 Normal Alkane C8 15.372 1050 389 IP9 Isoprenoid C9 MXYL m-Xylene 18.44..8. 104. 30 PXYL p-Xylene 18.509 157 41 OXYL o-Xylene. 19.467 48 11 NC9 Normal Alkane C9 21.065 239 72 1P10 Isoprenoid C10 NC10 Normal Alkane C10 26.636 1161 352 IP11 Isoprenoid C11 27.937 233 64 NC11 Normal Alkane C11 31.881 3983 1229 NC12 Normal Alkane C12 36.794 14960 4762 IP13 Isoprenoid C13 37.539 3306 880 IP14 Isoprenoid C14 40.296 5487 1722 NC13 Normal Alkane C13 41.402 55494 17359 1P15 Isoprenoid C15 44.844. 1.7756 5257 NC14 Normal Alkane C14 45.737 99568 29866 IP16 Isoprenoid. C16 48.385 42949 10412 NC15 Normal Alkane C15 49.817 120229 34787 • Company: CONOCOPHILLIPS Client ID: US138720 JVell Name: NOATAK-1 Project #: 07-247-A Depth: 8211 - FT Lab ID: CP282488 Sampling Point: File Name: G6070397.D NC16 Normal Alkane C16 53.680 112848 33794 IP18 Isoprenoid C18 55.603 36931 8004 NC17 Normal Alkane C17 57.329 101777 29982 IP19 Isoprenoid C19 (Pristane) 57.679 46479 8995 PHEN Phenanthrene 58.721 5190 1234 NC18 Normal Alkane C18 60.798 83953 25103 IP20 Isoprenoid C20 (Phytane) 61.243 19626 3566 NC19 Normal Alkane C19 64:101 75102 20902 NC20 Normal Alkane C20 67.253 65826 18704 NC21 Normal Alkane C21 70.263 55607 15721 C25H61 Highly Branch Isoprenoid C25 70.515 2208 536 NC22 NormaLAlkane C22 73.147 48243 13506 NC23 Normal Alkane C23 75.909 41699 11956 NC24 Normal Alkane C24 78.561 34986 9933 NC25 Normal Alkane C25 81.111 30617 8436 NC26 Normal Alkane C26 83.563 24268 6736 NC27 Normal Alkane C27 85.927 20083 5524 NC28 Normal Alkane C28 88.210 14767 3938 NC29 Normal Alkane C29 90.416 13529 3503 NC30 Normal Alkane C30 92.547 9035 2319 NC31 Normal Alkane C31 94.611 8196 1846 NC32 Normal Alkane C32 96.609 4769. 1°182 NC33 Normal Alkane C33 98.551 6706 1211 NC34 Normal Alkane C34 100.429 2970 671 NC35 Normal Alkane C35 102.267 2597 540 NC36 Normal Alkane C36 104.227 1989 340. NC37 Normal Alkane C37 106.427 1254 226 NC38 Normal Alkane C38 108.918 1024 157 NC39 Normal Alkane C39 111.778 868 114 NC40 Normal Alkane C40 115.112 882 87` NC41 Normal Alkane C41 118.970 735 69 •i • BASELINE WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138721 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282489 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8216 FT Longitude: Bottom Depth: FT G6070398.D U U 2 • • Pristane/Phytane 2.37 A. BZ/nCB, 0.52 Pristane/n C» 0.44 B. TOUn C7 24.48 PhytaneMC78 0.23 C. (nCe+nC,)i(CH+MCH) '0.39 nC~~/nC19 1.11 I. Isoheptane Value n C~7/n C2~ 7.75 F. n C7/MCH 0:31 CPI Marzi4 1.06 U. CH/MCP 7.11 Normal Paraffins 31.6 R. nC7l2MH Isoprenoids 4.9 S. nCs/22DM6 Cycloparaffins 0.1 H. Heptane Value 16:66 Branched (iso-) Paraffins MCH/n C7 3.21 BTX aromatics 2.4 mpXYUnCe 3.65 Resolved unknowns 60.6 1Thompson, K.F.M.,1983.GCA:V.47, p.303. 2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPG Bull.: V.79, p.801. °Mazzi,1993,OrgG;2Q1301. Company: CONOCOPHILLIPS Client ID: US138721 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8216 - FT ~ Lab ID: CP282489 Sam lin Point: File Name: G6070398.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 6.503 242 129 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 7.230 65 22 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 7.998 126 38 33DMP 3,3-Dimethylpentane CH Cyclohexane 8.310 462 209 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 10.089 257 93 ISTD Internal Standard 10.332 157 20 MCH Methylcyclohexane 10.941 824 289 113TMCP 1,1,3,-Trimethylcyclopentane 11.112 160 33 ECP Ethylcyclopentane 11.515 97 27 124TMCP 1,2,4-Trimethylcyclopentane 11.967 123 40 123TMCP 1,2,3-Trimethylcyclopentane 12.338 130 39 TOL Toluene 12.662 6291 2449 NC8 Normal Alkane C8 15.305 16347 6277 IP9 Isoprenoid C9 17.183 2372 872 MXYL m-Xylene 18.393 45509 16902 PXYL p-Xylene 18.456 14227 5466 OXYL o-Xylene 19.443 10164 3741, NC9 Normal Alkane C9 21.053 61519 22702 IP10 Isoprenoid C10 23.032 9906 2886 NC10 Normal Alkane C10 26.648 88135 30895 IP11 Isoprenoid C11 27.939 12245 4183 NC11 Normal Alkane C11 31.901 96857 31456 NC12 Normal Alkane C12 36.811 84019 27322 IP13 Isoprenoid C1.3 37.546 16654 4425 IP14 Isoprenoid C14 40.299 1133T 3681 NC13 Normal Alkane C13 41.411 78985 25442 IP15 Isoprenoid C15 44.848. 15632 4755 NC14 Normal Alkane C14 45.736 68287 21163 IP16 Isoprenoid C16 48.386 24517 5893 NC15 Normal Alkane C15 49.809 62143 17802 • Company: CONOCOPHILLIPS Client ID: US138721 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8216 - FT Lab ID: CP282489 Samplin Point: File Name: G6070398.D NC16 Normal Alkane C16 53.662 48969 14991 IP18 Isoprenoid C18 55.596 15709 3414 NC17 Normal Alkane C17 57.312 43717 12661 IP19 Isoprenoid C19 (Pristane) 57.663 19442 3786 PHEN Phenanthrene 58.714 2668 659 NC18 Normal Alkane C18 60.782 35898 10751 IP20 Isoprenoid C20 (Phytane) 61.239 8211 1487 NC19 Normal Alkane C19 64.089 32204 9341 NC20 Normal Alkane C20 67.240 28199 8123 NC21 Normal Alkane C21 70.253 23704 6999 C25HB1 Highly Branch Isoprenoid C25 70.508 1130 261 NC22 Normal Alkane C22 73.137 21602 6010 NC23 Normal Alkane C23 75.900 18299 5250 NC24 Normal Alkane C24 78.555 15119 4254 NC25 Normal Alkane C25 81.108 13196 3662 NC26 Normal Alkane C26 83.558 10486 2932 NC27 Normal Alkane C27 85.925 8507 2380 NC28 Normal Alkane C28 88.206 6258 .1643 NC29 Normal Alkane C29 90.412 5639 1426 NC30 Normal Alkane C30 92.549 3904 949 NC31 Normal Alkane C31 94.609 2911 736 NC32 Normal Alkane C32 96:604 2038 496 NC33 Normal Alkane C33 98.551 2227 453 NC34 Normal Alkane C34 100:431 1455 313 NC35 Normal Alkane C35 102.270 1047 239 NC36 Normal Alkane C36 104.229 841 140 NC37 Normal Alkane C37 106.424 636 109 NC38 Normal Alkane C38 108.916 608 84 NC39 Normal Alkane C39 111.790 579 65 NC40 Normal Alkane C40 115:101 684 60 NC41 Normal Alkane C41 118.990 374 39 i =• • BASELINE RESC)LUTI©N, INC. WHOLE OIL GC .. Company: CONOCOPHILLIPS Client ID: US138721 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282489 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8216 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070399.D U Z U Z U Z U Z V U 2 y V Z U Z U Z U Z U Z U d z N U Z z .°. z N U ~ Z U m Z Z z U~ '+ ~ b ~ z z Z Z z z z Z Z z z z z z a .a O U F Z Pristane/Phytane 2.35 A. BZ/n CB Pristane/nC17 0.45 B. TOUnC7 Phytane/nC18 0.23 C. (nce+nC,)I(CH+MCH) nC~~/nC19 1.11 I. Isoheptane Value nC~~/nC28 7.71 F. nC~/MCH CPI Marzi4 1.06 U. CH/MCP Normal. Paraffins 38.3 R. n C7/2MH . Isoprenoids 6.4 Cycloparaffins S. nCfi/22DMB H. Heptane Value Branched (iso-) Paraffins MCH/n C7 BTX aromatics. 0.0 mpXYUn Ce Resolved unknowns 55.1 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG $ull.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138721 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8216 - FT Lab ID: CP282489 Sampling Point: File Name: G6070399.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.662 141 43 NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 21.050 ' 99 33 IP10 Isoprenoid C10 NC10 Normal Alkane C10 26.634 13660 4857 1P11 Isoprenoid C11 27.936 .3459 1174 NC11 Normal Alkane C11 31.898 93214 31345 NC12 Normal Alkane C12 36:822 141683 45355 IP13 Isoprenoid C13 37.549 28460 7855 IP14 Isoprenoid C14 40.303 21961 7087 NC13 Normal Alkane C13 41.425 153508 46560 IP15 Isoprenoid C15 44.853 29904 9141 NC14 Normal Alkane C14 45.751 137160 41868 IP16 Isoprenoid C16 48.391 49051. 11613 NC15 Normal Alkane C15 49.823 124388 35585 • C company: CONOCOPHILLIPS Client ID: US138721 Nell Name: NOATAK-1 Project #: 07-247-A depth: 8216 - FT Lab ID: CP282489 Sampling Point: File Name: G6070399.D NC16 Normal Alkane C16 IP18 Isoprenoid C18 NC17 Normal Alkane C17 IP19 Isoprenoid C19 (Pristane) PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C21 C25HB1 Highly Branch Isoprenoid C25 NC22 Normal Alkane C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane C26 NC27 Normal Alkane C27 NC28 Normal Alkane C28 NC29 Normal Alkane C29 NC30 Normal Alkane C30 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 Normal Alkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkane C38 NC39 Normal Alkane C39 NC40 Normal Alkane C40 NC41 Normal Alkane C41 53.675 99176 30291 55:601 31961 6997 57.324 88170 26469 57.679 39469 7591 58.717 5266 1316 60.794 72983 21630 61.239 16799 3049 64.098 65621 18931 67.249 58079 16279 70.261 .48372 13690 70.514 2087 477 73.146 42022 12098 75.907 36521 10304 78:562 30184 8401 81.113 26412 7252 83.566 20818. 5753 85.928 17053 4622 88.213 12548 3334 90.419 11441 2881 92.549 7538 1.943 94.610 6505 1542 96.609 3900 933 98.549 4617 909 100.435 2497 535 102.268 2034 442 104.232. 1424 260 106.430 1096 177 108.925 825 120 111.777 760 90 115.137 715 64 118.980 727 58 i• • BASELINE RESOLUTI©N, INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138722 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282490 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8227 FT Longitude: Bottom Depth: FT G6070423.D U 2 L Pristane/Phytane 2.30 A. BZ/n Ce Pristane/nC~~ 0.44 B. TOUnC7 11. Phytane/nC18 0.23 C. lnCB+nC~N(CH+MCH) 0. nC~a/nC19 1.12 I. Isoheptane Value nCl~/nC29 7.52 F. nC7/MCH -0. CPI Marzi4 1.05 U. CH/MCP Normal Paraffins 33.5 R. nC~l2MH Isoprenoids 5.3 S. nCs/22DM6 Cycloparaffins 0.0 H. Heptane Value 43. Branched (iso-) Paraffins MCH/n C7 1. BTX aromatics 1.5 mpXYUn Ce 5. Resolved unknowns 59.3 1Thompson, K.F.M.,1983.GCA:V.47, p.303.2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPGBu11.: V.79, p.801. °Marzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138722 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8227 - FT Lab ID: CP282490 Samplin Point: File Name: G6070423.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 10.030 141 48 ISTD Internal Standard MCH Methylcyclohexane 10.880 182 58 113TMCP 1,1,3,-Trimethylcyclopentane 11.050 53 15 ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.606 1683 599 NC8 Normal Alkane C8 15.242. 11764 4499 IP9 Isoprenoid C9 17.119 2261 776 MXYL m-Xylene 18.329 46868. 17493 PXYL p-Xylene 18.392 14550 5550 OXYL o-Xylene 19.382 11684 4244 NC9 Normal Alkane C9 20.996 80412 29452 IP10 Isoprenoid C10 22.975 13839 4076. NC10 Normal Alkane C10 26.600 138069 47107 IP11 Isoprenoid C11 27.886 1.9287 6590 NC11 Normal Alkane C11 31.857 159126 51102 NC12 Normal Alkane C12 36.771 138524. 44250 IP13 Isoprenoid C13 37.499 27606 7477 IP14 Isoprenoid C14 40.254 18497 6067 NC13 Normal Alkane C13 41.372 130444 39904 IP15 Isoprenoid C15 44.803 26541 8281 NC14 Normal Alkane C14 45.697 110833 34511 IP16 Isoprenoid C16 48.342 39899 9513 - NC15 Normal Alkane C15 49.772 99449 27734 Company: CONOCOPHILLIPS Client ID: US138722 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8227 - FT Lab ID: CP282490 Sam ling Point: File Name: G6070423.D ' NC16 Normal Alkane C16 53.626 78463 23338 IP18 Isoprenoid C18 55.557 24771 5353 NC17 Normal Alkane C17 57.277 69435 20600 IP19 Isoprenoid C19 (Pristane) 57.631 30554 5826 PHEN Phenanthrene 58.670 5785 1516 NC18 Normal Alkane C18 60.748 57114 16918 IP20 Isoprenoid C20 (Phytane) 61.202 13284 2336 NC19 Normal Alkane C19 64.055 51021 14738 NC20 Normal Alkane C20 67.207 45060 12681 NC21 Normal Alkane C21 70.221 .37297 10743 C25H61 Highly Branch Isoprenoid C25 70.472 2570 553 NC22 Normal Alkane C22 73.105 33163 9553 I NC23 Normal Alkane C23 75.867 28666 8129 NC24 Normal Alkane C24 78.519 24127 6769 NC25 Normal Alkane C25 81.071 20936 5799 NC26 Normal Alkane C26 83..522 16771 4602 NC27 Normal Alkane C27 85.885 13688 3773 NG28 Normal Alkane C28 88.168 10167 2714 NC29 Normal Alkane C29 90.371 9228 2244 NC30 Normal Alkane C30 92.506 6095 1559 NC31 Normal Alkane C31 94.566 4659 1207 NC32 Normal Alkane C32 96.565 3409 754 NC33 Normal Alkane C33 98.504 3468 665 NC34 Normal Alkane C34 100.387 1900 423 NC35 Normal Alkane C35 102.226 1424 335 NG36 Normal Alkane C36 104.178 1117 211 NC37 Normal Alkane C37 106.373 889 143 NC38 Normal Alkane C38 908.890 667 98 NC39 Normal Alkane C39 111.707 521 71 NC40 Normal Alkane C40 115.012 691 63 NC41 Normal Alkane C41 118.880 1046 69 •i BASELINE RESOLUTION, INC_ WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138722 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282490 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8227 FT Longitude: Bottom Depth: FT G6070401.D U z • Pristane/Phytane 2.30 A. BZJn Cg 0.36 P~ 6:38 Try 1.57 Pristane/n C~~ 0.44 B: TOUn C~ 1.59 PZ 20.97 Tr2 0.99 Phytane/nC7B 0.23 C. (nCe+nCy)/(CH+MCH) 0.95 P3 12.67 Tr3 2.23 nC~B/nC~9 1.11 I. Isoheptane Value 0.66 5N~ 7.05 Tr4 1.01 nCI~/nC29 7.68 F. nC~IMCH 0.54 N2 30.96 Trg 3.25 CPI Marzi4 1.06 U. CH/MCP 1.58 6N~ 21.98 Try 1.31 Normal Paraffins 37.6 R. nC~/2MH 0.97 KI 0.71 Tr8 1.66 Isoprenoids 6.6 S. nCs/22DMB 3.97 KZ 0.40 C~ 0.11 Cycloparaffihs' 0.0 H. Heptahe Value 5.93 5N~/6N1 0.32 CZ 0.42 Branched (iso-) Paraffins 0.0 MCH/n C7 1.86 P3/NZ 0.41 C3 0.18 BTX aromatics 0.0 mpXYUnCe In(24DMP/23DMP) -0.86 C4 Resolved unknowns 55.5 Cs 0.28 IThompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F .D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG Bull.: V.79, p.801. °Marzi,1993,OrgG;2Q, 1301. :ompany: CONOCOPHILLIPS Client ID: US138722 'Nell Name: NOATAK-1 Project #: 07-247-A )epth: 8227 - FT Lab ID: CP282490 >ampling Point: File Name: G6070401.D IC4 Iso-alkane C4 3.968 110 27 NC4 Normal Alkane C4 4.085 133 85 IC5 Iso-alkane C5 4.518 211 138 NC5 Normal Alkane C5 4.759 374 194 22DM6 2,2-Dimethylbutane 5.346 86 28 CP Cyclopentane 5.697 167 56 23DMB 2,3-Dimethylbutane 5.731 64 36 2MP 2-Methylpentane 5.807 240 114 3MP 3-Methylpentane 6.098 203 77 NC6 Normal Alkane C6 6.504 341 176 22DMP 2,2-Dimethylpentane 7.173 17 10 MCP Methylcyclopentane 7.228 188 96 24DMP 2,4-Dimethylpentane 7.363 27 13 223TMB 2,2,3-Trimethylbutane BZ Benzene 7.998 123 47 33DMP 3,3-Dimethylpentane CH Cyclohexane 8.310 297 136 2MH 2-Methylhexane 8.692 78 27 23DMP 2,3-Dimethylpentane 8.742 64 21 11DMCP 1,1-Dimethylcyclopentane 8.828 77 17 3MH 3-Methylhexane 9.031 172 34 1C3DMCP 1-cis-3-Dimethylcyclopentane 9.272 191 ' 26 1T3DMCP 1-trans-3-Dimethylcyclopentane 9.384 101 27 3EP 3-Ethylpentane 9.434 43 20 1T2DMCP 1-trans-2-Dimethylcyclopentane 9.498 84 32 NC7 Normal Alkane C7 10.090 76 31 ISTD Internal Standard MCH Methylcyclohexane 10.943 141 56 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.680 121 36 NC8 Normal Alkane C8 15.306 594 212 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 21.045 310 70 IP14 Isoprenoid C10 NC10 Normal Alkane C10 26.631 364 120 IP11 Isoprenoid C11 27.931 201 49 NC11 Normal Alkane C11 31.883 23390 7990 NC12 Normal Alkane C12 36.810 94150 31664 IP13 Isoprenoid C13 37.541 19216 5456 IP14 Isoprenoid C14 40.298 18222 5959. NC13 Normal Alkane C13 41.417 136941 ' 42524 IP15 Isoprenoid C15 44.846 30116 9039 NC14 Normal Alkane C14 45.743 131785 40876 IP16 Isoprenoid C16 48.384 48027 1.1663 NC15 Normal Alkane C15 49.815 122438 34703 • Company: CONOCOPHILLIPS Client ID: US138722 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8227 - FT Lab ID: CP282490 Samplin Point: File Name: G6070401.D NC16 Normal Alkane C16 53.667 98624 29989 IP18 Isoprenoid C1$ 55.594 31622 6750 NC17 Normal Alkane C17 57.316 89211 26254 IP19 Isoprenoid C19 {Pristane) 57.664 39419 7567 PHEN Phenanthrene 58.710 7713 1996 NC18 Normal Alkane C18 60.785 73711 21869 IP20 Isoprenoid C20 (Phytane) 61.237 17148 3117 NC19 Normal Alkane C19 64.090 66226 19112 NC20 Normal Alkane C20 67.242 58259 16134 NC21 Normal Alkane C21 70.255 47854 13690 C25HB1 Highly Branch Isoprenoid C25 70.505 2313 553 NC22 Normal Alkane C22 73.137 4.1409. 11865 NC23 Normal Alkane C23 75.901 35817 10365 NC24 Normal Alkane C24 78.555 29605 8316 NC25 Normal Alkane C25 81.104 25890 6920 NC26 Normal Alkane C26 83.556 20478 5467 NC27 Normal Alkane C27 85.925 16900 4598 NC28 Normaf Alkane C28 88.202 12386. 3376 NC29 Normal Alkane C29 90.409 11615 3022 NC30 Normal Alkane C30 92:540 7468 1890 NC31 Normal Alkane C31 94.602 7982 1646 NC32 Normal Alkane C32 96:602 4050 959 NC33 Normal Alkane C33 98.543 6052 1015 NC34 Normal Alkane C34 100.421 2494 534 NC35 Normal Alkane C35 102.262 1876 391 NC36 Normaf Alkane C36 104.221 1582 258 NC37 Normal Alkane C37 106.408 1156 164 NC38 Normal Alkane C38 108.915 743 112 NC39 Normal Alkane C39 111.758 677 84 NC40 Normal Alkane C40 115.089 732 68 NC41 Normal Alkane C41 118.958 552 48 BASELINE RESC7LUTI©N, INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138723 Country: UNITED STATES Project #: 07-247-A _ Basin: NORTH SLOPE - Lab 1D: CP282491 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: , JURASSIC, LATE Latitude: Top Depth: 8241 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070350.D z z U z U z U z U z U z U U z Z U Z U U z z U z H U h z °~ U m Z l0 0 ~ H U U z z U m ~, `~ Z U U .a t7 a ~~ h m s z z z z z z z z z z z a z U ~ z Pristane/Phytane 1.73 A. BZJnCe Pristane/nC17 0.44 B. TOL/nC, Phytane/nC18 0.30 C. (nCe+nC,)/(CH+MCH) n C,e/n C19 ~ 1:12 I. Isoheptane Value _ nC17In C29 7.14 F, n C~IMCH CPI Marzi4 1.03 U. CH/M'CP NormaLParaffins 34.1 R. nC7/2MH Isoprenoids 5.5 S. n C~/22DM6 . Cycioparaffins H. Heptane Value Branched (iso-) Paraffins MCH/n C7 BTX aromatics mpXYUnCe Resolved unknowns 60.3 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG Bull.: V.79, p.801. QMarzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138723 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8241 - FT Lab ID: CP282491 .Sampling Point: File Name: G6070350.D IC4 Iso-alkane C4 - NC4 Normal Alkane C4 • IC5 Iso-alkane C5 NC5 Normal Alkane C5 ~ • 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane. 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2;2-Dimethylpentane MCP Methylcyclopentane . 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 21.059 1479 538 IP10 Isoprenoid C10 ~ 23.043 745 21$ NC10 Normal Alkane C10 26.649 25095 8936 IP11 Isoprenoid C11 27.950 4470 1543 NC11 Normal Alkane C11 31.906 57651 19479 NC12 Normal Alkane C12 36.822 64431 21331 IP13 Isoprenoid C13 37.559 12892 3514 IP14 Isoprenoid C14 40.313 9455 3028: NC13 Normal Alkane C13 41.422 64828 20973 IP15 Isoprenoid C15 44:860. 12284 3965- NC14 Normal Alkane C14 45.747 58945 18444 IP16 Isoprenoid C16 48.400 21146 5129 NC15 Normal Alkane C15 49.824 54652 15664 s• Company: CONOCOPHILLIPS Client ID: US138723 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8241 - FT Lab ID: CP282491 Sam ling Point: File Name: G6070350.D NC16 Normal Alkane C16 53.677 44124 13217 IP18 Isoprenoid C18 55.615 13959 3024 NC17 Normal Alkane C17 57.331 39741 11656 IP19 Isoprenoid C19 (Pristane) 57.684 17400 339.1 PHEN Phenanthrene 58.727 2264 580 NC18 Normal Alkane C18 60.802 34118 10010 IP20 Isoprenoid C20 (Phytane) 61.261 10078 1583 NC19 Normal Alkane C19 64.108 30391 8722 NC20 Normal Alkane C20 67.257 25818 7311 NC21 Normal Alkane C21 70:272 21339 6247 C25HB1 Highly Branch Isoprenoid C25 70.524 1012 249 NC22 Normal Alkane C22 73.161 24826 5851 NC23 Normal Alkane C23 75.922 16566 4714 NC24 Normal Alkane C24 78.572 14418 3956 NC25 Normal Alkane C25 81.122 12411 3371 NC26 Normal Alkane C26 83.574 .10112 2787 NC27 Normal Alkane C27 85.939 8163 2145 NC28 Normal Alkane C28 88225 6125 1622 NC29 Normal Alkane C29 90.428 5563 1442 NC30 Normal Alkane C30 92:549 11301 2618 NC31 Normal Alkane C31 94.626 3021 731 NC32 Normal Alkane C32 96.623 2118 510 NC33 Normal Alkane C33 98.565 2393 482 NC34 Normal Alkane C34 100.445 1407 306. NC35 Normal Alkane C35 102.281 1493 277 NC36 Normal Alkane C36 104.237 934 164 NC37 Normal Alkane C37 106.433 800 122 NC38 Normal Alkane C38 108,929 767 101 NC39 Normal Alkane C39 111.800 674 78 NC40 Normal Alkane C40 115.118 787 68 NC41 Normal Alkane C41 118.964 602 52 • C: BASELINE I~ESQLUTION. INC.. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138723 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: ~ CP282491 Lease: Sample Type: SWC ROTARY soak Block: _ Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8241 FT Longitude: Bottom Depth: FT G6070354.D ~J PristanelPhytane 1.24 Pristane/n C~~ 0.41 Phytane/n C1e - 0.37 nC~~/nC19 1.15 n Cl7ln C29 6:46 CPI Marzi4 0.99 _ Normal' Paraffins 25.8 Isoprenoids 4.0 ~~ Cycloparaffins 0.1 Branched (iso-) Paraffins BTX aromatics 2.8 Resolved unknowns 67.0 A. . BZ/n Ce B. TOLJn C~ I. Isoheptane Value F, nC~/MCH, U. CH/MCP R. nC7/2MH, S. nCs/22DMB H. Heptane Value MCH/n C~ mpXYUn Ce 0.51 0.51 33.90 1.95 P~ 3.86 PZ P3 5N~ 0.55 NZ 6N~ 95.59 Kl KZ 5N~I6N~ 0:01 P~/NZ In(24DMP/23DMPl 'Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG Bull.: V.79, p.801. °Mazzi,1993,OrgG;2Q,130I. Company: CONOCOPHILLIPS Client ID: US138723 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8241 - FT Lab ID: CP282491 Sam ling Point: File Name: G6070354.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 ` NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane " •CP Cyclopentane 23DM6 2,3-Dimethylbutane 2MP 2-Methylpentane ' 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NCZ Normal Alkane C7 10.105 704 311 ISTD Internal Standard MCH Methylcyclohexane 10.958 1373 583 113TMCP 1,1,3,-Trimethylcyclopentane 11.131 119 39 ECP Ethylcyclopentane 11.539 100 35 124TMCP 1,2,4-Trimethylcyclopentane 11.988 170 49 123TMCP 1,2,3-Trimethylcyclopentane 12.359 150 53 TOL Toluene 12.674 16052 6440 NC8 Normal Alkane C8 15.326 14813 5629 FP9 Isoprenoid C9 17.205 1835 665 MXYL m-Xylene 18.410 44688 16590 PXYL p-Xylene 18.474 14040 5342 OXYL o-Xylene 19.463 7368 2685 NC9 Normal Alkane C9 21.072 42653 15790 IP10 Isoprenoid C10 23.052 6665 1956 NC10 Normal Alkane C10 26.662 59737 21049 IP11 Isoprenoid C11 27.958 8234. 2845 NC11 Normal Alkane C11 31.913 66463 22062 NC12 Normal Alkane C12 36.824 58910 19503 IP13 Isoprenoid C13 37.564 11867 3057 IP14 Isoprenoid C14 40.317 7770 2473 NC13 Normal Alkane C13 41.424 54460 I 17625 IP15 Isoprenoid C15 44.864 11242. 3468 >" NC14 Normal Alkane C14 45.749 48705 14803 IP16 Isoprenoid C16 48.401 17142 4134 NC15 Normal Alkane C15 49.824 43728 12427 I C~ Company: CONOCOPHILLIPS Client ID: US138723 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8241 - FT Lab ID: CP282491 Sampling Point: File Name: G6070354.D NC16 Normal Alkane C16 53.679 36164 10493 IP18 Isoprenoid C18 55.616 11092 2379 NC17 Normal Alkane C17 57.331 32829 9487 IP19 Isoprenoid C19 (Pristane) 57.688 13593 2631 PHEN Phenanthrene 58.729 2532 622 NC18 Normal Alkane C18 60.803 29995 8198 IP20 Isoprenoid C20 (Phytane) 61.272 11004 1550 NC19 Normal Alkane C19 64,109 26153. 7263 NC20 Normal Alkane C20 67.259 21816 6339 NC21 Normal Alkane C21 70.272 17808 5266 C25HBI Highly Branch Isoprenoid C25 70.636 4929 759 NC22 Normal Alkane C22 73.163 31485 5825 NC23 Normal Alkane C23 75.920 14116 4003 NC24 Normal Alkane C24 78.571 13498 3474 NC25 Normal Alkane C25 81.121 10980 3001 NC26 Normal Alkane C26 83:575 9149 2445 NC27 Normal Alkane C27 85.936 7287 1998 NC28 Normal Alkane C28 88.218 5526 1472 NC29 Normal Alkane C29 90.422 5078 1281 NC30 Normal Alkane C30 92.544 18246. 4520 NC31 Normal Alkane C31 94.622 2734 672 NC32 Normal Alkane C32 96.617 1998. 475` NC33 Normal Alkane C33 98.555 2309 444 NC34 Normal Alkane C34 100.435 1298 280 NC35 Normal Alkane C35 102.270 1170 245 NC36 Normal Alkane C36 104.233 868 145' NC37 Normal Alkane C37 106.430 598 106 NC38 Normal Alkane C38 108.914 643 84 NC39 Normal Alkane C39 111.796 408 53 NC40 Normal Alkane C40 114.923 510 54 NC41 Normal Alkane C41 118.953 223 24 •i n C ~~ BASELfNE RESOLUTI©N INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138724 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282492 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8248 FT Lon itude: Bottom Depth: FT Whole Oil GC Trace ~so7oao2.D U Z U Z U z U z U z U z U Z U z U z U Z U Z N Z ti U N z U Z ,~ Pr U .~ z N X U '~ £ Z U z N U 2 U m rn Z ~ < u, a r m rn o Z U m ti m ~ Z Z z U z z 2 Z Z z Z Z ~ z U Z rn r] O E Pristane/Phytane 2.28 A. BZ/n Ce Pristane/nC~7 0.44 B. TOUnC7 Phytane/n Cis 0.23 C. (nC®+n C,)/(CH+MCH) n C18/n C19 1.10 I. Isoheptane Value nC~~/nC29 6.29 F. nC7/MCH CPI Marzi4 1.04 U. CH/MCP NormaCParaff~ns 34.4 R. nC7l2MH Isoprenoids 5.3 S. n C6/22DM6 Cycloparaffins H. Heptane Value Branched (iso-) Paraffins MCH/n C~ BTX aromatics 0.8 mpXYUn Ce 6.38 Resolved unknowns 59.1 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG Bull.: V.79, p.801. °Marci,1993,OrgG;2Q1301. Company: CONOCOPHILLIPS Client ID: US138724 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8248 - FT Lab ID: CP282492 Sampling Point: File Name: G6070402.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 tso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyciohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP10 Isoprenoid C10 NC10 Normal Alkane C10 IP11 Isoprenoid C11 NC11 Normal Alkane C11 NC12 Normal Alkane C12 IP13 Isoprenoid C13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 IP15 Isoprenoid C15 NC14 Normal Alkane C14 IP16 Isoprenoid C16 NC15 Normal Alkane C15 12.676 403 15.303 3265. 17.180 660 18.389 15921 18.454 4909 19.438 4732 21.047 36601 23.028 6773 26.642 73386 27.934 10566 31.895 88649 36.807 80069 37.541 16157 40.294 11268 41.405 78033 44.841 15780 45.728 69096 413.376 25197 49.799 64007 76 1186 233 5893 1803 .1730 13442 2008 25615 3621 28754 .26653 4358 3653..: 24533 .4782 21284 6019 18337 • Company: CONOCOPHILLIPS Client ID: US138724 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8248 - FT Lab ID: CP282492 Sampling Point: File Name: G6070402.D NC16 Normal Alkane C16 53.651 51773 16023 IP18 Isoprenoid C18 55:586 16714 3630 NC17 Normal Alkane C17 57.302 46853 14219 IP19 Isoprenoid C19 (Pristane) 57.659 20629 4001 PHEN Phenanthrene 58.851 2838 748 NC1$ Normal Alkane C18 60.772 39259 11711 IP20 Isoprenoid C20 (Phytane) 61.232 9041 1618 NC19 Normal Alkane C19 64.079 35820 10298 NC20 Normal Alkane C20 67.230 31796 9224 NC21 Normal Alkane. C21 70:246 27057 7926 C25HB1 Highly Branch Isoprenoid C25 70.498 1481 337 NC22 Normal Alkane C22 73.131 25173 6882 NC23 Normal Alkane C23 75.894 21661 6125 NC24 Normal Alkane C24 78.549 18703 5263 NC25 Normal Alkane C25 81.100 16639 4655 NC26 Normal Alkane C26 83.553 13562 3754 NC27 Normal Alkane C27 85.917 11231 2991 NC28 Normal Alkane C28 88.198 8487 2261 NC29 Normal Alkane C29 90.405 7446 1898 NC30 Normal Alkane C30 92.538 4843 .1209 NC31 Normal Alkane C31 94.598 3683 941 NC32 Normal Alkane C32 96.598 2304 584. NC33 Normal Alkane C33 98.538 2529 482 NC34 Normal Alkane C34 100,417 1447. 304 NC35 Normal Alkane C35 102.257 970 204 NC36 Normal Alkane C36 404,210. 774 128 NC37 Normal Alkane C37 106.407 462 72 NC38 Normal Alkane C38 108.907 308 46 NC39 Normal Alkane C39 111.773 161 25 NC40 Normal Alkane C40 115.116 360 37 NC41 Normal Alkane C41 i• • BASELINE RESOLUTION, INC. WHOLE OIL GC _- Company: CONOCOPHILLIPS Client ID: US138724 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282492 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8248 FT Longitude: Bottom Depth: FT G6070421.D U z Pristane/Phytane 2.35 A. BLn Ce Pristane/n C17 0.45 B. TOUn C7 PhytaneMC78 0.23 C. (nC®+n C,)/(CH+MCH) n C~~/n Ct9 1.11 I. Isoheptane Value n C17/n C29 6.68 F. n C~/MCH CPI Marzi4 1.06 U. CH/MCP Normal.Paraffins 38.5 R. nC7I2MH Isoprenoids 6.2 S. nC6/22DMB Cycloparaffins H. Heptane Value Branched (iso-) Paraffins MCH/n C7 BTX aromatics mpXYUnCB Resolved unknowns 55.2 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPGBinl.: V.79, p.801. 4Marzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138724 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8248- FT Lab ID: CP282492 Sampling Point: File Name: G6070421.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 .Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane. TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene. PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP10 Isoprenoid C10 NC10 Normal Alkane C10 IP11 Isoprenoid C11 NC11 Normal Alkane C11 NC12 Normal Alkane C12 IP13 Isoprenoid C13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 IP15 .Isoprenoid C15 NC14 Normal Alkane C14 IP16 Isoprenoid C16 NC15 Normal Alkane C15 21.002 2855 1039 22.986 1355 399 26.595 46085 16210 27.892 8061 2783 31.855 103122 34151 36.772 112060 36527 37.503 22662 6104 40.257 16240 5364 41.372 111854 34879 44.805 22090 6813 45.698 98987 30630 48.345 35976 8721. 49.773 91087 26245 ~ k• Company: CONOCOPHILLIPS Client ID: US138724 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8248 - FT Lab ID: CP282492 Samplin Point: File Name: G6070421.D NC16 Normal Alkane C16 53.626 73337 22265 IP18 Isoprenoid C18 55.558 .23806 5140 NC17 Normal Alkane C17 57.279 66077 20034 IP19 Isoprenoid G19 (Pristane) 57.636 29503 5677 PHEN Phenanthrene 58.673 3997 986 NC18 Normal Alkane C18 60.749 54710 16541 IP20 Isoprenoid C20 (Phytane) 61.197 12562 2250 NC19 Normal Alkane C19 64.055 49412 14355 NC20 Normal Alkane C20 67.208 44025 12649 NC21 NarmalAlkane C21 70.221 37031 10736 C25H61 Highly Branch Isoprenoid C25 70.472 1833 419 NC22 Normal Alkane C22 73.105 33075 9408 NC23 Normal Alkane C23 75.867 29216 8245 NC24 Normal Alkane C24 78.520 24663 6989 NC25 Norma! Alkane C25 81.069 21993 6022 NC26 Normal Alkane C26 83.523 17594 4781. NC27 Normal Alkane C27 85.886 14550 3951 NC28 .Normal Alkane C28 88.169 10723 2901 NC29 Normal Alkane C29 90.373 9889 2453 NC30 Normal Alkane C30 92.505 6516 1657 NC31 Normal Alkane C31 94.568 5570 1321 NC32 Normal Alkane C32 96.566. 3509 870 NC33 Normal Alkane C33 98.508 4054 792 NC34 Normal Alkane C34 100.386 2292 527 NC35 Normal Alkane C35 102.222 1840 416 NC36 Normal Alkane C36 104.174 1529 273 NC37 Normal Alkane C37 106.371 1073 186 NC38 Normal Alkane C38 108.857 921 133 NC39 Normal Alkane C39 111.702 790 95 NC40 Normal Alkane C40 114.999 738 73 NC41 Normal Alkane C41 118.869 640 55 • BASELINE RESOLUTION, INC.. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138725 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282493 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8255 FT Longitude: Bottom Depth: FT Whole Oil GC Trace cso7oaoa.D U Z U Z U z U Z U Z U z U Z U U Z Z V Z U z o U z .+ U N 2 U M .] Z U N z ~ N u, U 2 U z N c U r .r H Z U a Z U Z Z V m rNi m P N~ r m m o .y U z uzi Z y z z z z Z z z z z z x a 0 F Prstane/Phytane 2.27 A. BZ/nCB Pristane/nC17 0.45 B. TOtJnC7 Phytaheln C18 0.24 C. (n Cs+n G~)/(CH+MCH) nC18/nC19 1.09 I. Isoheptane Value n Cl~/n C29 5.52 F. n C~/MCH CPI Marzi4 1.04 U. CH/MCP Normal Paraffins 34.5 R. n C7/2MH Isoprenoids 5.3 S. n C6/22DMB Cycloparaffins H. Heptane Value Branched (iso-) Paraffins MCH/n C~ BTX aromatics T.0 mpXYlJnCB 4.97 Resolved unknowns 59.0 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. sHalpern,H.L,1995,AAPGBulL: V.79, p.801. °Marzi,1993,OrgG;2Q,1301. Company: CONOCOPHILLIPS Well Name: NOATAK-1 Depth: 8255 - FT Sampling Point: Client ID: Project #: Lab ID: File Name: US138725 07-247-A CP282493 ' G6070404.D .. .. .. ..- IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DM6 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane ' 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.663 1004 383 NC8 Normal Alkane C8 15.305 7556. 2937 IP9 Isoprenoid C9 17.183 1440 528 MXYL m-Xylene 18.390 28760. 10696 , PXYL p-Xylene 18.454 8801 3340 OXYL o-Xylene 19.441 8812 3249 NC9 Normal Alkane C9 21.051 61959 22628 IP10 Isoprenoid C10 23.030 11439 3331 NC10 Normal Alkane C10 26.648 113678 38974 IP11 Isoprenoid C11 27.936 16766 5708 NC11 Normal Alkane C11 31.901 135120 44162 NC12 Normal Alkane C12 36.810 123723 39995 IP13 Isoprenoid C13 37.539 25199 6849 IP14 Isoprenoid C14 40.292 17900 5806.:.. NC13 Normal Alkane C13 41.408 120017 37530 1P15 Isoprenoid C15 44'.838 23471. 7168 - NC14 Normal Alkane C14 45.731 106994 32577 IP16 Isoprenoid C16 48.375 39298 9470 NC15 Normal Alkane C15 49.805 99821 28349 • ~_J Company: CONOCOPHILLIPS Client ID: US138725 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8255 - FT Lab ID: CP282493 Sampling Point: Fite Name: G6070404.D NC16 Normal Alkane C16 53.657 81230 24741 IP18 Isoprenoid C18 55.586 26755 5810 NC17 Normal Alkane C17 57.307 74424 21812 IP19 Isoprenoid C19 (Pristane) 57.656 33707 6524 PHEN Phenanthrene 58.705 3456 813 NC18 Normaf Alkane C18 60:779 62684 .18735 IP20 Isoprenoid C20 (Phytane) 61.231 14819 2718 NC19 Normal Alkane C19 64.083 57482. 16624 NC20 Normal Alkane C20 67.239 51558 14633 NC21 .Normal Alkane C21 70.254 44501 12847 C25HB1 Highly Branch Isoprenoid C25 70.505 2684 579 NC22 NormaLAlkane C22 73.138 42160 11454 NC23 .Normal Alkane C23 75.901 36204 10661 NC24 Normal Alkane C24 78.554 31479 8841 NC25 Normal Alkane C25 81.103 28375 .7909 NC26 Normal Alkane C26 83.557 23443 6347 NC27 Normal Alkane C27 85.922 19515. 5393 NC28 Normal Alkane C28 88.203 14791 4010 NC29 Normal Alkane C29 90.409 13493 3430 NC30 Normal Alkane C30 92.542 9399. 2299 NC31 Normal Alkane C31 94.601 7432 1869 NC32 Normal Alkane C32 96.602 5065 1263 NC33 Normal Alkane C33 98.539 5903 1203 NC34 Normal Alkane C34 100.421 3705. 779 NC35 Normal Alkane C35 102.255 2899 627 NC36 Normaf Alkane C36 104217 2182 405 NC37 Normal Alkane C37 106.412 1590 268 NC38 Normal Alkane. C38 408:901 .1294 184 NC39 Normal Alkane C39 111.767 1056 149 NC40 Normal Alkane C40 115.087 866 94 NC41 Normal Alkane C41 118.933 699 58 ~~ BASELINE RESCaLUTION, INC_ WHOLE OIL GC ti• i • Company: CONOCOPHILLIPS Client ID: US138725 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282493 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8255 FT Longitude: Bottom Depth: FT G6070405.D U 2 (~ Pristane/Phytane 2.34 A. BZJn CB Pristaneln C» 0.44 B. TOUn C7 Phytane/nC18 -0.23 C. (nCe+nC~)/(CH+MCH) nC~~/nC,9 1.11 I. Isoheptane Value nC1~MC29 6.44 F, nC7/MCH CPI Marzi4 1.05 U. CH/MCP Normal Paraffins 36.4 R. n C7/2MH Isoprenoids 5.7 S. nC~/22DM6 Cycloparaffins 0:0 H. Heptane Value Branched (iso-) Paraffins MCH/nC~ BTX aromatics 0.1 mpXYUnCB 6.62 Resolved unknowns 57.6 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. sHalpem,H.L,1995,AAPGBinl.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. company: CONOCOPHILLIPS Client ID: US138725 NeII Name: NOATAK-1 Project #: 07-247-A depth: 8255 - FT Lab ID: CP282493 3amplin Point: File Name: G6070405.D IC4 Iso-afkane C4 NC4 Normal Alkane C4 IC5 Iso-akane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 7.998 189 48 33DMP 3,3-Dimethylpentane CH Cyclohexane 8.309 966 402 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.665 128 39 NC8 Normal Alkane C8 15.304. 363 140 IP9 Isoprenoid C9 17.178 103 30 MXYL m-Xylene 18.394 1844 663 PXYL p-Xylene 18.459 559 205 OXYL o-Xylene 19.438 1328 481 NC9 Normal Alkane C9 21.043 18220 6691 IP10 Isoprenoid C10 23.027 5233 .1517 NC10 Normal Alkane C10 26.642 93883 32831 IP11 Isoprenoid C11 27.933 14814 5103 NC11 Normal Alkane C11 31.902 151066 48866 NC12 Normal Alkane C12 36.8.14 147913 47301 IP13 Isoprenoid C13 37.540 30233 7941 IP14 Isoprenoid. C14 40.292 20861 6780 NC13 Normal Alkane C13 41.412 144336 44570 1P15 Isoprenoid C15 44.840 .28378 8613 NC14 Normal Alkane C14 45.735 126814 39235 IP16 Isoprenoid C16 48.377 45836 10920 NC15 Normal Alkane C15 49.809 116856 33077 • C7 company: CONOCOPHILLIPS Client ID: US138725 Nell Name: NOATAK-1 Project #: 07-247-A )epth: 8255- FT Lab ID: CP282493 sampling Point: File Name: G6070405.D NC16 Normal Alkane C16 53.662 93675 28661 IP18 Isoprenoid C18 55.589 30264 6528 NC17 Normal Alkane C17 57.313 84769 25278 IP19 Isoprenoid C19 (Pristane) 57.665 37438 7370 PHEN Phenanthrene 58.708 4659 1106 NC18 Normal Alkane C18 60:783 69845 20695 IP20 Isoprenoid C20 (Phytane) 61.235 15971 2887 NC19 Normal Alkane C19 64.091 62920 18361 NC20 Normal Alkane C20 67.242 55567 15500 NC21 Normal Alkane C21 70.258 47581 13819 C25HB1 Highly Branch Isoprenoid C25 70.507 2021 458 NC22 Normal Alkane C22 73.141 42669 12024 NC23 Normal Alkane C23 75.905 37858 10765 NC24 Normal Alkane C24 78.561 32061 8751 NC25 Normal Alkane C25 81.108 28628 7832 NC26 Normal Alkane C26 83.561 23193 6433 NC27 Normal Alkane C27 85.926 19176 5295 NC28 .Normal Alkane C28 88.207 14329 3817 NC29 Normal Alkane C29 90.414 13167 3346 NC30 Normal Alkane C30 92.546 8918 2237 NC31 Normal Alkane C31 94.607 7295 1792 NC32 Normal Alkane C32 96.607 4860 1204;. NC33 Normal Alkane C33 98.545 5682 1120 NC34 Normal Alkane C34 100.428 3341 732 NC35 Normal Alkane C35 102.264 2665 568 NC36 Normal Alkane C36 104.227 2186 376 NC37 Normal Alkane C37 106.419 1683 285 NC38 Normal Alkane C38 108.913 1462 213 NC39 Normal Alkane C39 111.780 1161 150 NC40 Normal Alkane C40 115.090 1223 118 NC41 Normal Alkane C41 118.952 942 82 ~~ • Bp-SELINE RIESOLUTI©N, INC_ WHOLE OIL GC 6 Company: CONOCOPHILLIPS Client ID: US138726 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282494 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8265 FT Longitude: Bottom Depth: FT G6070422.D U Z • PristaneiPhytane 2.23 A: BZ/n Ce Pristane/n C» 0.44 B. TOUn C~ PhytaneMC18 0.24 C. (n CB+nC~)/(CH+MCH) n C~~/n C19 1.11 I. Isoheptane Value nC~~/nC29 6.56 F. nC~/MCH CPI Marzi4 1.06 U. CH/MCP Normal Paraffins 38.3 R. nC~/2MH Isoprenoids 6.2 S. nCb/22DM6 Cycloparaffihs H. Heptane Value Branched (iso-) Paraffins MCH/n C~ BTX aromatics_ mpXYUnCe Resolved unknowns 55.3 'Thompson, K.F.M.,1983.GCA:V.47, p.303.2Mango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPGBuh.: V.79, p.801. 4Mazzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138726 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8265 - FT Lab ID: CP282494 Sampling Point: File Name: G6070422.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 20.988 230 77 IP10 Isoprenoid C10 22.971 186 49 NC10 Normal Alkane C10 26.576 16102 5714 IP11 Isoprenoid C11 27.878 3297 1131 NC11 Normal Alkane C11 31.837 65640 21964 NC12 Normal Alkane C12 36.757 85460 28296 IP13 Isoprenoid C13 37.490 16858 4676 IP14 Isoprenoid C14 40.246 12635 4111 NC13 Normal Alkane C13 41.358 90527 29067 IP15 Isoprenoid C15 44.794 18230 5649 NC14 Normal Alkane C14 45.685 81065 25064 IP16 Isoprenoid C16 48.334 29069 7016 NC15 Normal Alkane C15 49.760 74198 21209 • company: CONOCOPHILLIPS Client ID: US138726 Nell Name: NOATAK-1 Project #: 07-247-A depth: 8265 - FT Lab ID: CP282494 Sampling Point: File Name: G6070422.D NC16 Normal Alkane C16 53.614 59867 18290 IP18 Isoprenoid C1$ 55.548 19579 4233 NC17 Normal Alkane C17 57.266 53786 16330 IP19 Isoprenoid C19 (Pristane) 57.623 23649 4487 PHEN Phenanthrene 58.662 3433 853 NC18 Normal Alkane C18 60.737 45182 13687 IP20 Isoprenoid C20 (Phytane) 61.195 10622 1889 NC19 Normal Alkane C19 64.045 40797 11707 NC20 Normal Alkane C20 67.197 36393 10145 NC21 Normal Alkane C21 70.212 30765 8909 C25HB1 Highly Branch Isoprenoid C25 70.469 2378 512 NC22 Normal Alkane C22 73.095 27734 7822 NC23 Normal Alkane C23 75.858 24474 7126 NC24 Normal Alkane C24 78.511 20719 5856 NC25 Normal Alkane C25 81.062 18351 4991 NC26 Normal Alkane C26 83.516 14507 3898 NC27 Normal Alkane C27 85.880 11923 3171 NC28 Normal Alkane C28 88.160 8724 2410 NC29 Normal Alkane C29 90.366 8198 2098 NC30 Normal Alkane C30 92.501 5358 1365 i~ NC31 NC32 Normal Alkane C31 Normal Alkane C32 94.562 96.560 5512 2785 1174 723 NC33 Normal Alkane C33 98.503 3291 650 NC34 Normal Alkane C34 100.384 2024 410 NC35 Normal Alkane C35 102.217 1500 329 NC36 Normal Alkane C36 104.173 1019 190 NC37 Normal Alkane C37 106.355 756 134 NC38 Normal Alkane C38 108.852 689 97 NC39 Normal Alkane C39 111.703 532 70 NC40 Normal Alkane C40 115.030 638 79 NC41 Normal Alkane C41 118.831 562 40 •i • 4• is BASELINE RESt~LLJTION, ~IwIC. WHOLE OIL GC ~. Company: CONOCOPHILLIPS Client ID: US138726 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282494 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8265 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070406.D U z U Z V Z U Z U Z U Z U N z >+ x s ~ U z U Z U Z U z N z ., U U z Z U Z U ,~ 2 O F ~ U ~ Z N U Z U Z U z m m Z U ,o'f .y N~< 'n M r m m o .i Z U U U t.f < e ~ z z Z z z Z 2 z z z z z x U ?CU Z ` Z Pristane/Phytane 2.19 A. BZ/n CB 2.34 Pristane/nC~7 0.45 B. TOUnC~ 18.81 Phytahe/n C18 0.23 C. (n Ca+n C,)~(cH+MCH) 0.36 n C~~InC19 1.07 I. Isoheptane Value n C17/n C29 4.98 F. n C7/MCH 0.34 CPI Marzi4 1.04 U. CH/MCP Normal Paraffins 33.3 R, n C7/2MH 3.46 Isoprenoids 4.8 S. nC~/22DM6 Cycloparaffins 0.1 H. Heptane Value 20.64 Branched (iso-) Paraffins 0.0 MCH/n C7 2.91 BTX aromatics 2.7 mpXYUnCe 2.59 Resolved unknowns 58.5 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895, sHalpern,H.L,1995,AAPG Bu11.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138726 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8265 - FT Lab ID: CP282494 Sam lin Point: File Name: G6070406.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 NormaLAlkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP10 Isoprenoid C10 NC10 Normal Alkane C10 IP11 Isoprenoid C11 NC11 Normal Alkane C11 NC12 Normal Alkane C12 IP13 Isoprenoid C13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 1P15 Isoprenoid C15 NC14 Normal Alkane C14 IP96 Isoprenoid C16 NC15 Normal Alkane C15 6.505 175 78 7.998 410 125 8.310 382 109 8.691 262 38 9.034 10.088 10.939 11.111 11.519 11.967 12.335 12.655 15.302 17.180 18.388 18.452 19.439 21.049 23.028 26.641 27.934 31.892 36.803 37.538 40.291 41.400 44:838 45.723 48.373 49.797 204 50 906 371 2636 1099 246 78 208 64 225 89 248 86 17044 6776 22538 8633` 2728 989 44155.: 1.6387 14106 5401 10445 3843 60015 21954 `9185 2755 80323 27728 11346 3841 87452 28648 76552 25513 15444 4181 10786 3478 72939 23579 14389 4397 63873 19599 23232 5578 58659 16973 company: CONOCOPHILLIPS Client ID: US138726 JVell Name: NOATAK-1 Project #: 07-247-A depth: 8265 - FT Lab ID: CP282494 Sampling Point: File Name: G6070406.D NC16 Normal Alkane C16 53.652 48262 14641 IP18 Isoprenoid C18 55.588 15965 3426 NC17 Normal Alkane C17 57.306 45145 13304 IP19 Isoprenoid C19 (Pristane) 57.659 20139 3955 PHEN Phenanthrene 58.708 2345 568 NC18 Normal Alkane C18 60.778 39063 11486 IP20 Isoprenoid C20 (Phytane) 61.240 9178 1648 NC19 Normal Alkane C19 64.085 36597 10507 NC20 Normal Alkane C20 67.238 33107 9540 NC21 Normal Alkane C21 70.253 28969 8301 C25HB1 Highly Branch Isoprenoid C25 70.509 1527 332 NC22 Normal Alkane C22 73.140 28448 7583 NC23 Normal Alkane C23 75.903 23890 6913 NC24 Normal Alkane C24 78.554 20602 5751 NC25 Normal Alkane C25 81.106 18502 4945 NC26 Normal Alkane C26 83.558 15325 4300 NC27 Normal Alkane C27 85.923 12867 3460 NC28 Normal Alkane C28 88.206 10028 2626 NC29 Normal Alkane C29 90.411 9071 2297 NC30 Normal Alkane C30 92.542 6297 1581 NC31 Normal Alkane C31 94.602 5256 1327 NC32 Normal Alkane C32 96.603 3489 844 NC33 Normal Alkane C33 98.543 3973 823 NC34 Normal Alkane C34 100.424 2615 562 NC35 Normal Alkane C35 102.259 1990 429 NC36 Normal Alkane C36 104.221 1574 288 NC37 Normal Alkane C37 106.413 1136 195 NC38 Normal Alkane C38 108.906 938 143. NC39 Normal Alkane C39 111.769 773 102 NC40 Normal Alkane C40 115.090 849 75 NC41 Normal Alkane C41 118.973 561 45 • U BASELINE ~NC_ WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138727 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282495 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8273 FT Lon itude: Bottom Depth: FT G6070417.D U 2 C Pristane/Phytane 2.32 A. BZJnCe Pristane/n C17 0.46 B. TOUn C7 Phytane/nC18 0.23 C. (nCB+nC,)/(CH+MCH) nC~~/nC19 1.10 I. Isoheptane Value nC~~/nC29 5.70 F. nC~IMCH CPI Marzi4 1.04 U. CH/MCP Normal Paraffins 35.t R: nC7I2MH Isoprenoids 5.4 S. n C~/22DMB Cycloparaffins 0.0 H. Heptane Value. Branched (iso-) Paraffins MCH/n C7 BTX aromatics 1.4 mpXYUn Ce Resolved unknowns 57.7 P~ 4.63 18.87 PZ 0.65 P3 5N~ 0.89 0.65 N2 6N1 94.48 K~ KZ 39.24' 5N{/6N~ 0.01 1.55 P3/NZ 3.83 Ih(24DMP/23DMP) 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPGBulL: V.79, p.801. °Marzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138727 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8273 - FT Lab ID: CP282495 Sampling Point: File Name: G6070417.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 10.121 166 42 ISTD Internal Standard MCH Methylcyclohexane 10.970 257 88 113TMCP 1,1,3,-Trimethylcyclopentane 11.155 106 16 ECP Ethylcyclopentane 11.547 32 13 124TMCP 1,2,4-Trimethylcyclopentane 11.988 82 23 123TMCP 1,2,3-Trimethylcyclopentane 12.360 90 23 TOL Toluene 12.682 3132 1225 NC8 Normal Alkane C8 15:322 13123 5058 IP9 Isoprenoid C9 17.198 2107 787 MXYL m-Xylene 18.404 38400 14305 PXYL p-Xylene 18.468 11865 4497 OXYL o-Xylene 19.454: 11153 4082 NC9 Normal Alkane C9 21.064 72235 26397 IP10 Isoprenoid C10 23.041 12464 3723 NC10 Normal Alkane C10 26.658 116641 39950 IP11 Isoprenoid C11 27.945. 17046 5843 NC11 Normal Alkane C11 31.911 133418 43073 NC12 Normal Alkane C12 36.822 119789 38943 IP13 Isoprenoid C13 37.551 24289 6621 IP14 Isoprenoid C14 40.305 17226 5588 NC13 Normal Alkane C13 41.420 114491 35808 IP15 Isoprenoid C15 44.852 22150 67$7 NC14 Normal Alkane C14 45.745 100941 30911 IP16 Isoprenoid C16 48.389 36910 8947 NC15 Normal Alkane C15 49.817 93166 27119 r~ ~J f ~ ~J Company: CONOCOPHILLIPS Client ID: US138727 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8273 - FT Lab ID: CP282495 Samplin Point: File Name: G6070417.D NC16 Normal Alkane C16 53.672 75520 23524 IP18 Isoprenoid C18 55.601 24984 5480 NC17 Normal Alkane C17 57.321 68878 20135 IP19 Isoprenoid C19 (Pristane) 57.674 31479 61:64 PHEN Phenanthrene 58.718 3078 715 NC18 Normal Alkane C18 60.790 57887 17543 IP20 Isoprenoid C20 (Phytane) 61.244 13576 2504 NC19 Normal Alkane C19 64.096. 52752 1519.1 NC20 Normal Alkane C20 67.248 47055 13543 NC21 Normal Alkane C21 70.262 40654 11836. C25H61 Highly Branch Isoprenoid C25 70.513 1901 457 NC22 Normal Alkane C22 73.145 37564 10587 NC23 Normal Alkane C23 75.906 32843 9466 NC24 Normal Alkane C24 78.557 28518 8008 NC25 Normal Alkane C25 81.107 25623 7059 NC26 Normal Alkane C26 83.558 21027 5646 NC27 Normal Alkane C27 85.922 17544 4729 NC28 Normal Alkane. C28 88.204 13290 3680 NC29 Normal Alkane C29 90.411 12081 3143 NC30 Normal Alkane C30 92:539 8317 2091 NC31 Normal Alkane C31 94.598 6730 1680 NC32 Normal Alkane C32 96.597 4674 1147 NC33 Normal Alkane C33 98.541 5262 1054 NC34 Normal Alkane C34 100:418. 3460. 753 NC35 Normal Alkane C35 102.254 2657 586 NC36 Normal Alkane C36 104.214 2022 350 NC37 Normal Alkane C37 106.414 1464 268 NC38 Normal Alkane C38 108.898 1313 180 NC39 Normal Alkane C39 111.759 932 122 NC40 Normal Alkane C40 115.080 1009 94 NC41 Normal Alkane C41 118.883 712 63 • C • BASELINE RESOLUTION. INC_ WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138727 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282495 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8273 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070409.D V Z U Z U Z U z U z U z U Z U z U z U z U 5 .a U Z U a z U Z U Z N U ~ U ,y Z r Z .y Z U "'~ Z U ~ .-~ v, ~ ~ r m Z U ~ m o .y Z U U U U .a ~ Z Z 2 Z Z Z Z Z Z Z Z 5 N U H~O Z Pristane/Phytahe 2.33 A. BZIn GB Pristane/nC17 0.44 B. TOL/n C7 Phytaneln C18 0.23 C. (n C®+n C~)/(CH+MCH) nC1e/nC~a 1.11 I. Isoheptane Value nCi~/nC29 6.62 F. nC7/MGH CPI Marzi4 1.06 U. CH/MCP NormalParaffins 36.8 R. nC7/2MH Isoprenoids 5.8 S. nCs/22DMB Cycioparaffins H. Neptane Value Branched (iso-) Paraffins MCH/n C7 BTX aromatics 0.1 mpXYLlnGe 6.48 Resolved unknowns 57.2 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPGBull.s V.79, p.801. °Mazzi,1993,OrgG;2Q,1301. Company: CONOCOPHILLIPS Client ID: US138727 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8273 - FT Lab ID: CP282495 Sampling Point: File Name: G6070409.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 15.304 249 84 IP9 Isoprenoid C9 17.175 80 22 MXYL m-Xylene 18.395 1237 441. PXYL p-Xylene 18.459 376 136 OXYL o-Xylene 19.437 1047 37Z NC9 Normal Alkane C9 21.041 15166 5615 IP10 Isoprenoid C10 23.025 4291 1272. NC10 Normal Alkane C10 26.639 80616 28200 IP11 Isoprenoid C11 27.931 12472- 4309 NC11 Normal Alkane C11 31.897 127003 41221 NC12 Normal Alkane C12 36.808 121822 39906 IP13 Isoprenoid C13 37.537 24583 6419 IP14 NC13 ,Isoprenoid C14 Normal Alkane C13 40.291 41.407 16572 116638 5389 36503 ' IP15 Isoprenoid C15 44.840 23007' 7045 ` NC14 Normal Alkane C14 45.733 100966 31395 IP16 Isoprenoid C16 48.380 36206: 8805: NC15 Normal Alkane C15 49.807 91879 26334 Company: CONOCOPHILLIPS Client ID: US138727 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8273 - FT Lab ID: CP282495 Sampling Point: File Name: G6070409.D NC16 Normal Alkane C16 53.661 73674 22418 IP18 Isoprenoid C18 55.592 23474 5123 NC17 Normal Alkane C17 57.312 65411 19683 IP19 Isoprenoid C19 (Pristane) 57.670 28538 5582 PHEN Phenanthrene 58.710 3872 950 NC18 Normal Alkane C18 60.784 54018 16128 IP20 Isoprenoid C20 (Phytane) 61.233 12224 2203 NC19 Normal Alkane C19 64.091 48586 14192 NC20 Normal Alkane C20 67244 42823 12258 NC21 Normal Alkane C21 70.257 36521 10468. C25HB1 Highly Branch Isoprenoid C25 70.512 1743 387 NC22 Normal Alkane C22 73.142 32492 9148 NC23 Normal Alkane C23 75.906 28987 8172 NC24 Normal Alkane C24 78.559 24502 6877 NC25 Normal Alkane C25 81.108 21745 5825 NC26 Normal Alkane C26 83.560 17508 4768 NC27 Normal Alkane C27 85.925 14493 3891 NC28 .Normal Alkane C28 88.206 10705 2855 NC29 Normal Alkane C29 90.414 9874 2512 NC30 Normal Alkane C30 92:543 6595 1691 NC31 Normal Alkane C31 94.605 5549 1353 NC32 Normal Alkane C32 96.602 3561 904 NC33 Normal Alkane C33 98.542 4084 828 NC34 Normal Alkane C34 100.426 2331 550 NC35 Normal Alkane C35 102.264 2005 430 NC36 Normal Alkane C36 104.219 1861 303 NC37 Normal Alkane C37 106.416 1264 203 NC38 Normal Alkane C38 1-08.916 1045 145 NC39 Normal Alkane C39 111.770 885 115 NC40 Normal Alkane C40 115.078 812 79 NC41 Normal Alkane C41 118.943 656 59 • EL_ WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138728 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282496 Lease: Sample Type: SWC ROTARY soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8287 FT Longitude: Bottom Depth: FT G6070353.D U Z I`~ • Pristane/Phytane 2.25 A. BZln CB Pristaneln C17 0.45 B. TOL/n C7 Phytane/n C18 0.24 C. (n Ca+n C,)/(CH+MCH) nC~$/nCt9 1.05 I. Isoheptane Value nC~~/nC29 5.16 F. nC~/MCH CPI Marzi4 1.04 U. CH/MCP Normal Paraffins 35.6 R. nC~/2MH Isoprenoids 5.4 S. nC~/22DMB Cycloparaffins H. Heptane Value Branched (iso-) Paraffins MCH/nC~ BTX aromatics 1.0 mpXYUnCe Resolved unknowns 57.8 5 ~Thompsoq K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPGBinl.: V.79, p.801. °Mazzi,1993,OrgG;2Q,1301. Company: CONOCOPHILLIPS Client ID: US138728 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8287 - FT Lab ID: CP282496 Sampling Point: File Name: G6070353.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP10 Isoprenoid C10 NC10 Normal Alkane C10 IP11 Isoprenoid C11 NC11 Normal Alkane C11 NC12 Normal Alkane C12 IP13 Isoprenoid G13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 IP15 Isoprenoid G15 NC14 Normal Alkane C14 IP16 Isoprenoid C16 NC15 Normal Alkane C15 12.668 523 15.311 3345 17.191 770 18.395 14142 18.461 4324 19.449 3987 21.057 28243 23.040 5275 26.650 53996 27.947 7962 31.903 66026 36.817 61209 37.556 12439 40.310 8773 41.418 59304 44.857 11840 45.742 53193 .48.395 19617 49.817 49263 177 1210 250 5233 1616 1451 10430 1543 18947 2730 22091 20198 3338 2852 - 18985 ' 3712 16633 4766 14434 • • Company: CONOCOPHILLIPS Client ID: US138728 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8287 - FT Lab ID: CP282496 Samplin Point: File Name: G6070353.D NC16 Normal Alkane C16 IP18 Isoprenoid C18 NC17 Normal Alkane C17 IP19 Isoprenoid C19 (Pristane) PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C21 C25H61 Highly Branch Isoprenoid C25 NC22 Normal Alkane C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane C26 NC27 Normal Alkane C27 NC28 Normal Alkane C28 NC29 Normal Alkane C29 NC30 Normal Alkane C30 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 NormaFAlkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkane. C38 NC39 Normal Alkane C39 NC40 Normal Alkane C40 NC41 Normal Alkane C41 53.673 41105 12553 55.:610 .13582 2910 57.326 38201 11536 57.683 17270 3397 58.722 1866 455 60.798 32653 9889. 61.251 7674 1378 64.104 31127 8812. 67.256 27167 7982 70.270 23564 6794 70.524 1217 286 73.152 22192 6114. 75.915 19333 5409 78.567 17067 4663. 81.118 15244 4207 83.572 12660 3417 85.937 10600 2906 88.219 8082 2158 90.429 7401 1859 92.556 5529 1339 94.617 4143 1021 96.618 2788 701 98.557 3404 669 100.440 2099 451 102.274 1760 362 104:127 110 41 106.436 938 153 108.926 770 103 111.789 610 77 115.403 715 62 118.967 405 34 • • ~. Inge. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138728 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282496 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8287 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070352.D U Z V z U Z U Z U ~ Z U 2 U z r z U Z U z U z .. U z N U to Z U W Z ~n U '^ W z U U 5 ~ Z rNai z N U Z U m y Z ° ,y n h l0 ~ m U M m P M N w d Z Z 2 Z Z Z Z Z Z Z Z 2 U M'~O Z Pristane/Phytane 2.29 A. BZIn Ce Pristane/n C~~ 0.44 B. TOUn C7 Phytane/nC1B 0.23 C. (n C8+rrC7)/(CH+MCH) nC~~/nC19 1.10 I. Isoheptane Value n CIS/n C29 5.82 F. n C7/MCH CPI Marzi4 1.05 U. CH/MCP Normal Paraffins 36.9 R. n C7I2MH Isoprenoids 5.7 S. nC~/22DMB Gycloparaffins H. Heptane Value Branched (iso-) Paraffins MCH/nC~ BTX aromatics 0.1 mpXYUn C8 Resolved unknowns 57.1 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.I.,1995,AAPG Bull.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138728 Well Name: NOATAK-1 Project #: 07-247-A Depth: ~ 8287 - FT Lab ID: CP282496 5amplin Point: File Name: G6070352.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 15.314 108 37 IP9 Isoprenoid C9 17.193 110 29 MXYL m-Xylene 18.402 1562 .555. PXYL p-Xylene 18.467 444 166 OXYL o-Xylene 19.449 1036 379 NC9 Normal Alkane C9 21.055 12806 4726 iP10 Isoprenoid C10 23.040 3425 ' 986 NC10 Normal Alkane C10 26.651 54774 19355 1P14 Isoprenoid C11 27.948 8488 2902 NC11 Normal Alkane C11 31.907 83045 27285 NC12 Normal Alkane C12 36.822 78962 26363 IP13 Isoprenoid C13 37.557 16014 4248 IP14 Isoprenoid C14 40.310 1.1214 3586 NC13 Normal Alkane C13 41.421 77073 24456 1P15 Isoprenoid C15 ; 44.858 15445 4784`- NC14 Normal Alkane C14 45.746 67944 21487 IP16 Isoprenoid C16 48.396 24835 5995 NC15 Normal Alkane C15 49.820 62792 18353 r~ Company: CONOCOPHILLIPS Client ID: US138728 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8287 - FT Lab ID: CP282496 Sampling Point: File Name: G6070352.D NC16 Normal Alkane C16 53.674 51224 15490 IP18 Isoprenoid C18 55.609 .16637 3653 NC17 Normal Alkane C17 57.327 46715 13999 IP19 Isoprenoid C19 (Pristane) 57..682. 20661. 4126 PHEN Phenanthrene 58.722 2561 650 NC18 Normal Alkane C18 60.796 39214 11583 IP20 Isoprenoid C20 (Phytane) 61.259 9015 1632 NC19 Normal Alkane C19 64.103 35762 10291 NC20 Normal Alkane C20 67.254 31700 9227 NC21 Normal Alkane C21 70.266 27402 8117 C25HB1 Highly Branch Isoprenoid C25 70.520 1184 270 NC22 Normal Alkane C22 73:151 24641 7056 NC23 Normal Alkane C23 75.913 22170 6303 NC24 Normal Alkane C24 78.567 19.114 5260 NC25 Normal Alkane C25 81.118 16960 4640 NC26 Normal Alkane C26 83.572 13942 3876 NC27 Normal Alkane C27 85.936 11696 3184 NC28 Normal Alkane C28 88.219 8717 2327 NC29 Normal Alkane C29 90.425 8023 2051 NC30 Normal Alkane C30 92:558 5643 1430 NC31 Normal Alkane C31 94.618 4505 1084 NC32 Normal Alkane C32 96.617 3054 792 NC33 Normal Alkane C33 98.557 3707 719 NC34 Normal Alkane C34 .100.439 2143 474 NC35 Normal Alkane C35 102.277 1833 391 NC36 NormalAlkane C36 104.235 1366 260 NC37 Normal Alkane C37 106.428 1741 238 NC38 Normal Alkane C38 108..918 914:. 135 NC39 Normal Alkane C39 111.790 810 104 NC40 Normal Alkane C40 11.5.092. 898 85 NC41 Normal Alkane C41 118.971 606 53 • ~`• C • WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138728 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282496 Lease: Sample Type: SWC ROTARY repeat of soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8287 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070395.D U Z U Z U 2 U Z U ~ Z V Z U z v z U z U z U Z `~ U Z N U N 2 U w z U ~n Z U ~ .°. z U U ~ Z Z U w '+ Z U N° ~~ °' rn O ti V ~ ~ Z Z Z U Z z z 2 Z 2 Z 2 Z Z Z Z a ° w r H a x U a O Z ~-+ Pristahe/Phytane 2.31 Pristane/n C17 0.45 PhytaneM C18 -0.23 nC~~lnC19 1.09 n C~~/n C29 5.44 CPI Marzi4 1.05 Normal Paraffins 37.2 Isoprenoids 5.7 Cycloparaffins Branched (iso-) Paraffins BTX aromatics. 0.1 Resolved unknowns 56.9 A. BZIn Ce B. TOIJn C7 C. , (n Ce+n C~)/(CH+MCH) I. Isoheptane Value F. nC~/MCH U. CH/MCP R. n C~/2MH S. nCs/22DM6 H. Heptane Value. MCH/n C7 mpXYlJn C8 2 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. sHalpem,H.L,1995,AAPGBinl.: V.79, p.801. °Marzi,1993,OrgG;2Q,1301. Company: CONOCOPHILLIPS Client ID: US138728 Jllell Name: NOATAK-1 Project #: 07-247-A Depth: 8287 - FT Lab ID: CP282496 Sam lin Point: File Name: G6070395.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard ' MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 15.325 84 IP9 Isoprenoid C9 17.198 66 MXYL m-Xylene 18.415 1444 PXYL p-Xylene 18.480 438 OXYL o-Xylene 19.459. 1003 NC9 ~ Normal Alkane C9 21.064 12337 IP10 Isoprenoid C10 23.048 3199 NC10 Normal Alkane C10 26.658 52748 IP11 Isoprenoid C11 27.953 8169 NC11 Normal Alkane C11 31.912 79557 NC12 Normal Alkane C12 36.824 76016 IP13 Isoprenoid C13 37.559 15246 IP14 Isoprenoid C14 40.313 10696 NC13 Normal Alkane C13 41.422 73953 IP15 Isoprenoid C15 44.859 14836 NC14 Normal Alkane C14 45.746 65124 IP16 Isoprenoid C16 48:396 23955. NC15 Normal Alkane C15 49.820 60499 30 21 521 157 366 4562 948. 18494 2796. 26176 2531.1 4082 3456 ' 23602 4489 20302 5745 17618 • • Company: CONOCOPHILLIPS Client ID: US138728 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8287 - FT Lab ID: CP282496 Sampling Point: File Name: G6070395.D NC16 Normal Alkane C16 IP18 Isoprenoid C18 NC17 Normal Alkane C17 IP19 Isoprenoid C19 (Pristane) PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C21 C25H61 Highly Branch Isoprenoid C25 NC22 Normal: Alkane C22 NC23 Normal Alkane C23 NC24 .Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane C26 NC27 Normal Alkane C27 NC28 Normal Alkane C28 NC29 Normal Alkane C29 NC30 Normal Alkane C30 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 Normal Alkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkane C38 NC39 Normal Alkane C39 NC40 Normal Alkane C40 NC41 Normal Alkane C41 53.673 49745 15028 55.607 16174 3497 57.323 45237 13574 57.679 20170. 3872 58.727 2582 628 60.793 38218 11485 61.245 8748 1563 64.098 35028 10270 67.251 31339 8914 70.261 27444 7989. 70.516 1182 263 73.145 24685 6963. 75.907 22311 6305 78.560 19130 5377 81.108 17289. 4769 83.562. 14244 3867 85.927 11872 3162 88.209 8917 2423 90.416 8310 2082 92.547. 5770 1422 94.607 4753 1158 96.607 3095 772 98.548 3754 749 100.430 2148 494 102.266 2004 421 104.231 1497 260 106.430 1290 205 108.922 968 138 111.787 768 112 115.120 761 85 118.964 875 74 C, !~ BASELINE WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138729 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282497 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8290 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070418.D U 2 U Z U z z U Z U Z U Z U z U Z V Z N U .] V Z ry >. 'G U ~ m z U Z w U a z ~ O U E z ~ U i~ H Z U V Z Z 0. Z Z 2 U V U U~ m o .+ ~ a z z Z z Z z z z z z Pristane/Phytahe `2.16 A. 87Jn Ce 2.69 Pristane/nC~~ 0.44 B. TOUnCi 21.88 Phytane/nCte 0.24 C. (nc,+nC,)/(CH+MCM) 0.33 nC~~/nC~y 1.09 I. Isoheptane Value 0.88 nC~~/nGza 5.49 F. nC~/MGH 0.35 CPI Marzi4 1.04 U. CH/MCP 9.60 Normal Paraffins.: 33.1 R, nC~/2MH 12.03 Isoprenoids 5.0 S. nC~/22DMB Cycloparaffins 0.1 H. Heptane Value 18.77 Branched (iso-) Paraffins 0.0 MCH/n C~ 2.87 BTX aromatics 1.Z mpXYUn Ce 3.10 Resolved unknowns 59.7 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPGBull.s V.79, p.801. 4Marzi,1993,OrgG;2Q,1301 Company; CONOCOPHILLIPS Client ID: US138729 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8290 - FT Lab ID: CP282497 5amplin Point: File Name: G6070418.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DM6 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 6.542 247 11.7 22DMP 2,2-Dimethylpentane MCP Methylcyclopehtane 7.260 94 35 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 8.024 665 282 33DMP 3,3-Dimethylpentane CH Cyclohexane 8.338 902 429 2MH 2-Methylhexane 8.720 86 39 23DMP 2,3-Dimethylpentane 8.773 45 17 11DMCP 1,1-Dimethylcyclopentane 8.860 42 15 - 3MH 3-Methylhexane 9.059 158 55 1C3DMCP 1-cis-3-Dimethylcyclopentane 9.294 83 ' 25 1T3DMCP 1-trans-3-Dimethylcyclopentane 9.406 89 28 3EP 3-Ethylpentane 9.470 28 16 1T2DMCP 1-trans-2-Dimethylcyclopentane 9.517 105 41 NC7 Normal Alkane C7 10.111 1035 405 ISTD Internal Standard 10.331 124 19 MCH Methylcyclohexane 10.961 2969 1231 113TMCP 1,1,3,-Trimethylcyclopentane 11.134 242 76 ECP Ethylcyclopentane 11.537 250 64 124TMCP 1,2,4-Trimethylcyclopentane 11.984 209 80 123TMCP 1,2,3-Trimethylcyclopentane 12.354 197 77 TOL Toluene 12.669 22646 9240 NC8 Normal Alkane C8 15.314 17249•` .6632: IP9 Isoprenoid C9 17.190 1983 750 MXYL m-Xylene 18.397 40650 1:51:55 PXYL p-Xylene 18.460 12863 4895 OXYL o-Xylene 19.445 7590 2794 NC9 Normal Alkane C9 21.053 44814 16577 IP10 Isoprenoid C10 23.033 7894` 2338: NC10 Normal Alkane C10 26.647 92416 32280 IP11 Isoprenoid C11 27.939 44194 4839 NC11 Normal Alkane C11 31.905 135653 43806 NC12 Normal Alkane C12 36.819 132342 42562 IP13 Isoprenoid C13 37.546 26768 7267 IP14 Isoprenoid C14 40.300 18993 6108 NC13 Normal Alkane C13 41.418 130541 41272 IP15 Isoprenoid C15 44.848 26206 7996 NC14 Normal Alkane C14 45.743 117590 36555 IP16 Isoprenoid C16 48.387 42857 10186 NC15 Normal Alkane C15 49.817 109320 31063 :ompany: CONOCOPHILLIPS Client ID: US138729 Nell Name: NOATAK-1 Project #: 07-247-A )epth: 8290 - FT Lab ID: CP282497 sampling Point: File Name: G6070418.D NC16 Normal Alkane C16 53.670 89835 26650 IP18 Isoprenoid C18 55.598 29078 6347 NC17 Normal Alkane C17 57.321 82346 24128 IP19 Isoprenoid C19 (Pristane) 57.672 36419 7071 PHEN Phenanthrene 58.715 4461 1071 NC18 Normal Alkane C18 60.792 69675 20367 IP20 Isoprenoid C20 (Phytane) 61.243 16822 3025 NC19 Normal Alkane C19 64.097 63802 18347 NC20 Normal Alkane C20 67.248 57171 16209 NC21 Normal Alkane C21 70.262 48486: 14354 C25H61 Highly Branch Isoprenoid C25 70.513 3072 690 NC22 NormaLAlkane C22 73.15.1 56327 13211 NC23 Normal Alkane C23 75.909 39536 11096 NC24 Normal Alkane C24 78.559 35029 9734 NC25 Normal Alkane C25 81.107 30956 8403 NC26 Normal Alkane C26 83.559 25608 6991 NC27 Normal Alkane C27 85.923 21351 5921 NC28 Normal Alkane C28 88.206 16170 4282 NC29 Normal Alkane C29 90.408 14998 3817 NC30 Normal Alkane C30 92:540 ` 10747 2622 NC31 Normal Alkane C31 94.600 8581 2134 NC32 Normal Alkane C32 96.597 5797 1428 NC33 Normal Alkane C33 98.539 6601 1388 NC34 Normal Alkane C34 100.414 3963 883 NC35 Normal Alkane C35 102.251 3319 712 NC36 Normal Alkahe C36 104.219 2589 481 NC37 Normal Alkane C37 106.413 2038 348 NC38 Normal Alkane C38 108.887 1651 239 NC39 Normal Alkane C39 111.753 1285 173 NC40 Normal Alkane C40 115.068 1779 147 NC41 Normal Alkane C41 118.948 1230 96 L` BASELfNE RESOLUTION, INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138730 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282498 Lease: Sample Type: SWC ROTARY combined Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8297 FT Longitude: Bottom Depth: FT G6070411.D U Z • Pristane/Phytane 2.24 A. BZJn CB Pristane/nC~~ 0.44 B. TOUnC~ Phytane/nC18 0.23 C. (nCe+nC,)1(CH+MCH) n C,~/n C19 1.08 I. Isoheptane Value nC~~/nC29 5.27 F. nC7/MCH CPI Marzi4 1.05 U. CH/MCP Normal Paraffhs 38.3 R. nC7/2MH Isoprenoids 5.8 S. n C~/22DM6 Cycloparaffins H. Heptane Value. Branched (iso-) Paraffins MCH/n C~ BTX aromatics 0.0 mpXYUn Ge" Resolved unknowns 55.7 2.93 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPGBulL: V.79, p.801. °Mazzi,1993,OrgG;20,1301. ;ompany: CONOCOPHILLIPS Client ID: US138730 Nell Name: NOATAK-1 Project #: 07-247-A )epth: 8297 - FT Lab ID: CP,282498 yam ling Point: File Name: G6070411.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DM6 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane I 1C3DMCP 1-cis-3-Dimethylcyclopentane i 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP , 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane. TOL Toluene 12.673 99 22 NC8 Normal Alkane C8 15.302 228 86 IP9 Isoprenoid C9 MXYL m-Xylene 18.394 495 189. PXYL p-Xylene 18.458 172 62 OXYL o-Xylene 19.434 420 154 NC9 Normal Alkane C9 21.037 6561 2432 IP10 Isoprenoid C10 23.021 1972 585 NC10 Normal Alkane C10 26.627 40110 14223 IP11 Isoprenoid C11 27.925 6413 2198 NC11 Normal Alkane C11 31.882 72221 23450 NC12 Normal Alkane C12 36.797 80567 26356 IP13 Isoprenoid C13 37.531 16385 4358 IP14 Isoprenoid C14 40.287 12108 3931 NC13 Normal Alkane C13 41.399 87340 28156 IP15 Isoprenoid C15 44:836 18543 5648 NC14 Normal Alkane C14 45.726 82581 25692 IP16 Isoprenoid C16 48.375 30842 7445 NC15 Normal Alkane C15 49.801 79619 22949 ~J ~• Company: CONOCOPHILLIPS Client ID: US138730 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8297 - FT Lab ID: CP282498 Sampling Point: File Name: G6070411.D NC16 Normal Alkane C16 53.655 66517 20344 IP18 Isoprenoid C18 55:588. 21557 4631 NC17 Normal Alkane C17 57.307 60976 18217 IP19 Isoprenoid C19 (Pristane) 57.664 26990 5265 PHEN Phenanthrene 58.705 3736 894 NC18 Normal Alkane C18 60.779 52283 15645 IP20 Isoprenoid C20 (Phytane) 61.230 12039 2122 NC19 Normal Alkane C19 64:085 48560 14014 NC20 Normal Alkane C20 67.237 43724 12478 NC21 Normal Alkane C21 70.252 37803 11126 C25HB1 Highly Branch I soprenoid C25 70.503 1703 388 NC22 Normal Alkane C22 73.135 34792 9734 NC23 Normal Alkane C23 75.898 31081 8683 NC24 Normal Alkane C24 78.550: 26633 7481 NC25 Normal Alkane C25 81.098 24057 6738 NC26 Normal Alkane C26 83.550 19762 5323 NC27 Normal Alkane C27 85.913 16630 4626 NC28 Normal Alkane C28 88.197 12591 3441 NC29 Normal Alkane C29 90.398 11581 2943 NC30 Normal Alkane C30 92.533 7839 1989 NC31 Normal Alkane C31 94.594 6533 1621 NC32 Normal Alkane C32 96.593 4357 1109 NC33 Normal Alkane C33 98.531 4966 1059 NC34 Normal Alkane C34 100.413 3059 684 NC35 Normal Alkane C35 102.249 2460 561 NC36 Normal Alkane C36 104:207. 1828 339 NC37 Normal Alkane C37 106.394 1702 263 NC38 Normal Alkane C38 1D8.896 1164 181 NC39 Normal Alkane C39 111.748 1052 131 NC40 Normal Alkane C40 115:066 973 102 NC41 Normal Alkane C41 118.931 789 68 C BASELINE R'ESOLUTI©N, INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138731 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282499 Lease: Sample Type: SWC ROTARY combined Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8299 FT Lon itude: Bottom Depth: FT Whole Oil GC Trace G6070412.D V 2 U U Z z U U Z z U Z U Z U Z U U Z Z U Z N Z N U Z ri U z U z a U Z ip ~ V p, 2 U Z N U O1 Z U U Z o Z .i U .+ Z U n ~ ~ 2 Z y Z Z 2 Z tJ U m ~ .a r aN Z z z z z E Z i-+ ~ Pristane/Phytane 2:25 A. BZ/n Ce P~ ` Pristane/nC17 0.44 B. TOUnC7 P2 PhytanelnCle 0.23 C. (nCe+n C,)/(CH+MCH) P3 nC~a/nC19 1.08 I. Isoheptane Value 5N1 n Cl~ln C29 5.00 F, n C7/MCH Nz CPI Marzi4 1.05 U. CH/MCP 6N1 100.00 Normal Paraffins 38.7 R: n Cy/2MH Kl Isoprenoids 5.8 S. nCs/22DM6 KZ Cyclopaiaffins H. Heptane Value 5N~/6N1 Branched (iso-) Paraffins MCH/n C7 P~/NZ BTX aromatics 0.1 mpXYlJn C8 4.61 In(24DMP/23DMP) Resolved unknowns 55.2 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPGBulL: V.79, p.801. 4Marzi,1993,OrgG;20,1301, Company: CONOCOPHILLIPS Client ID: US138731 JVell Name: NOATAK-1 Project #: 07-247-A Depth: 8299 - FT Lab ID: CP282499 5amplin Point: File Name: G6070412.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane G5 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DM6 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 .Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP - 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.669 159 42 NC8 Normal Alkane C8 15.304 712 262 IP9 Isoprenoid C9 17.177 101 35 MXYL m-Xylene 18.391 2509 907 PXYL p-Xylene 18.456 771 283 OXYL o-Xylene 19.436 :.1445 526 ; NC9 Normal Alkane C9 21.040 17900 6627 IP10 Isoprenoid C10 23.023 4543 1364 NC10 Normal Alkane C10 26.635 78360 27344 IP11 Isoprenoid C11 27.928 12153 4185 NC11 Normal Alkane C11 31.893 126920 41626 NC12 Normal Alkane C12 36.807 138325 44492 IP13 Isoprenoid C13 37.534 27403 7540 IP14 Isoprenoid C14 40.289 21274 6804 NC13 Normal Alkane C13 41.410 154613 46772 IP15 Isoprenoid C15 44.838 32886 10164 NC14 Normal Alkane C14 45.738 149811 44600 IP16 Isoprenoid C16 48.379 56442 13468 NC15 Normal Alkane C15 49.813 146940 41884 :~ company: CONOCOPHILLIPS Client ID: US138731 Nell Name: NOATAK-1 Project #: 07-247-A depth: 8299- FT Lab ID: CP282499 Sampling Point: File Name: G6070412.D NC16 Normal Alkane C16 53.666 123632 36145 IP18 Isoprenoid C18 55.590 40636 8901 NC17 Normal Alkane C17 57.317 115246 33450 IP19 Isoprenoid C19 (Pristane) 57,670 59156 9726 PHEN Phenanthrene 58.705 6631 1622 NC18 Normal Alkane C18 60.788 98546 29054 IP20 Isoprenoid C20 (Phytane) 61.231 22691 4061 NC19 Normal Alkane C19 64.094 91375 26053 NC20 Normal Alkane C20 67.246 83066 23886 NC21 Normal Alkane C21 70:262 72001 20828 C25H61 Highly Branch Isoprenoid C25 70.507 3339 779 NC22 Normal Alkane C22 73.143 66214 19039 NC23 Normal Alkane C23 75.903 59800 17162 NC24 Normal Alkane C24 78:555 51753 14379 NC25 Normal Alkane C25 81.106 46920 12464 NC26 Normal Alkane C26 83.558 38763 10550 NC27 Normal Alkane C27 85.920 32713 8891 NC28 Normal Alkane C28 88.201 24806 6677 NC29 Normal Alkane C29 90.405 23034 5713 NC30 .Normal Alkane C30 92:537. 15901 4058 NC31 Normal Alkane C31 94.b97 13212 3287 NC32 Normal Alkane C32 96.596 8777 2193 NC33 Normal Alkane C33 98.535 10355 2068 NC34 Normal Alkane C34 100.417 6340 1390 NC35 Normal Alkane C35 102.252 5084 1144 NC36 Normal Alkane C36 104.213. 3981 723 NC37 Normal Alkane C37 106.406 3027 534 NC38 Normal Alkane C38 108.892 2325 353 NC39 Normal Alkane C39 111.750 1997 267 NC40 Normal Alkane C40 115.061 2013. 21A NC41 Normal Alkane C41 118.928 1472 131 •i `• I. BASELINE RES©LUTION, INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138732 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282500 Lease: Sample Type: SWC ROTARY combined Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8301 FT Longitude: Bottom De the FT Whole Oil GC Trace G6070413.D U z z v .°, z z O U U Z Z U Z U Z U Z U Z U Z U U Z Z N U m Z U Z N z U ~ H Z U ~ '>SC Z U a Z U Z U Z U m N m °~ m~ ~ m ~, m o r, Z Z z m z z z m ~ z U U W 1 Z Z Z U a z N O E Pristane/Phytane 2.23 Pristane/n C17 0.44 Phytane/n C18 0.23 n C~ $/n C19 1.07 n C~~/n C29 4.74 CPI Marzi° 1.05 Normal Paraffins 36.9 Isoprenoids 5.4 CycloparafBns Branched (iso-) Paraffins BTX aromatics 0.9 Resolved unknowns 56.5 A. BZIn Ce B. TOUn C7 I. Isoheptane Value F. nG7/MGH U. CH/MCP R. n C~l2MH S. nCs/22DMB H. Heptane Value MCH/n C7 mpXYUnCB 5.97 PZ P3 5N~ Nz 6N~ 100.00 K~ KZ 5N~/6N~ P3/Nz In(24DMPl23DMP) (Thompson, K.F.M.,1983.GCA:V.47, p.303.1Mango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG Bu1L: V.79, p.801. °Marzi,1993,OrgG;2Q,1301. Company: CONOCOPHILLIPS Client ID: US138732 V11e11 Name: NOATAK-1 Project #: 07-247-A Depth: 8301 - FT Lab ID: CP282500 Sampling Point: File Name: G6070413.D IC4 Iso-akane C4 NC4 Normal Alkane C4 IC5 Iso-a{kane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.663 339 119 NC8 Normal Alkane C8 15.295 3642 1371 IP9 Isoprenoid C9 17.172 767 267 MXYL m-Xylene 18.379 16536 6128 PXYL p-Xylene 18.444 5189 1917 OXYL o-Xylene 19.429 4343 1572 NC9 Normal Alkane C9 21.034 30772 11301 IP10 Isoprenoid C10 23.016 5487 1609 NC10 Normal Alkane C10 26.625 56548 19887 IP11 Isoprenoid C11 27.920 8109 2755 NC11 Normal Alkane C11 31.876 68929 23020 NC12 Normal Alkane C12 36.789 6847:1 22938 IP13 Isoprenoid C13 37.525 14264 3760 IP14 Isoprenoid C14 40.281 10316. 3312 NC13 Normal Alkane C13 41.391 74565 24095 IP15 Isoprenoid C15 44:830 15928 4776 NC14 Normal Alkane C14 45.718 71491 22264 IP16 Isoprenoid C16 48.369 27040 6448 NC15 Normal Alkane C15 49.795 70146 19921 Company: CONOCOPHILLIPS Client ID: US138732 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8301 - FT Lab ID: CP282500 Sam ling Point: File Name: G6070413.D NC16 Normal Alkane C16 53.650 59704 18456 IP18 Isoprenoid C18 55.582 19719 4253 NC17 Normal Alkane C17 57.302 56210 16686 IP19 Isoprenoid C19 (Pristane) 57.651 24915 4756 PHEN Phenanthrene 58.702 3405 822 NC18 Normal Alkane C18 60.774 48478. 14412 IP20 Isoprenoid C20 (Phytane) 61.225 11176 2036 NC19 Normal Alkane C19 64.081 45326 13047 NC20 Normal Alkane C20 67.233 41470 11788 NC21 Normal Alkane C21 70:248 36152 10469. C25H61 Highly Branch Isoprenoid C25 70.497 1573 377 NC22 Normal Alkane C22 73.130 33265 9422 NC23 Normal Alkane C23 75.894 30138 8719 NC24 Normal Alkane C24 78.547 26079 7371 NC25 Normal Alkane C25 81.097 23788 6534 NC26 Normal Aikane C26 83.549 19728 5428 NC27 Normal Alkane C27 85.912 16622 4478 NC28 Normal Alkane C28 88.192 12679 3409 NC29 Normal Alkane C29 90.399 11856 3029 NC30 Normal Alkane C30 92.532 8103 2046 NC31 Normal Alkane C31 94.593 6536 1665 NC32 Normal Alkane C32 96.592 4602. 1142 NC33 Normal Alkane C33 98.534 5239 1077 NC34 Normal Alkane C34 100.412 3505 749 NC35 Normal Alkane C35 102.249 2602 595 NC36 Normal Alkane C36 104.208 1929 368 NC37 Normal Alkane C37 106.399 1635 276 NC38 Normal Alkane C38 108.896 1440 217 NC39 Normal Alkane C39 111.751 1147 143 NC40 Normal Alkane C40 115.051 1060 106 NC41 Normal Alkane C41 118.928 1026 88 C • • BASELINE RESOLUTION. INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138733 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282501 Lease: Sample Type: SWC ROTARY combined Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8304 FT Longitude: Bottom Depth: FT Whole Oil GC Trace G6070415.D U U Z Z U Z U U y 2 U U Z Z U Z U U Z Z U z U Z U z U z U ~ Z U Z N z H ~ U Z N U Z N ~ ~ N m X °~ .F7 Z U Z (J N Z U N z m a .n ~ ~ Z z z z u~~ O1 0 .+ Z U U 2 ~' I 1 ~_ Z Z Z Z ~ `~ d UU O ~ H Pristane/Phytane 2.24 A. BZ/n CB Pristane/n C» 0.44 B. TOUn C~ 8.8 PhytanelnC~e 0.23 C: (nCe+nC,)/(CH+MCH) 1.1 nC~~/nC19 1.06 I. Isoheptane Value nC~~lnC29 4.33 F. nC~/MCH 1.1 CPI Marzi4 1.05 U. CH/MCP Normal Paraffins 38.6 R: nC~l2MH Isoprenoids 5.5 S. n C6/22DMB Cycloparaffins 0:0 H. Heptane Value 53.5 Branched (iso-) Paraffins MCH/nC~ O.E BTX aromatics 0.7 mpXYlJn C8 5.4 Resolved unknowns 54.9 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPGBoll.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. :ompany: CONOCOPHILLIPS Client ID: US138733 Vell Name: NOATAK-1 Project #: 07-247-A )epth: 8304 - FT Lab ID: CP282501 ~amplin Point: File Name: G6070415.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TM6 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 10.118 76 21 ISTD Internal Standard MCH Methylcyclohexane 10.966 66 26 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene 12.681 675 236 NCS Normal Alkane C8 15.313 5720 2200' IP9 Isoprenoid C9 17.189 1059 392 MXYL m-Xylene 18.394 23905...: 8905. PXYL p-Xylene 18.459 7455 2794 OXYL o-Xylene - 19.443 6087 2247 NC9 Normal Alkane C9 21.050 43043 15982 1P10 Isoprenoid C10 23:028 7250' 2194 NC10 Normal Alkane C10 26.640 76936 26742 IP11 Isoprenoid C11 27.932 10922 3741 NC11 Normal Alkane C11 31.892 96558 31926 NC12 Normal Alkane C12 36.808 106876` 34780 IP13 Isoprenoid C13 37.539 21579 5840 IP14 Isoprenoid C14 40.295 16917 5462 NC13 Normal Alkane C13 41.412 127840 39919 ' IP15 Isoprenoid C15 44.843 28376 8637 NC14 Normal Alkane C14 45.740 131243 40206 IP16 Isoprenoid: C16 48:384 50591 12245 NC15 Normal Alkane C15 49.817 134191 37412 • • Company: CONOCOPHILLIPS Client ID: US138733 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8304 - FT Lab ID: CP282501 Sampling Point: File Name: G6070415.D NC16 Normal Alkane C16 IP18 Isoprenoid C48 NC17 Normal Alkane C17 IP19 Isoprenoid C19 (Pristane) PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C21 C25H61 Highly Branch Isoprenoid C25 NC22 NormaLAlkane C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane. C26 NC27 Normal Alkane C27 NC28 Normal Alkane C28 NC29 Normal Alkane C29 NC30 Normal Alkane C30 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 Normal Alkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkane C38 NC39 Normal Alkane C39 NC40 Normal Alkane C40 NC41 Normal Alkane C41 53.671 115640 34338 55.595 38348 .8352' 57.323 109479 31864 57.675 48375 9461 58.712 6131 1471 60:792 95371 28419 61.240 21587 3886 64.100 89788. 25666 67.252 81645 23497 70.266 72414 20731 70.515 3177 719 73:149 66546 18797 75.911 61044 16780 7$.562 53263 14540 81.111 48879 13378 83.564 40798. 1.1106 85.925 34804 9749 88.207 26593 7234 90.412 25258 6585 92:542 17487 4437 94.602 14114 3583 96:599 9910 2494 98.539 11630 2379 100.419 7261 1580 102.254 5897 1321 104:214 4771 838 106.404 3491 592 108.890 2767 421 111.767 2270 297 .115.080. 2365 222 118.931 1595 143 •i BASELINE RESOLUTION, INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138733 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282501 Lease: Sample Type: SWC ROTARY replicate of combined Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8304 FT Longitude: Bottom Depth: FT G8070418.D U U 2 Z ~ C PristanelPhytane 2.23 A. BZ/n CB Pristane/n C17 0.44 B. TOUn C7 7.57 Phytane/nC1B 0:23 C. (nCe+nc,}/(CH+MCH} p.74 nC18/nC19 1.06 I. Isoheptane Value nC~~InC29 4.34 F. n'C7/MCH 0.74 CPI Marzi4 1.05 U. CH/MCP Normal Paraffins 38.6 R. nC~I2MH Isoprenoids 5.5 S. nC~/22DM6 ~• Cycloparaffins 0.0 H. Heptane Value 42.48 Branched (iso-) Paraffins MCH/n C7 1.35 BTX aromatics 0.7 mpXYUnCe 5.21 Resolved unknowns 54.9 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPG Biill.: V.79, p.801. °Marzi,1993,OrgG;2Q1301 Company: CONOCOPHILLIPS Client ID: US138733 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8304 - FT Lab ID: CP282501 Sampling Point: File Name: G6070416.D IC4 fso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP10 Isoprenoid C10 NC10 Normal Alkane C10 IP11 Isoprenoid C11 NC11 Normal Alkane C11 NC12 Normal Alkane C12 IP13 Isoprenoid C13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 IP15 Isoprenoid C15 NC14 Normal Alkane C14 IP16 Isoprenoid C16 NC15 Normal Alkane C15 10.123 96 20 10.967 130 40 12.689 727 239 15..322 6122 2255 17.198 1192 410 18.404 24325 9058 18.468 7601 2841 19.452 6222 2280 ? 21.059 43767 16041 23.039' 7388.. 2229 26.651 78290 27308 27.943 11089 3771 31.904 98465 32215 36.820 108188- .35491 37.552 22003 5916 40 306 17148 5538 . 41.424 129856 40396 44.856 28821 8807. 45.755 133378 40414 48.396 51447 12314 49.830 136607 38448 • • Company: CONOCOPHILLIPS Client ID: US138733 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8304 - FT Lab ID: CP282501 Samplin Point: File Name: G6070416.D NC16 Normal Alkane C16 53.685 118810 34538 IP18 .Isoprenoid C18 55.608 39214 8500 NC17 Normal Alkane C17 57.335 113222 33526 fP19 Isoprenoid C19 (Pristane) 57.684 .49555 9612 PHEN Phenanthrene 58.723 6326 1538 NC18 Normal Alkane C18 60.806 97769 28612 IP20 Isoprenoid C20 (Phytane) 61.253 22183 4044 NC19 Normal Alkane C19 64,112 92240 26012 NC20 Normal Alkane C20 67.264 84160 23747 NC21 Normal Alkane C21 70.276 74452 21599 C25HB1 Highly Branch Isoprenoid C25 70.523 3070 745 NC22 Normal Alkane C22 73:182 68726 19779 NC23 Normal Alkane C23 75.922 63170 17904 NC24 Normal Alkane C24 78.572 55026 15478 NC25 Normal Alkane C25 81.125 50583 13895 NC26 Normal Alkane C26 83.574 42241 11231 NC27 Normal Alkane C27 85.938 36050 9726 NC28 Normal Alkane C28 88.218 27484 7352 NC29 Normal Alkane C29 90.426 26082 6598 NC30 Normal Alkane C30 92.552 17967 4697 NC31 Normal Alkane C31 94.615 14515 3588 NC32 Normal Alkane C32 96.610 10244 2613 NC33 Normal Alkane C33 98.552 12464 2385 NC34 Normal Alkane C34 100,431 .7801 1694 NC35 Normal Alkane C35 102.268 6536 1385 NC36 Normal Alkane C36 104:232 4791 857 NC37 Normal Alkane C37 106.423 3672 634 NC38 Normal Alkane C38 108.916 2901 429 NC39 Normal Alkane C39 111.787 2405 304 NC40 Normal Alkane C40 115.091 2212 223 NC41 Normal Alkane C41 118.971 1709 144 • .7 • BASELINE ICES©LUTI©N, INC_ WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138734 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282502 Lease: .Sample Type: SWC ROTARY -soak Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8306 FT Longitude: Bottom De the FT Whole Oil GC Trace ~so~o3as.D U Z U Z U Z U V Z Z U z U 2 U z U z 2 U Z N U Z M U 2 v U 2 N z U Z U Z U Z U U Z 2 U m n z ~. ~, Z U U ~n ~ ~ m Z Z Z Z U ~ ~ .i W Z Z z U U V w Z Z Z N,a ~ o ~ U ,y 2 MS.O Z w Pristane/Phytane 2.23 A: BZ/nCe P~ Pristane/n C~~ 0.45 B. TOL/n C7 PZ Phytane/nC18 0.23 C: (nCe+nC,)/{CH+MCH) Pg nC~~/nC19 1.05 I. Isoheptane Value 5N~ nC»/nC29 4.05 F. nC7/MCH NZ CPI Marzi4 1.05 U. CH/MCP 6N~ Normal Paraffins 40.1 R. nC~/2MH Kl Isoprenoids 5.8 S. nC~/22DMB KZ cloparaffins H: Heptahe Value 5N~/6N~ anched (iso-) Paraffins MCH/n C7 P~/NZ Xaromatics 0.0 mpXYUnCe 2:40 In(24DMP/23DMP) :solved unknowns 53.9 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPGBulL: V.79, p.801. QMarzi,1993,OrgG;20,1301. company: CONOCOPHILLIPS Client ID: US138734 JVell Name: NOATAK-1 Project #: 07-247-A depth: 8306 - FT Lab ID: CP282502 3amplin Point: File Name: G6070349.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 . IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 15.320 213 49 IP9 Isoprenoid C9 17.186 109 18 MXYL m-Xylene 18.414 .397... 130 PXYL p-Xylene 18.482 114 40 OXYL o-Xylene 19.453 168 51 NC9 Normal Alkane C9 21.060 1310 472 IP10 Isoprenoid C10 23.045 472 129 NC10 Normal Alkane C10 26.647 10842 3818 IP11 Isoprenoid C11 27.949 2014 692 NC11 Normal Alkane C11 31.901 33981 11355 NC12 Normal Alkane C12 36.817 50872 16904 IP13 Isoprenoid C13 37.558 10748 2773 IP14 .Isoprenoid C14 40.311 8430 2718 NC13 Normal Alkane C13 41.420 62456 20036 IP15 Isoprenoid C15 44.859 14032. 4337 NC14 Normal Alkane C14 45.747 62397 19324 IP16 Isoprenoid C16 48.398 24097 5720 NC15 Normal Alkane C15 49.822 62758 18082 • ~_J Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: G6070349.D NC16 Normal Alkane C16 IP18 Isoprenoid C18 NC17 Normal Alkane C17 IP19 Isoprenoid C19 (Pristane) PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C21 C25HB1 Highly Branch Isoprenoid C25 NC22 Normal Alkane C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane C26 NC27 Normal Alkane C27 NC28 Normal Alkane C28 NC29 Normal Alkane C29 NC30 Normal Alkane: C30 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 Normal Alkane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkane C38 NC39 Normal Alkane C39 NC40 Normal Alkahe C40 NC41 Normal Alkane C41 53.678 54326 16530 55.61.4 18078 3934 57.333 52214 15748 57.686 23316 4442 58.725 3099 760 60.804 45735' 13639 61.252 10478 1901 64.1D9 43536. 12796 67.262 39782 11279 70:276 .35484 10332 70.526 1544 356 73.159 33369 9433 75.922 30596 8464 78.576 26953 7519 81.125 24706 6825 83.580 20832 554? 85.944 17859 4781 88.226 13695 3604 90.431 12899 3183 92.564 9298. 2293 94.629 7243 1808 96.624 5114. 1290 98.564 6134 1246 100.445 3674. 822 102.284 3086 634 104.238 2134 400 106.443 1618 279 108.935 1166 176 111.803 917 118 115.103 992 86 118.994 605 53 BASELINE RESOLUTI®N, INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138734 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282502 Lease: Sample Type: SWC ROTARY soxhlet Block: Sampling- Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8306 FT Lon itude: Bottom Depth: FT G6070348.D • U Z i'~istane/Phytane 2.26 Pristane/n C17 0.43 Phytane/n C18 0.22 n C~~/n C19 1.07 n C~yln C29 5.72 CPI Marzi4 1.05 Normal Paraffins 36.9 Isoprenoids 5.5 Cycloparaffins Branched (iso-) Paraffins BTX aromatics 0.5 Resolved unknowns 56.9 A. BZ/n CB B. TOL/nC~ C. (n CB+n Cr)/(CH+MCH) I. Isoheptane Value F. n Cl/MCH U. CH/MCP R. n Cy/2MH S. nCs/22DMB H. Heptane Value MCH/n C~ mpXYUn CB 1 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. sHalpern,H.L,1995,AAPG Bull.: V.79, p.801. 4Marzi,1993,OrgG;20,1301. :.ompany: CONOCOPHILLIPS Client ID: US138734 Nell Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sam ling Point: File Name: G6070348.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DM6 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 15.356 1228 468 IP9 Isoprenoid C9 17.232 444 146 MXYL m-Xylene 18.434 9507 3541 PXYL p-Xylene 18.500 2870 1075 OXYL o-Xylene 19.484 3308 1217 NC9 Normal Alkane C9 21.088 28691 10565 IP10 Isoprenoid C10 23.069 5779. 1688 NC10 Normal Alkane C10 26.678 71268 25261 IP11 Isoprenoid C11 27.971 10434 3577 NC11 Normal Alkane C11 31.930 93597 31068 NC12 Normal Alkane C12 36.840 87021 28729 IP13 Isoprenoid C13 37.576 17278 4627 1P14 Isoprenoid C14 40.329 11926 3860 NC13 Normal Alkane C13 41.440 85362 26962 IP15 Isoprenoid C15 44.:875 17305 5296 NC14 Normal Alkane C14 45.764 76392 23830 IP16 Isoprenoid C16 48.413 27944 6648 NC15 Normal Alkane C15 49.839 72748 21116 • Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: G6070348.D NC16 Normal Alkane C16 53.691 61040 18277 IP18 Isoprenoid C18 55.626 19588 4279 NC17 Normal Alkane C17 57.342 56481 16851 IP49 Isoprenoid C19 (Pristane) 57.692 .24167 4664 PHEN Phenanthrene 58.737 3292 795 NC18 Normal Alkane C18 60.814 47972 14051 IP20 Isoprenoid C20 (Phytane) 61.268 10673 1892 NC19 Normal Alkane C19 64.117 44776 12918 NC20 Normal Alkane C20 67.269 39605 11206 NC21 NormaFAlkane C21 70.282 34718 10021 C25HB1 Highly Branch Isoprenoid C25 70.538 1566 324 NC22 Normal Alkane C22 73.166 31110 9047 NC23 Normal Alkane C23 75.930 27926 7915 NC24 Normal Alkane C24 78.581 23890 6591 NC25 Normal Alkane C25 81.131 21451 5686 NC26 Normal Alkane C26 83.585 17465 4675 NC27 Normal Alkane C27 85.950 14460 3921 NC28 Normal Alkane C28 88.233 10852 2765 NC29 Normal Alkane C29 90.439 9873 2451 NC30 Normal Alkane C30 92:571 6791 1668 NC31 Normal Alkane C31 94.631 5439 1327 NC32 Normal Alkane C32 96.631 3835 904 NC33 Normal Alkane C33 98.573 4266 871 NC34 Normal Alkane C34 100.451 2654 610 NC35 Normal Alkane C35 102.289 2502 529 NC36 Normal Alkane C36 104,252 2282 355 NC37 Normal Alkane C37 106.447 1675 262 NC38 Normal Alkane C38 108.946 1255 189 NC39 Normal Alkane C39 111.810 1403 170 NC40 Normal Alkane C40 115.133 1403 132 NC41 Normal Alkane C41 119.007 1186 103 • ,• BASELINE RES©LUTI©N, INC. WHOLE OIL GC _ _• Company: CONOCOPHILLIPS Client ID: US138820 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282588 Lease: Sample Type: DRILLING MUD Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: Latitude: Top Depth: Longitude: Bottom Depth: G8070388.D C Pristane/Phytane 0.40 Pristane/n Ct7 0.13 Phytane/n C18 0.72 nC~~/nC19 1.24 n C~~/n C29 12.78 CPI Marzi4 0.46 Normal Paraffins 5.2 s,• Isoprenoids Cycloparaffins 0.6 Branched (iso-) Paraffins BTX aromatics Resolved unknowns 94.1 A. BZ/n GB B. TOUn C7 C. (nCe+nC~)1(CH+MCH) I. Isoheptane Value F. nC~/MCH U. CH/MCP R. nC~/2MH S. nCs/22DMB H. Heptane Value 100:00 MCH/n C~ mpXYUn Ce 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPGBull.s V.79, p.801. °Mazzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US138820 Well Name: NOATAK-1 Project #: 07-247-A Depth: - Lab ID: CP282588 Sam ling Point: File Name: G6070388.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 _ NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane CP Cyclopentane 23DM6 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 6.546 4826 2864 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane ' 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 10.113 5171 2359 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 15.319 7882 2977 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 21.050 6423 2372 IP10 Isoprenoid C10 ~ 23.000 694 141 NC10 Normal Alkane C10 26.632 7198 2512 IP11 Isoprenoid C11 27.954 734 221 NC11 Normal Alkane C11 31.879 7388 2400 NC12 Normal Alkane C12 36.790 7683 2320 IP13 Isoprenoid C13 37.525 4008 1279 IP14 Isoprenoid C14 40.282 503 103 NC13 Normal Alkane C13 41.387 8019 t 2365 IP15 Isoprenoid C15 44:839 1006. 266" NC14 Normal Alkane C14 45.716 19479 5412 IP16 Isoprenoid C16 48.365 3544 924 NC15 Normal Alkane C15 49.798 6768 3314 ~J Company: CONOCOPHILLIPS Client ID: US138820 Well Name: NOATAK-1 Project #: 07-247-A Depth: - Lab ID: CP282588 Sampling Point: File Name: G6070388.D NC16 Normal Alkane C16 53.683 27122 5728 1P18 Isoprenoid C18 55.588 3126 619 NC17 Normal Alkane C17 57.351 29353 6680 IP19 Isoprenoid C19 (Pristane) 57.656 3705 8~5 PHEN Phenanthrene 58.746 6815 1413 NC18 Normal Alkane C18 60.800 50129 8438 IP20 Isoprenoid C20 (Phytane) 61.264 35991 6163 NC19 Normal Alkane C19 64.110 40556 6517 NC20 Normal Alkane C20 67.234 16510 3804 NC21 Normal`Alkane C21 70'260 8048 2465 C25H61 Highly Branch Isoprenoid C25 NC22 Normal Alkane C22 73.150 75260 18291 NC23 Normal Alkane C23 75.937 5419 1816 NC24 Normal Alkane C24 78.578 18858 2885 NC25 Normal Alkane C25 81.112 4923 894 NC26 NormaLAlkane C26 83.553 3274 669 NC27 Normal Alkane C27 85.916 2136 453 NC28 Normal Alkane. C28 88.194 1598; 391 NC29 Normal Alkane C29 90.399 2297 500 NC30 Normal Alkane C30 92.572 7:1257 13997: NC31 Normal Alkane C31 94.603 2076 393 NC32 Normal Alkane C32 96.594. 1318 290 NC33 Normal Alkane C33 98.547 2580 453 NC34 Normal Alkane C34 100.426 1049: 240 NC35 Normal Alkane C35 102.265 1515 286 NC36 .Normal Alkane G36 104.284 2349 398 NC37 Normal Alkane C37 106.407 739 125 NC38 Normal Alkane C38 108'.890 1747 233: NC39 Normal Alkane C39 111.763 614 82 NC40 Normal Alkane C40 115.146 1134 t51 NC41 Normal Alkane C41 118.924 588 69 j`. • BASELINE RESQLUTI©N, INC.. WHOLE OIL GC s Company: CONOCOPHILLIPS Client ID: US138822 Country: UNITED STATES Project #: 07-247-A Basin: NDRTH SLOPE Lab ID: CP282590 Lease: Sample Type: SOLTEX Block: Sampling Point; Field: - Formation: Well Name: NOATAK-1 Geologic Age: - Latitude: Top Depth: Lon itude: Bottom Depth: G6070389.D C. PristanelPhytane A. BZ/nC® Pristane/nC~~ B. TOUnC7 Phytane/nC1e C. (nCe+nC,)I(CH+MCH) n C~~/n C19 2.07 I. Isoheptane Value nC~~/nC29 F. nC~IMCH CPI Marzi4 U. CH/MCP Normal Paraffins 0.1 R, n C7/2MH- Isoprenoids S. nC~/22DMB Cycloparaffins H. Heptane Value Branched (iso-) Paraffins MCH/n C7 BTX aromatics mpXYUn C8 Resolved unknowns 99.9 1Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPG Bu11.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. Company: CONOCOPHILLIPS ~ Client ID: US138822 Well Name: NOATAK-1 Project #: 07-247-A Depth: - Lab ID: CP282590 Samplin Point: File Name: G6070389.D IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DM6 2,2-Dimethylbutane CP Cyclopen#ane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP1Q Isoprenoid C10 NC10 Normal Alkane C10 IP11 Isoprenoid C11 NC11 Normal Alkane C11 NC12 Normal Alkane C12 IP13 Isoprenoid C13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 IP15 Isoprenoid C15 NC14 Normal Alkane C14 IP16 Isoprenoid C16 NC15 Normal Alkane C15 36.859 250 67 41.385 149 28 45.713 395 106 49.787 445 98 Company: CONOCOPHILLIPS Client ID: US138822 Well Name: NOATAK-1 Project #: 07-247-A ~ Depth: - Lab ID: CP282590 Samplin Point: File Name: G6070389.D n C • BASELINE RESOLUTI©N INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US138822 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282590 Lease: Sample Type: SOLTEX drilling mud additive Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: Latitude: Top Depth: Longitude: Bottom Depth: Pristane/Phytane A: BZ/n CB P~ Pristane/n C17 B. TOUn C~ PZ Phytane/n C18 C. (n C,+n Cy)I(CH+MCH} P3 n C~a/n C19 2.07 I. Isoheptane Value 5N~ n Cl~ln C2e F n C~/MCH NZ CPI Marzi4 U. CH/MCP 6N~ Normaf Paraffins 0.1 R: n C~/2MH Ki Isoprenoids S. n CB/22DM6 KZ Cycloparaffins H. Heptane Value 5N1/6N{ Branched (iso-) Paraffins MCHIn C~ P3/NZ BTX aromatics mpXYUn Ce In(24DMP/23DMP) Resolved unknowns 99.9 Thompson, K.F.M.,1983.GCA:V.47, p.303. ZMango, F.D.,1994.GCA: V.58, p.895. 3Halpern,H.L,1995,AAPG Bull.: V.79, p.801. °Mazzi,1993,OrgG;20,1301. Company: Well Name: Depth: Sampling Point: CONOCOPHILLIPS NOATAK-1 IC4 Iso-alkane C4 NC4 Normal Alkane C4 IC5 Iso-alkane C5 NC5 Normal Alkane C5 22DMB 2,2-Dimethylbutane CP Cyclopentane 23DMB 2,3-Dimethylbutane 2MP 2-Methylpentane 3MP 3-Methylpentane NC6 Normal Alkane C6 22DMP 2,2-Dimethylpentane MCP Methylcyclopentane 24DMP 2,4-Dimethylpentane 223TMB 2,2,3-Trimethylbutane BZ Benzene 33DMP 3,3-Dimethylpentane CH Cyclohexane 2MH 2-Methylhexane 23DMP 2,3-Dimethylpentane 11DMCP 1,1-Dimethylcyclopentane 3MH 3-Methylhexane 1C3DMCP 1-cis-3-Dimethylcyclopentane 1T3DMCP 1-trans-3-Dimethylcyclopentane 3EP 3-Ethylpentane 1T2DMCP 1-trans-2-Dimethylcyclopentane NC7 Normal Alkane C7 ISTD Internal Standard MCH Methylcyclohexane 113TMCP 1,1,3,-Trimethylcyclopentane ECP Ethylcyclopentane 124TMCP 1,2,4-Trimethylcyclopentane 123TMCP 1,2,3-Trimethylcyclopentane TOL Toluene NC8 Normal Alkane C8 IP9 Isoprenoid C9 MXYL m-Xylene PXYL p-Xylene OXYL o-Xylene NC9 Normal Alkane C9 IP10 Isoprenoid C10 NC10 Normal Alkane C10 IP11 Isoprenoid C11 NC11 Normal Alkane C11 NC12 .Normal Alkane C12 IP13 Isoprenoid C13 IP14 Isoprenoid C14 NC13 Normal Alkane C13 IP15 Isoprenoid C15 NC14 Normal Alkane C14 IP16 Isoprenoid C16 NC15 Normal Alkane C15 Client ID: US138822 Project #: 07-247-A Lab ID: CP282590 File Name: G6070389.D 36.859 250 67 41.385 149 28 45.713 395 106 49.787 445 98 i• Company: CONOCOPHILLIPS Client ID: US138822 Well Name: NOATAK-1 Project #: 07-247-A Depth: - Lab ID: CP282590 Samplin Point: File Name: G6070389.D C • BASELINE RES©LUTION, INC.. WHOLE OIL GCMS Company: CONOCOPHILLIPS Client ID: US138734 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282502 Lease: Sample Type: SWC ROTARY Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8306 FT Longitude: Bottom Depth: FT m/z 187: Methyldiamantanes M2071024.D Area Height Methy-adamantane Index 0.46 0.45 Methyidiamantane Index 0.27 0.27 Ethyladamantane Index 0.78 0.71 Dimethyldiamantane Index-1 D.58 0.59 Dimethyldiamantane Index-2 0.40 0.49 (4MDI + 3MDI) / C29R Diamondoids /Terpanes 5.29 3.68 from ion 149 Adamantanes / Diamantanes 9.35 90.42 ~ • ~• ~ Area Height Methyladamantanes ion 135 9.4 7.1 Adamantane ion 136 0.7 0.6' Dimethyladamantanes ion 149 5.4 4.1 Trimethyladamantanes ion 163 3;1 2.6 Tetramethyladamantanes ion 177 0.5 0.4 Methyidiamantanes ioh 187 1.1_ 0:6 Diamantane ion 188 0.3 0.3 Dimethyldiamantanes~ ion 201 0.6 0.4 Trimethyldiamantane ion 215 0.1 0.0 Total Adamantanes 19.1 14,.7 Total Diamantanes 2.0 1.4 Terpanes ion 149 1:0 1.1 (steranes & hopanes) Methyladamantane Index= 1MAM / (1MAM+2MAM) Methyldiamantane Index= 4MDI /-( 1 MDI+3MDI+4MDI) Ethyladamantane Index = 2EAM / (2EAM+1 EAM) Dimethyldiamantane Index-1 = 34DMDI /"(34DMDI+49DMDI), Dimethyldiamantane Index-2 = 48DMDI / (48DMDI+49DMDI) Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M2071024.D 217 CHOL 5(3 cholane (internal standard) 217 C29R C29 as 20R sterane from ion 217 135 1MAM 1-Methyladamantane 135 2MAM 2-Methyladamantane 135 1EAM 1-Ethyladamantane 135 2EAM 2-Ethyladamantane 136 AM Adamantane 149 13DMAM 1,3-Dimethyladamantane 149 C14DMAM 1,4-Dimethyladamantane, cis 149 T14DMAM 1,4-Dimethyladamantane, trans 149 12DMAM 1,2-Dimethyladamantane 149 1E3MAM 1-Ethyl-3-methyladamantane 149 CHOL_149 5(3 cholane from ion 149 149 27D C27 as 20S diasterane from ion 149 149 27R C27 as 20R sterane from ion 149 149 28R C28 as 20R sterane from ion 149 149 29R C29 as 20R sterane from ion 149 149 29H C29 ap norhopane from ion 149 149 30H C30 a(3 hopane from 149 149 31 S C31 22S ap hopane from 149 149 31 R C31 22R aR hopane from 149 149 32S C32 22S a(3 hopane from 149 149 32R C32 22R a(3 hopane from 149 149 33S C33 22S. as hopane from 149 149 33R C33 22R ap hopane from 149 149 34S C34 22S a(3 hopane from 149 149 34R C34 22R a(3 hopane from 149 149 35S C35 22S a(3 hopane from 149 149 35R C35 22R aR hopane from 149 163 135TMAM 1,3,5-Trimethyladamantane 163 136TMAM 1,3,6-Trimethyladamantane 163 C134TMAM 1,3,4-Trimethyladamantane, cis 163 T134TMAM 1,3,4-Trimethyladamantane, trans 163 1E35DMAM 1-Ethyl-3,5-dimethyladamantane 177 1357TMAM 1,3,5,7-Tetramethyladamantane 177. 1257TMAM 1,2,5,7=Tetramethyladamantane 187 4MDI 4-Methyldiamantane 187. 1 MDI 1-Methyldiamantane 187 3MDI 3-Methyldiamantane 188 DI Diamantane 201 49DM D I 4, 9-Dimethyld iamantane 201 1424DMDI 1,4 and 2,4-dimethyldiamantane 201 48DMDI 4,8-Dimethyldiamantane 201 34DMDI 3,4-Dmethyldiamantane 215 TMDI Trimethyldiamantane 50.090 9029 2790 25.0 25.0 10.033 1223 292 2.5 2.1 11.473 1427 351 2.9 2:5 13.242 1123 260 0.9 0.7 14.092 2793 431 3.1 1`.7 9.704 364 91 0.7 0.6 10.311 882 231 0.$ 0.7 11.716 1300 306 1.2 0.9 11.855 1312 310 1.2 09 12.566 1489 376 1.4 1.1 13.555 835 201 0.8 0:6 50.090 1842 586 25.0 25.0 52.833 75 26 1.0 1;1 10.519 279 80 0.3 0:2 11.994 699 180 0.6 0.5 12.739 1327 301 1.2 0.9 12.878 821 206 0.8 0.6 13.746 259 13L 0.2 0.4 10.675 60 16 0.1 0.0 12.948 433 108 0.4 0.3 23.269 230 42 0.3 0.2 24.657 348 60 0.4 02 25.542 284 56 0.3 0.2 22.818 222 tit 0:3 0.3 23.703 147 26 0.2 0.1 24.726 72 18 0.1 0.1 24.917 100 25 0.1 0.1 25.906 206. 37 0:3 01 24.952 55 12 0.1 0.0 • • • Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M2071024.D m/z 191 ~~ Baseline Resolution, Inc., 143 Vision Park Blvd., Shenandoah, Texas 77384 Phone: 281-681-2200 Fax: 281-681-0326 Email: info@brilabs.com Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M2071024.D Im/z 178 + 192 Im/z 198 342 • Baseline Resolution, Inc., 143 Vision Park Blvd., Shenandoah, Texas 77384 Phone: 281-681-2200 Fax: 281-681-0326 Email: info@brilabs.com • • • et N d' ~ ai L~ O 00 1~ N ~ M ~ 00 I~ V)NdN ~ O V d w = d ~ Z ~ ~Q ~ d L U a ~ v/ a J J_ 2 a~ ~a`~` o~ zao UZaMo w c 'O ~; a ~, ~ _ ~ c ~. z = ' c°~~cv~ HCZ~ sLZYIQ 'IOHO ti N E E 0 U N Q f0 a~ V O c .~ W N M O a0 N X m 0 0 N N 00 N N C O t d W M n N f6 X N H ~: C7 • Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M2071024.D 'm/z 217 !m/z 218 m/z 231 Baseline Resolution, Inc., 143 Vision Park Blvd., Shenandoah, Texas 77384 Phone: 281-681-2200 Fax: 281-681-0326 Email: info@brilabs.com C7 C7 • Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M2071024.D i~ ~ III,, ~ ~~~1!,I ... f_ II,I ~I lip ~ r' ,o, m~,~~~,~,~°~~ti~, I. III III ~- ---- ~~ ~rv~~;~^'~u,~i ,_.vJ.. ~,„~,~,n'~~~ ,.~,~ Baseline Resolution, Inc., 143 Vision Park Blvd., Shenandoah, Texas 77384 Phone: 281-681-2200 Fax: 281-681-0326 Email: info@brilabs.com BASELINE RE5©LUTIC7N, tNA. SATURATE GCMS Company: CONOCOPHILLIPS Client ID: US138734 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282502 Lease: Sample Type: SWC ROTARY Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8306 FT Lon itude: Bottom De the FT DS (nn Areas' Anr, M2071032.D %Czs apps (218) 43.8 ` D %C28 apps (218) 28.4 D %C2e apps (218) 27.8 D %C27 aaaR (217) 47.8 D %C28 aaaR (217) 28.3 D %C29 aaaR (217) 23.8 D S/(S+R) (CZB aaa) (217) 0.65 M 0.55 (0.8%) ppS/(ppS+aaR) (C29) (217) 0.56 M 0.70 (0.9%) (Czs+Czz)/(Czs+Cze+Czs) (217) 0.17 C27/Czs (apps) (218) 1.58 D Cze/Czs (apps) (218) 1.02 D Diaster/aaa Ster (Czs) (217) 3.80 M/D 1.00 (1.4%) C30 Sterane Index (218) 5.97 . D Oleanahe/Hopane D/A Gammacerane/Hopane D Nofiopahe/Hopane 0,71 D Bisnorhopane/Hopane 0.76 Diahopane/Hopane $.42 M/D Moretane/Hopane M 0.05 (0.7%) 25-nor-hopane/hopane B Ts/(Ts+Tm) trisnorhopanes 0.89 M/D 1.00 (1.4%) C29Ts/C29 Hopane 137 M H32 S/(R+S) Homohopanes 0.64 M 0.60 (0.6%) H35/H34 Homohopanes D C24 Tetracyclic/Hopane 0.33 D C24 Tetracyciic/C26 Tricyclics 0.47 D C23/C24 Tricyclic terpanes 1.09 D C19/C23`Tricyclicterpanes 1.43 D C26/C25 Tricyclic terpanes 1.01 D (C28+C28 Tricyclics Rs 0.67 A SteraneslHopanes 0.52 D Tricyclic terpanes/Hopanes 0.76 M 1.00 (1.4%) Tricyclic terpanes/Steranes 1;47 M!D 1.00(1.4°h) 'Definition and utility of the ratios can be found on our website www.BaselineDGSl.com t`,~ zA=Source Age; D=Depositional environment; M= Maturity; 6=Possible Biodegradation 3Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M2071032.D 217 CHOL 5Q cholane (internal standard) 125 H30_125 C3017a(H)-hopane (125) 125 GCAR y-carotane 125 GCAR p-carotane 177 L24BNR1 24,28-bisnorlupane isomer 177 LA24BNR 17a(H)24,28-bisnorlupane 177 LB246NR 17(3(H)24,28-bisnorlupane 177 L246NR2 24,28-bisnorlupane isomer 177 L24NOR 24-norlupane 191 TR19 C19 tricyclic terpane 191 TR20 C20 tricyclic terpane 191 TR21 C21 tricyclic terpane 191 TR22 C22 tricyclic terpane 191 TR23 C23 tricyclic terpane 191 TR24 C24 tricyclic terpane 191 C24DEOL C24 des-A-oleanane 191 C24DELUP C24 des-A-lupane 191 TR25A C25 tricyclic terpane (a) 191 TR256 C25 tricyclic terpane (b) 191 C24DEURS C24 des-A-ursane 191 C24DEHOP C24 des-E-hopane 191 TET24 C24 tetracyclic terpane (TET) 191 TR26A C26 tricyclic terpane (a) 191 TR26B C26 tricyclic terpane (b) 191 TR28A C28 tricyclic terpane (a) 191 TR28B C28 tricyclic terpane (b) 191 TR29A C29 tricyclic terpane (a) 191 TR29B C29 tricyclic terpane (b) 191 TS Ts 18a(H)-trisnorhopane 191 TM Tm 17a(H)-trisnorhopane 191 TR30A C30 tricyclic terpane (a) 191 TR30B C30 tricyclic terpane (b) 191 H28 C2817a18a21(3(H)-brsnorhopane 191 NOR25H C29 Nor-25-hopane 191 H29 C29 Tm 17a(H)21(3(H)-norhopane 181 C29TS C29 Ts 18a(H)-norneohopane 191 DH30 C3017a(H)-diahopane 191 M29 C29 normoretane 191 OL oleanane 191 H30 C30 17a(H)-hopane 191 M30 C30 moretane 191 TARAX Taraxerane 191 H31 S C31 22S 17a(H) hopane 191 H31R C3122R 17a(H)hopane 191 GAM gammacerane 62.300 13044 3287 100.0 100.0 76.579 2478 361 19.0 11.0 88.149 837 89 6.4 2.7 44.546 470 96 3.6 2:9 47.622 771 132 5.9 4.0 50.676 187 45 1.4 1.4 53.449 39 18 0.3 0.5 56.407 329 69 2.5 2.1 57.967 303 78 2.3 2.4 61.043 95 23 0.7 0.7 61.152 199 36 1.5 1.1 • 63.015 139 33 1.1 1:0 63.297 112 26 0.9 0.8 • 63.448 185 44 1.4 1.3 68.150 170 39 1.3 1.2 68.475 185 39 1.4 1.2 69.494 341 68 2.6 2.1 69.905 186 40 1.4 1.2 70.880 1313 315 10.1 9.6 71.747 160 24 1.2 0.7 72.094 143 44 1.1 1.3 72.505 182 39 1,4 1.2 73.827 319 55 2.4 1.7 74.737 299 49 2.3 1.5 74.887 41 T 98 3.2 3.0 75.214 1435 323 11.0 9.8 76.535 420 86 3.2 2.6 78.594 344 56 2.6 1.7 78.854 161 35 1.2 1'.1 Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sam lin Point: File Name: M2071032.D 191 H32S C32 22S 17a(H)hopane 191 H32R C32 22R 17a(H)hopane 191 H33S C33 22S 17a(H) hopane 191 H33R C33 22R 17a(H)hopane 191 H34S C34 22S 17a(H)hopane 191 H34R C34 22R 17a(Hj hopane 191 H35S C35 22S 17a(H)hopane 191 H35R C35 22R 17a(H)hopane 217 S21 C21 sterane 217 DIA27S C27 pa 20S diasterane 217 C27R C27 as 20R sterane 217 C28R C28 as 20R sterane 217 C29S C29 as 20S sterane 217 C29BBR C29 pp 20R sterane(+5 paaj 217 C29BBS C29 pp 20S sterane 217 C29R C29 as 20R sterane. 218 C27ABBR C27 pp 20R sterane 218 C27ABBS C27 pp 20S sterane 218 C28ABBR C28 pp 20R sterane 218 C28ABBS C28 pp 20S sterane 218 C29ABBR C29 pp 20R sterane 218. C29ABBS C29 pp 20S sterane 218 C30ABBR C30 pp 20R sterane 218 C30ABBS C30 pp 20S sterane 259 D27S C27 pa 20S diasterane 259 D27R C27 pa 20R diasterane 259 D28SA C28 pa 20S diasterane a 259 D28S6 C28 pa 20S diasterane b 259 D28RA C28 pa 20R diasterane a 259 D28RB C28 pa 20R diasterane b 259 D29S C29 pa 20S diasterane 259 D29R C29 pa 20R diasterane 259 C30TP1 C30 tetracyclic polyprenoid 259 C30TP2 C30 tetracyclic polyprenoid 80.241 156 32 1.2 1.0 80.587 86 22 0.7 0.7 53.795 452 71 3.5 2.2 65.702 1213 277 9.3 8.4 70.339 319 55 2.4 1.7 72:765 189 24 1.4 0.7 73.307 296 42 2.3 1.3 73.805 272 50 2:1 1.5 73.892 203 32 1.6 1.0 74.715 159. 28 1.2 0.9 69.624 528 86 4.0 2.6 69.819 380 4T 2.9 1.4 71.899 194 33 1.5 1.0 72.115 246 49 1.9 1.5 73.784 246 46 1.9 1.4 73.914 241 39 1.8 1.2' 75.322 77 18 0.6 0.5 75.430 5fi 13 0.4 0:4 65.724 770 177 5.9 5.4 66.54.7 530 .109.. 4.1 3.3 67.782 389 89 3.0 2.7 67.934 478 95 3.7 2.9 68.714 475 82 3.6 2.5 68.757 218 66 1.7 2.0 69.645 727 127 5.6 3.9 70.599 605 88 4.8 2.7 •i Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M2071032.D • 135 1MAM 1-Methyladamantane 13.258 18 6 0.1 0.2 135 2MAM 2-Methyladamantane 15.138 55 23 0.4 0.7 135 1EAM 1-Ethyladamantane 17.019 155 58 1.2 1.8 135 2EAM 2-Ethyladamantane 17.854 1216 406 9.3 12.4 136 AM Adamantane 149 13DMAM 1,3-Dimethyladamantane 13.676 19 6 0.1 -0.2 - 149 C14DMAM 1,4-Dimethyladamantane, cis 15.431 88 28 0.7 0.9 149 T14DMAM 1,4-Dimethyladamantane, trans 15.577 83 36 0.6 1.1 149 12DMAM 1,2-Dimethyladamantane 16.329 165 73 1.3 2.2 149 1E3MAM 1-Ethyl-3-methyladamantane 17.332 318 100 2.4 3.0 163 135TMAM 1,3,5-Trimethyladamantane 13.989 14 5 0.1 0.2 163 136TMAM 1,3,6-Trimethyladamantane 15.765 60 25 0.5 0.8 163 C134TMAM 1,3,4-Trimethyladamantane, cis 16.517 145 60 1.1 1.8 163 T134TMAM 1,3,4-Trimethyladamantane, trans 16.643 193 73 1.5 2:2 163 1E35DMAM 1-Ethyl-3,5-dimethyladamantane 17.583 290 75 2.2 2.3 177 1357TMAM 1,3,5,7-Tetramethyladamantane 177 1257TMAM 1,2,5,7-Tetramethyladamantane 16.747 139 60 1.1 1.8 187 4MDI 4-Methyldiamantane 25.417 597 150 4.6 4.6 187 1MDI 1-Methyldiamantane 26.921 859 192 6.6 5.8 187 3MDI 3-Methyldiamantane 28.008 856 196 6.6 6.0' 188 DI Diamantane 24.978 579 166 4.4 5.1 201. 49DMD1 4,9-Dimethyldiamantane 25.856 167 45 1:3 1.4 201 1424DMDI 1,4 and 2,4-dimethyldiamantane 27.026 301 70 2.3 2.1 • 201 48DMDI 4,8-Dimethyldiamantane 27.235 422 87 3.2 2.6 201 34DMDI 3,4-Dimethyldiamantane 28.509 626 128 4.8 3.9 215 TMDI Trimethyldiamantane 27.297 191 41 1.5 1.2 • Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Samplin Point: F[le Name: M2071032.D Steroids %Czs aRRS (218) 43.8 %C28 aRRS (218) 28.4 %C29 aRRS (218) 27.8 Czs/Czs (aRRS) (218) 1,58 Cza/Czs (aRRS) (218) 1.02 Cze/Cz~ (aRRS) (218) 0.63 %Czs aaaR (217) 47.8 %C28 aaaR (217) 28.3 %C29 aaaR (217) 23.8 S/R (C29 aaa) (217) 1.86 S/(S+R) (CzB aaa) (217) 0.65 RR/(«a+RR) (Czs) (217) 0.51 aRRSlaaaR (Cz9) (217) 1.28 (Czs+Czz)/(Cz7+Cze+Cze) (217) 0.17 Diaster/aaa Ster (C27) (217) 3.80 Terpenoids C19/C23 Tricyclic terpanes 1.43 C23/C24 Tricyclic terpanes 1.09 C26/C25 Tricyclic terpanes 1.01 C24 TetracycliGC26 TricyGics 0.47 C24 TetracycliGHopane 0.33 Tsfl'm trisnorhopanes 8.21 Ts/(Ts+Tm) trisnorhopanes 0.89 C29Ts/C29 Hopane 1.37 Bisnorhopane/Hopane 0.76 Norhopane/Hopane 0.71 Diahopane/Hopane 3.42 Oleanane/Hopane Gammacerane/Hopane Moretane/(Moretane+Hopane) H32 S/(S+R) Homohopanes 0.64 H35/H34 Homohopanes [Steranes]/[Hopanes] 0.52 [Tricyclic terpanes]/[Hopanes] 0.76 [Tricyclic terpanes]/[Steranes] 1.47 DIAMONDOID Ratios Methyl Adamantane Index 0.25 Methyl Diamantane Index 0.26 34.8 36.3 28.9 1.21 1.26 0.83 51.4 22.4 26.2 1.50 0.60 0.54 0.14 5.04 1.39 0.88 1.19 0.47 0.38 13.13 0.93 2.00 0.64 0.57 3.76 0.59 0.46 0.76 1.65 0.21 4.28 ~~ BASELINE RE5®LUTION, INC. AROMATIC GCMS Company: CONOCOPHILLIPS Client ID: US138734 Country: UNITED STATES Project #: 07-247-A Basin: NORTH SLOPE Lab ID: CP282502 Lease: Sample Type: SWC ROTARY Block: Sampling Point: Field: Formation: Well Name: NOATAK-1 Geologic Age: JURASSIC, LATE Latitude: Top Depth: 8306 FT Longitude: Bottom Depth: FT m/z 253: Monoaromatic steroids M1070970.D C M1070970.D • . ~~. . (C20+G21)/E TAS ~ M 1.0 (1i3%) TAS #1 20/20+27 M TAS #2 21/21+28 M %26 TAS D %27 TAS D %28 TAS D %29 TAS D C28/C26 20S TAS C28/C27 20R TAS Dia/Regular C27 MAS %27 MAS D %28 MAS D %29 MAS Q (C21+C22)/E MAS M 1.0 (1.3%) TAS/(MAS+TAS)_ M TA28/(TA28+MA29) M 1.0 (0.8%) . .. Dinosteroid Index A C4/C3+C4 Mester A .. ~ . .~ MPH 0.73 M Rc(a) if Ro < 1.3 (Ro%) 0.81 M Rc(b) if Ro > 1.3 (Ro%) 1.86 M MPI-2 0.79 M DNR-1 6.37 M DNR-2 2.84 M TNR1 0.94 M` TDE-1 2.84 M TDE-2 0.16 M MDR 5.43 M Rm {Ro%) 1.02 M MDR23 0.98 M MDR1 0.27 M DBT/Phenanthrene 0.13 D • 'Definition and utility of the ratios can be found on our website www.BaselineDGSl.com 3 2A=Source Age; D=Depositional environment; M= Maturity 3TThermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project#: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M1070970.D 230 92 92 92 92 92 92 92 92 92 92 106 106 106 106 106 106 106 106 1D6 106 106 106 106 106 106 106 106 106 106 106 106 134 134 134 134 134 134 134 134 OTP Ortho-terphenyl (internal standard) 75.010 74265 18829 300.0 300.0 16AB C16 Alkyl Benzene 66.742 42060 8981 169.9 143.1 17AB C17 Alkyl Benzene 71.580 38126 9260 154.0 147.5 18AB C18 Alkyl Benzene 75.767 31571 8301 127.5 132.3 1TH1092 Dimethyl dibenzothiophene 1 77.508 6179 879 25.0 14.0 2TH1092 Dimethyl dibenzothiophene 2 78.230 6839 877 27.6 14.0 19AB C19 Alkyl Benzene 79.514 27614 7513 111.5 119.7 20AB C20 Alkyl Benzene. 82.945 22446 6017. 90.7 95.9 21 AB C21 Alkyl Benzene 86.146 19774 5407 79.9 86.1 22AB C22 Alkyl Benzene 89.172 16187 4319 65.4 68.8 23AB C23 Alkyl Benzene 92.022 14063 3725 56.8 59.4 PHYBz Phytanyl Benzene 93.940 3000 444 12.1 7.1 24AB C24 Alkyl Benzene 94.749 11505 2706 46.5 43.1 25AB C25 Alkyl Benzene 97.353 9631 2374 38.9 37.8 26AB C26 Alkyl Benzene 99.851 8160 1703 33.0 27.1 16ATM C16 Alkyl Toluene (meta) 65.985 60598 13964 244.8 222.5 16AT0 C16 Alkyl Toluene (ortho) 66.935 28424 5805 114.8 92.5 17ATM C17 AIkyI Toluene (meta) 70.876 61010 14875 246.5 237.0 17AT0 C17 Alkyl Toluene (ortho) 71.738 25457 6073 102.8 96.8 18ATM C18 Alkyl Toluene (meta) 75.116 53907 13132 217.8 209:2 18AT0 C18 AIkyI Toluene (ortho) 75.907 22141 5473 89.4 87.2 1THI0106 Dimethyl dibenzothiophene 1 77.544 6309 1270 25.5 20.2 2THI0106 Dimethyl dibenzothiophene 2 78.265 5136 720 20.7 11.5 • 19ATM C19 Alkyl Toluene (meta) 78.881 41600 10829 168.0 172.5 19AT0 C19 Alkyl Toluene (ortho) 79.637 18186 4748 73.5 75.6 20ATM C20 Alkyl Toluene (meta) 82.346 35880 9794 144:9 156.0 20AT0 C20 Alkyl Toluene (ortho) 83.068 14376 3800 58.1 60.5 21ATM C21 Alkyl Toluene (meta) 85.566 30994 7934 125.2 ..126.4 21AT0 C21 Alkyl Toluene (ortho) 86.270 17056 3537 68.9 56.4 22ATM C22 Alkyl Toluene (meta) 88.592 26112 7185 105.5 114:5 22AT0 C22 AIkyI Toluene (ortho) 89.296 13798 3401 55.7 54.2 23ATM C23 Alkyl Toluene (meta) 91.459 21316 5284 86:1 84.2 23AT0 C23 Alkyl Toluene (ortho) 92.146 10351 2829 41.8 45.1 24ATM C24 Alkyl Toluene (meta) 94.188 17789 4546. 71.9 72.4 24AT0 C24 Alkyl Toluene (ortho) 94.872 9657 1959 39.0 31.2 PHYTL Phytanyl Toluene 95.875 9616 1508 38.8 24.0 25ATM C25 Alkyl Toluene (meta) 96.790 14253 3370 57.6 53.7 25AT0 C25 Alkyl Toluene (ortho) 97.476 6352 1569 25.7 25.0 26ATM C26 Alkyl Toluene (meta) 99.306 13610 2997 55.0 47.8 26AT0 C28 Alkyl Toluene (ortho) 99.974 5324 1232 21.5 19.6 15A1 C15 Aryl Isoprenoids 60.866 1782 349 7.2 5.6 16A1 C16 Aryl Isoprenoids 66.073 3498 695 14.1 11.1 17AI C17 Aryl Isoprenoids 70.471 4375 876 17.7 14.0 18A1 C18 Aryl Isoprenoids 74.817 2611 544 10.5 8.7 19A1 C19 Aryl Isoprenoids 20A1 C20 Aryl Isoprenoids 21AI C21 Aryl Isoprenoids 22A1 C22 Aryl Isoprenoids ISOR Isorenieratane • C C €. Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M1070970.D 142 2MN 2-Methylnaphthalene 37.942 130978 24471 529.1 389.9 142 1MN 1-Methylnaphthalene 39.174 98750 17417 398:$ 277.5: 149 MTTC578 5,7,8,-triMe-MTTChroman 156 2EN 2-Ethylnaphthalene 46.123 42409 7217 171.3 115.0... 156 1EN 1-Ethylnaphthalene 46.211 14032 2952 56.7 47.0 156 26DMN 2,6-Dimethylnaphthalene 47.038 259962. 42789. 1050:1 681:8 156 27DMN 2,7-Dimethylnaphthalene 47.196 216230 40557 873.5 646.2 156 1317DMN 1,3 & 1,7-Dimethylnaphthalenes 48.199 490249 69045 4980.4 1100:1 156 16DMN 1,6-Dimethylnaphthalene 48.445 357606. 62981 1444.6 1003.5 1b6 23DMN 2,3-Dimethylnaphthalene 49:624 58098 911.7. 234.7. 145.3 156 14DMN 1,4-Dimethylnaphthalene 49.712 109422 18178. 442.0 289.6 156 15DMN 1,5-Dimethylnaphthalene 49.817 74697 14497 301:7 231;0 156 12DMN 1,2-Dimethylnaphthalene 50.767 38831 6500 156.9 103.6 161 MTTC8 B-Me-MTTChroman 168 2MBP 2-Methylbiphenyl 46.598 10465 1885 42.3 30.0 168 DPM Diphenylmethane 48.850 20822 3615 84.1 57:6 168 3MBP 3-Methylbiphenyl 53.301 430213 75173 1737.9 1197.7 168 4MBP 4-Methylbiphenyl 53.952 186276 32861 752.& ` 523.8 168 DBF Dibenzofuran 55.377 48525 7862 196.0 125.3 170 BB_EMN Ethyl-methyl-Naphthalene 55.113 152389 20852 615.6. 329.0 170 AB_EMN Ethyl-methyl-Naphthalene 56.327 62732 10177 253.4 162.1 170 137TMN 1,3,7-Trimethylnaphthalene. 56:784 325107 55726 1313.3 887:9 170 136TMN 1,3,6-Trimethylnaphthalene 57.171 404884 69142 1635.6 1101.6 170 146135T (1,4,6+1,3,5)-Trimethyinaphthalenes 58.227 321586 50873 1299:1 810:6 170 236TMN 2,3,6-Trimethylnaphthalene 58.491 302566 54977 1222.2 875.9 170 127TMN 1,2,7-Trimethylnaphthalene 59.229 45602 $069 184:2 128.8- 170 167126T (1,6,7+1,2,6)-Trimethylnaphthalenes 59.405 282392 45972 1140.7 732.5 170 124TMN 1,2,4-Trimethylnaphthalene 60.320 21050 4052 85.0 64.6 170 125TMN 1,2,5-Trimethylnaphthalene 60.760 59883 10934 241.9 174.2 178 PHEN Phenanthrene 70.278 543605 124128 2195.9 1977.7 184 1357 1,3,5,7-Tetramethylnaphthalene 64.718 124036 23233 501.1 370.2 184 1367 1,3,6,7-Tetramethylnaphthalene 65.880 185133 40205 747.9 640.6 184 1247 (1,2,4,7+1,2,4,6+1,4,6,7)-Tetramethylnaphthalenes 66.636 90892 17946 367.2 285.9 184 1257 1,2,5,7-Tetramethylnaphthalene 66.812 41281 8341 166.8 132.9 ` 184 2367 2,3,6,7-Tetramethylnaphthalene 67.181 37748 7930 152:5 126.3 184 1267 1,2,6,7-Tetramethylhaphthalene 67.621 38900: 8389 157.1.. 133:7 184 1237 1,2,3,7-Tetramethylnaphthalene 67.797 14252 3380 57.6 53.9 184 1236 1,2,3,6-Tetramethylnaphthalene &8.061 23220 ' " 4992 93.8 `79.5' 184 1256 1,2,5,6-Tetramethylnaphthalene 68.782 32137 7333 129.8 116.8 184 DBT Dibenzothiophene 68.993 70238 15658 283.7 ! 249.5` 191 BH32 C32 Benzohopane 1.94 BH33 C33 Benzohopane 191 BH34 C34 Benzohopane 191 BH35 C35 Benzohopane 192 3MP 3-Methylphenanthrene 75.204 300034 70684 1212.0 1126.2 192 2MP 2-Methylphenanthrehe 75.380 -349720 84379 1412.7 1344.4 192 9MP 9-Methylphenanthrene 76.083 442922 100641 1789.2 1603.5 192 1MP 1-Methylphenanthrene...: 76.259 346203- 82889 1398.5 1$20.7 :ompany: CONOCOPHILLIPS Client ID: US138734 'Nell Name: NOATAK-1 Project #: 07-247-A )epth: 8306 - FT Lab ID: CP282502 iampling Point: File Name: M1070970.D 198 CAD Cadalene 198 12467PMN 1,2,4,6,7-Pentamethylnaphthalene 73.075 13653 3175 55:2 50:6 ,198 12357PMN 1,2,3,5,7-Pentamethylnaphthalene 73.392 8924 2114 36.0 33.7 1198 4MDBT 4 Methyl Dibenzothiophene 73.532 104628 24716 422.7 - 393:8'. 198 23MDBT 2 & 3 Methyl Dibenzothiophenes 74.324 69154 14345 279.4 228.6 198 1MDBT 1 Methyl Dibenzothiophene 75.133 19251 4219 77:8 67.2 206 36DMP 3,6-Dimethylphenanthrene 79.426 59833 12541 241.7 199.8 206 26DMP 2,6-Dimethylphenanthrene 79.690 127915 30971 816.7 493:5.. 206 27DMP 2,7-Dimethylphenanthrene 79.795 80487 20827 325.1 331.8 206 39DMP (3,9+3,10+2,10+1,3)-Dimethylphenanthrenes 80.306 568114 116473 2294.9 1855.7' 206 29DMP (2,9+1,6)-Dimethylphenanthrenes 80.499 299822 53457 1211.2 851.7 206 17DMP 1,7-Dimethylphenanthrene 80.658 202968 52881 819.9 842.5 206 23DMP 2,3-Dimethylphenanthrene 80.921 76784 18605 310.2 296.4 206 19DMP 1,9-Dimethylphenanthrene 81.045 133638 33173 539.8 528.5 206 18DMP 1,8-Dimethylphenanthrene 81.449 59317 14468 239.6 230.5 206 12DMP 1,2-Dimethylphenanthrene 81.959 19600 4891 79:2 77.9 206 9 10DMP 9,10-Dimethylphenanthrene 82.610 3486 877 14.1 14.0 212 DMDBT Dimethyldibenzothiophene 219 RET Retene 86.234 14010 2947 56.6 47.0 226 TMDBT Trimethyldibenzothiophene 81.608 164207 8263 663.3 131.7 231 231A20 C20 Triaromatic Steroid 231 231 B21 C21 Triaromatic 231 231 C26 C26 20S Triaromatic • 231 231 D26 C27 20S 8 C26 20R Triaromatic 231 TADMD1 C28 23,24-Cholestane Triaromatic 231 TADMD2 C28 23,24-Cholestane Triaromatic 231 231 E28 C28 20S Triaromatic 231 231 F27 C27 20R Triaromatic 231 TADMD3 C28 23,24-Cholestane Triaromatic 231 C29TA1 C29 Triaromatic 231 C29TA2 C29 Triaromatic 231 TADMD4 C28 23,24-Cholestane Triaromatic 231 231G28 C28 20R Triaromatic 231 TADMD5 C28 23,24-Cholestane Triaromatic - 231 C29TA3 C29 Triaromatic 245.. C3S C27 20S 3-Methyl Triaromatic Steroid 245 C4S C27 20S 4-Methyl Triaromatic Steroid 245 E2S C28 20S 2-Methyl Triaromatic Steroid 245 E3SC3R C28 20S 3-Methyl & C27 20R 3-Methyl TAS 245 E4SC4R C28 20S 4-Methyl & C27 20R 4-Methyl TAS 245 S2S C29 20S 2-Methyl Triaromatic Steroid 245 DA Triaromatic Dinosteroid a 245 S3S C29 20S 3-Methyl Triaromatic Steroid 245 DB Triaromatic Dinosteroid b 245 S4SE2R C29 20S 4-Methyl & C28 20R 2-Methyl TAS 245 E3R C28 20R 3-Methyl Triaromatic Steroid 245 E4R C28 20R 4-Methyl Triaromatic Steroid 245 DC TriaromaticDinosteroid c 245 DD Triaromatic Dinosteroid d • company: CONOCOPHILLIPS Client ID: US138734 Nell Name: NOATAK-1 Project #: 07-247-A )epth: 8306- FT Lab ID: CP282502 Sampling Point: File Name: M1070970.D 245 S2R C29 20R 2-Methyl Triaromatic Steroid 245 S3R C29 20R 3-Methyl Triaromatic Steroid 245 DE Triaromatic Dinosteroid e 245 S4R C29 20R 4-Methyl Triaromatic Steroid 245 DF Triaromatic Dinosteroid f 253 S253A ~ C21 Ring-C Monoaromatic Steroid 253 S253B C22 Monoaromatic steroid 253 S253C C27 Reg 5p(H),10(3(CH3) 20S 253 S253D C27 Dia 10(3(H),5(3(CH3) 20S 253 S253E C27 Dial-0pH,5pCH3 20R+Reg5~H,10(3CH3 20R 253 S253F C27 Reg 5a(H),10(3(CH3) 20S 253 S253G C28 Dia 10aH,5aCH3 20s+Reg5pH,10pCH3 20S 253 S253H C27 Reg 5a(H),10(3(CH3) 20R 253 S2531 C28 Reg 5a(H),10(3(CH3) 20S 253 S253J C28 Dia 10aH,5aCH3 20R+Reg5pH,10(3CH3 20R 253 S253K C29 Dia 10(iH,5pCH320S+Reg5pH,10(3CH3 20S 253 S253L C29 Reg 5a(H),10(3(CH3) 20S 253 S253M C28 Reg 5a(H),10R(CH3) 20R 253 S253N C29 Dia 10(3H,5RCH3 20R+Reg5(3H,10RCH3 20R 253 S2530 C29 Reg 5a(H),10p(CH3) 20R 182 DMBP1 Dimethybiphenyl peak 1 60.056 38803 7453 156.7 118.7 182 DMBP2 Dimethylbiphenyi peak 2 60.830. 103754 20136 419.1 $20.6 182 DMBP3 Dimethylbiphenyl peak 3 61.059 285847 58016 1154.7 924.4 182 DMBP4 Dimethylbiphenyl peak 4 61.235 23422 4753 ' 94:6 75.7 182 DMBP5 Dimethylbiphenyi peak 5 61.675 222904 44016 900.4 701.3 182 DMBP6 Dimethylbiphenyl peak 6 62.097 52149 10632 270.7 169.4 182 DMBP7 Dimethylbiphenyl peak 7 62.238 2923 401 11.8 6.4 182 DMBP8 Dimethylbiphenyi peak 8 62:713 86652 17064 350.0 271.9 182 DMBP9 Dimethylbiphenyl peak 9 62.942 3323 487 13.4 7.8 182 DMBP10 Dimethyibiphenylpeak 10 63.188 111320 24040 449.7 3$3.0 182 DMBP11 Dimethylbiphenyl peak 11 63.487 85509 12870 345.4 205.1 182 DMBP12 Dimethyibiphenyl peak 12 63.751 6544 1082 26.4 17.2 182 DMBP13 Dimethylbiphenyl peak 13 63.927 68810 13937 278.0 222.1 182 DMBP14 :Dimethylbiphenyl peak 14 64.191 4779 647 19.3 10.3 182 DMBP15 Dimethylbiphenyl peak 15 64.490 5039 530 20.4 8.4 182 DMBP16 Dimethylbiphenyl peak 16 64.771 4613 692 18.6 11.0 212 ET4DBT 4-Ethyldibenzothiophene 77.157 8003 1986 32.3 31.6 212 DM46D6T 4,6-Dimethyldibenzothiophene 77.526 54838 13569 221.5 216.2 212 DMDBTS Dimethyldibenzothiophene peak 3 77.825 2182 401 8.8 6.4 212 DMDBT4 Dimethyldibenzothiophene peak 4 78.089 27808. ` 6532 - 112.3 104:1 212 DMDBTS Dimethyldibenzothiophene peak 5 78.282 69698 11723 281.6 186.8 212. DMDBT6 Dimethyldibenzothiophene peak 6 78.898 18957. 4101 76.6- 65.3 212 DM14DBT 1,4-Dimethyldibenzothiophene 79.092 21398 3836 86.4 61.1 212 DMDBT7 Dimethyldibenzothiophene peak 7 79.584. 16213 2635 65,5 ' 42,0 `, 212 DMDBT8 Dimethyldibenzothiophene peak 8 79.672 3562 1084 14.4 17.3 212 DMDBTS Dimethyldibenzothiophene peak 9 80.165' 4205 1D17 17.0 16:7 r~ V Company: CONOCOPHILLIPS Client ID: US138734 Well Name: NOATAK-1 Project #: 07-247-A Depth: 8306 - FT Lab ID: CP282502 Sampling Point: File Name: M1070970.D • • ~_J • • Isotech Mudgas Data Job 8250 Well: NOATAK #1 59 IsoTubes Company Depth 1 Isotech Isotech Sample Sample Gas GC Oz+Ar COz Nz CO C, Cz Cilia C3 C3Hs iCq nC4 iCs nCs Cs+ Mass Spec S13C~ S"CZ S"C3 S"iCa S13nCa SDC~ Comments Lab No. Feet Lab No. Job No. Dale Time Upils Date ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm_ _ppm ppm_ .ppm ppm Date per mil pef mll pef mil per mil per mil per mil US138735 510 114507 8250 2/12/2007 6:00 1 3/29/2007 219500 410 779900 0 174 12 0 5 0 1 1 0 0 0 U5138736 750 114508 8250 2/12/2007 11;40 1 3/29/2007 219400 420 780000 0 167 2 0 1 0 0 0 0 0 0 US138737 1000 114509 8250 2/1212007 0:00 2.5 3/29/2007 219200 590 779900 0 295 1 0 0 0 0 0 0 0 0 US138738 1250 114510 8250 211212007 0:00 2 3/29/2007 219400 540 779600 0 415 1 0 0 0 0 0 0 0 0 US138739 1500 114511 8250 211312007 4:45 78 3/29/2007 213400 380 771700 0 14500 47 0 1 0 0 0 0 0 0 3/30/2007 -47.4 -35.5 -231 US138740 1724 114512 8250 2113/2007 0:00 54 3129/2007 215800 340 773500 0 10100 183 0 1 0 90 0 0 0 0 3/30/2007 -46.8 -34.7 -30.7 -234 US138741 1724 114513 8250 2/1312007 0:00 54 3/29/2007 219000 680 780300 0 6 0 0 0 0 0 0 0 0 0 US138742 2000 114514 8250 2/13/2007 0:00 41 3/29/2007 215800 370 776100 0 7580 64 0 1 0 46 0 0 0 0 3/3012007 -49.4 US138743 2298 114515 8250 2/13/2007 22:30 57 3/29/2007 211500 380 777500 0 10600 36 0 2 0 27 0 0 0 0 3130!2007 -50.0 US138744 2500 114516 8250 2/14/2007 1:47 62 3/29/2007 207100 500 781000 0 11400 13 0 1 0 14 0 0 0 0 3130/2007 -51.4 US138745 2750 114517 8250 2/14/2007 0:00 40 3/29/2007 214400 520 777200 0 7650 5 0 0 0 2 0 0 0 0 3/30/2007 -53.4 US138746 3020 114518 8250 2/21/2007 5:26 i6 3/29/2007 207500 190 789800 50 2440 5 1 0 0 1 0 0 0 0 3/30/2007 -55.7 US138747 3255 114519 8250 2/21/2007 0:00 37 3/29/2007 215600 530 777200 0 6690 20 0 1 0 0 1 0 0 0 3/30/2007 -57.6 US138748 3500 114520 8250 2/21/2007 19:24 71 3/29/2007 211800 500 776700 0 10900 59 0 15 0 4 7 4 4 10 3/30/2007 -57.9 -239 US138749 4000 114521 8250 2/22/2007 0:00 30 3/29/2007 216800 440 779400 0 3320 21 0 8 0 2 3 2 1 3 3/30/2007 -58.5 US138750 4250 114522 8250 212212007 20:02 35 3/30/2007 213400 580 779500 0 6400 74 0 24 0 6 6 4 3 10 3130/2007 -58.4 US138751 4500 114523 8250 2/23/2007 1:34 22 3/30/2007 214200 760 780700 0 4200 56 0 17 0 5 4 3 2 6 3/30/2007 -58.2 US138752 4750 114524 8250 2/23/2007 0:00 20 3/30/2007 213400 1800 780300 0 4390 51 0 15 0 5 3 2 1 6 3130/2007 -58.4 US138753 5000 114525 8250 2124/2007 2:29 13 3/30/2007 213300 2900 781100 0 2690 30 0 14 0 5 3 2 1 5 3130/2007 -58.6 US138754 5250 114526 8250 2/2412007 0:00 12 3/30/2007 215100 700 761000 0 3110 34 1 19 0 7 5 4 2 6 313012007 -58.5 US138755 5500 114527 8250 2/24/2007 0:00 14 3130/2007 214200 580 782100 0 3020 42 1 27 0 10 7 5 2 7 3/30/2007 -58.3 US138756 5750 114528 8250 212412007 20:02 26 3/30/2007 213800 660 780500 0 4870 66 1 57 0 19 16 9 4 12 4/01/2007 -58.0 -216 US138757 6000 114529 8250 2/25/2007 0:28 22 3/30/2007 214700 550 761000 0 3580 73 1 47 0 15 10 4 1 1 3/30/2007 -56.7 US138758 6250 114530 8250 2/25/2007 0:00 15 3/30/2007 216200 370 780400 0 2930 69 1 38 0 11 10 5 2 8 3/30/2007 -56.4 US138759 6500 114531 8250 2/25/2007 19:44 14 3/30/2007 216800 400 780000 0 2560 93 1 52 0 14 13 6 3 10 3130/2007 -55.5 US738760 6750 114532 8250 2126/2007 1:01 29 3/30/2007 213700 710 780500 0 4530 238 2 150 1 38 38 16 9 23 3130/2007 -55.1 US138761 7000 114533 8250 2/26/2007 0:00 16 3/30/2007 214500 350 782400 0 2320 194 3 142 1 35 43 17 11 25 3130/2007 -54.5 US138762 7063 114534 8250 2/26/2007 0:00 102 3/30/2007 208500 360 772500 0 15600 1360 25 949 9 182 263 83 65 113 3/30/2007 -53.9 US138763 7096 114535 8250 2/26/2007 0:00 122 3/30/2007 208200 370 769800 0 18300 1560 28 1000 10 175 266 80 64 108 3/30/2007 -53.5 US138764 7240 114536 8250 2/27/2007 2:29 222 3/30/2007 207200 500 758300 80 26500 3090 72 2440 25 306 740 165 187 356 3/30/2007 -53.0 US138765 7250 114537 8250 2/27/2007 2:40 41 3/30/2007 214900 500 779600 0 3230 467 8 574 5 105 242 71 76 226 3/30/2007 -53.2 US138766 7314 114538 8250 2/27/2007 0:00 62 3/30/2007 213400 440 775300 0 8460 911 9 793 5 96 262 58 67 156 3/30/2007 -52.8 US138767 7360 114539 8250 2/27/2007 18:23 88 3/30/2007 212300 460 772000 0 11800 1390 12 1160 6 126 374 74 88 172 3/30/2007 52.9 US738768 7372 114540 8250 ~ 2/27/2007 18:42 112 3/30/2007 211000 470 767700 0 16400 1900 22 1500 11 159 477 92 112 200 3/30/2007 -52.8 -37.2 -33.5 -33.4 -32.8 -238 US138769 7420 114541 8250 2/2712007 20:47 120 3/30/2007 210900 530 766600 0 17500 1910 11 1430 10 151 485 99 126 240 3/30/2007 -52.7 US138770 7500 114542 8250 2/2712007 23:12 90 3130/2007 211400 390 773000 0 11200 1510 7 1370 6 156 502 103 135 254 3/3012007 -52.9 US138771 7750 114543 6250 310312007 0:00 37 3/30/2007 214400 380 780100 0 3620 518 1 501 2 67 165 42 45 98 3130/2007 -52.3 US138772 8000 114544 8250 3104/2007 3:19 38 3/3012007 212200 820 781000 0 4080 694 1 628 1 115 203 57 58 132 3130YL007 -51.5 US138773 8160 114545 8250 311012007 0:00 15 3130!2007 2140D0 320 783300 0 1960 232 1 103 1 14 28 9 10 30 3/30/2007 -51.0 US138774 8170 114546 8250 3/1012007 0:00 18 3/30/2007 208100 350 789400 0 1700 212 1 104 1 15 30 9 10 30 3/30/2007 -50.8 US138775 8180 114547 8250 3!10/2007 0:00 20 3/30/2007 213000 330 783900 0 2280 273 1 124 1 17 32 9 10 29 4/01/2007 -50.9 US138776 8188 114548 6250 3/1012007 0:00 87 3/30/2007 209900 320 776800 0 10900 1280 2 543 2 67 107 27 25 46 3/31/2007 -51.3 US138777 8190 114549 8250 3/10/2007 0:00 223 3/30/2007 204100 370 745400 0 41600 5440 1 2250 1 246 369 86 74 100 3/31/2007 -50.3 US738778 8195 114550 8250 3/10/2007 0:00 546 3/30/2007 129400 360 522100 0 290000 37200 0 15400 2 1620 2440 516 441 571 3/31/2007 -50.3 US138779 8205 114551 8250 3/10/2007 0:00 567 3/30/2007 115200 330 495100 0 325000 41100 0 16900 2 1810 2780 597 518 679 3/31/2007 -50.3 US138780 8225 114552 8250 3/10/2007 0:00 750 3/30/2007 87000 2100 435300 0 404800 45400 0 18500 1 1920 3020 616 539 802 3/31/2007 -51.0 US138781 8232 114553 8250 3/10/2007 17:21 205 3/30/2007 207900 370 759400 0 24600 4170 0 2350 0 317 496 132 119 186 3/31/2007 ~-50.3 US138782 8243 114554 8250 3/1012007 18:41 260 313012007 197800 370 731900 0 54900 8690 0 4320 0 545 842 217 191 264 3/31!2007 -50.4 US138783 8253 114555 8250 3/10/2007 19:00 350 3/30/2007 168100 470 648300 0 146500 22000 0 10300 1 1200 1850 431 373 488 4/01/2007 -50.4 US138784 8266 114556 8250 3!10/2007 19:37 390 3130/2007 155900 940 615200 0 183800 27100 0 12100 1 1350 2110 486 427 607 4/01/2007 -50.4 -34.5 -29.6 -30.7 -27.9 -241 US138785 8280 114557 8250 311012007 19:57 245 3/30/2007 202300 540 739800 0 45300 6960 0 3420 1 416 670 170 155 262 4/0112007 -50.7 US138786 8295 114558 8250 311012007 23:27 1300 3/3012007 25400 2500 143300 0 644900 102400 0 53800 0 6830 11200 2650 2440 4570 4/01/2007 -50.6 US138787 8298 114559 8250 3/10/2007 23:40 670 3/3012007 130300 1300 537600 0 263300 39500 0 19100 0 2380 3530 869 755 1410 4/0112007 -50.1 US138788 8310 114560 8250 3/10/2007 23:56 575 3130/2007 120900 2900 527900 0 268300 44500 0 22900 0 2890 4640 1250 1160 2430 4/0112007 -50.5 US138789 8317 114561 8250 3/11/2007 3:03 122 3/30/2007 210900 560 777400 0 6920 1530 2 1210 1 224 440 171 176 503 4/0112007 -51.1 US738790 8330 114562 8250 3/11/2007 4:01 85 3!3012007 212000 560 776900 0 6960 1300 1 927 1 180 362 155 160 460 4/01/2007 -51.0 US138791 8360 114563 8250 3/11/2007 0:00 50 3/30/2007 211700 860 779900 0 4880 987 1 713 1 129 270 110 116 356 4/01/2007 -50.8 US138792 8375 114564 8250 3/11/2007 0:00 70 3/30/2007 212100 990 773700 0 9250 1620 1 1030 1 181 370 155 162 482 4/01/2007 -51.0 -34.6 -29.6 -226 U5138793 8425 114565 8250 3/11/2007 0:00 54 3/30/2007 210000 560 779200 0 7000 1370 0 792 0 120 261 112 122 433 4/01/2007 -50.6 • Chemical analysis based on standards accurate to within 2°h. In blue m carbon Isotope data obtained Wa cryogenle anrlchmenl • • • Isotech Mudgas Data Job 8272 Well: Noatak #1 27 Gas Bags Company Depth 1 Gas Isotech Isotech GC 02 + Ar COZ NZ CO C~ CZ CzHq C3 C3Hg iCq nCq iCs nCg Cg+ Mass Spec S13C~ S13C2 S13C3 S13iCq S13nCq SDC~ SDCZ SDC3 Comments Lab No. Feet Units Lab No. Job No. Date ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm ppm Date per mii per mil per mif per mii per mil per mil per mil per mil US138823 7096 122 114764 8272 4/03/2007 207400 370 768800 0 19700 1780 29 1180 10 203 308 88 70 97 4/10/2007 -53.4 US138824 7235 100 114765 8272 4/03/2007 212600 400 775500 0 8760 1000 16 944 7 143 327 84 88 111 4/10/2007 -53.5 US138825 7241 175 114766 8272 4/03/2007 209400 520 765800 50 19100 2130 53 1740 18 230 541 123 133 195 4/10/2007 -53.1 -36.4 -32.4 -32.3 -31.6 -241 US138826 7360 88 114767 8272 4/03/2007 212500 500 772500 0 11300 1330 11 1110 6 119 349 66 77 105 4/10/2007 -53.0 US138827 7372 112 114768 8272 4/03/2007 210900 470 768100 0 16200 1870 21 1480 11 154 460 86 101 136 4/10/2007 -52.9 US138828 7420 120 114769 8272 4/03/2007 211000 530 767600 0 16800 1810 10 1350 9 141 441 85 105 134 4/10/2007 -52.8 US138829 8160 19 114770 8272 4/03/2007 213900 370 783200 0 2080 236 1 97 1 13 25 7 8 17 4/10/2007 -51.3 US138830 8170 18 114771 8272 4/03/2007 208500 360 789100 0 1680 211 1 104 1 15 29 9 9 19 4/10/2007 -51.1 US138831 8180 21 114772 8272 4/03/2007 2135D0 360 783400 0 2290 270 1 120 1 16 29 9 9 19 4/10/2007 -51.4 US138832 8188 87 114773 8272 4/03/2007 210200 320 776700 0 10700 1250 2 533 1 65 103 25 23 33 4/10/2007 -50.7 US138833 8190 223 114774 8272 4/03/2007 204700 440 747400 0 39400 5140 1 2110 1 230 341 77 65 66 4/10/2007 -51.0 US138834 8195 546 114775 8272 4/03/2007 218500 420 780500 0 247 120 0 107 0 17 27 7 6 9 US138835 8205 567 114776 8272 4/03/2007 Flat Bag US138836 8225 750 114777 8272 4/03/2007 93200 2100 454500 0 382800 43500 0 17600 0 1820 2830 558 478 565 4/10/2007 -51.1 -34.6 -29.5 -31.2 -28.6 -225.8 -162.4 -132.3 US138837 8232 205 114778 8272 4/03/2007 208000 400 759300 0 24700 4140 0 2310 0 307 471 118 101 113 4/10/2007 -50.6 US138838 8243 260 114779 8272 4/03/2007 198400 380 733500 0 53200 8460 0 4190 0 524 797 197 167 171 4/10/2007 -50.9 US138839 8253 350 114780 8272 4/03/2007 170000 470 651800 0 142100 21500 0 10100 0 1170 1770 398 333 322 4/10/2007 -49.8 US138840 8266 390 114781 8272 4/03/2007 159800 930 625900 0 172500 25400 0 11200 0 1240 1890 417 351 366 4/10/2007 -50.4 US138841 8280 245 114782 8272 4/03/2007 202000 590 738800 0 46200 7210 0 3570 0 436 689 168 146 175 4/10/2007 -50.9 US138842 8295 1300 114783 8272 4/03/2007 18800 2800 121200 0 660900 108500 0 58800 0 7670 12300 2860 2550 3610 4/10/2007 -50.5 -34.2 -29.3 -31.1 -28.5 -227.7 -179.2 -132.1 US138843 8298 670 114784 8272 4/03/2007 123300 1300 517800 0 276400 46000 0 24000 0 2980 4830 1140 1000 1300 4/10/2007 -50.2 US138844 8310 575 114785 8272 4/03/2007 121300 3000 530000 0 266400 44800 0 23100 0 2890 4760 1180 1050 1570 4/10/2007 -50.4 US138845 8317 122 114786 8272 4/03/2007 211100 540 776400 0 7790 1650 1 1250 0 220 422 154 151 289 4/10/2007 -51.2 US138846 8330 85 114787 8272 4/03/2007 212000 580 777600 0 6670 1240 1 -882 1 169 334 135 133 249 4/10/2007 -51.0 US138847 8360 50 114788 8272 4/03/2007 212000 850 779900 0 4690 951 1 691 1 127 262 106 109 269 4/10/2007 -50.8 US138848 8375 70 114789 8272 4/03/2007 212300 990 773800 0 9150 1600 1 1010 1 177 354 143 145 315 4/10/2007 -51.1 US138849 8425 54 114790 8272 4/03/2007 210100 570 779500 0 6840 1330 0 764 0 115 247 103 109 275 4/10/2007 -50.5 Chemical analysis based on standards accurate to within 2%. in bold =isotopes analyzed using conventional off-line preparation, dual inlet mass spectrometry. ~. BASELINE RES©LUTiON, INC- SOXHLET Com an CONOCOPHILLIPS Pro ect #: 07-247-A D • ~ ~•. ~ -. ~, • -. -. .. US138720 8211 CP282488 44.7680 0.0645 0.14 1441 US138721 8218 CP282489 44.9382 0.0181 0.04 403 US138722 8227 CP282490 46.1971 0.0171 0.04: 370, US138723 8241 CP282491 46.7667 0.0412 0.09 881 US138724 8248 CP282492 39.8916 0.0209. 0.05 524 US138725 8255 CP282493 38.8790 0.0247 0.06 635 US138726 8265 CP282494 34.3413 OA123 0.04 358 US138727 8273 CP282495 42.0846 0.0331 0.08 787 US138728 8287 CP282496 42.4521 0.0255 0.06 601 US138729 8290 CP282497 39.6088 0.0412 0.10 1040 US138730 8297. CP282498 40.2563 0.0250 0.06 621 US138731 8299 CP282499 40.1093 0.0327 0.08 815 US138732 8304 CP282500 38.3106 0.0377' 0.:10. 984 US138733 8304 CP282501 35.6474 0.0514 0.14 1442 US138734 8306 CP282502 26.6956 0.0840 0.3.1 3147 US138822 Soltex CP282590 9.4904 0.3468 3.65 36542 Baseline Resolution, Inc., 143 Vision Park Blvd., Shenandoah, Texas 77384 Phone: 281-681-2200 Fax: 281-881-0328 Email: info@brilabs.com • • ~- • .• .. .. .. US138719 CP282487 SWC ROTARY 8173 I I I NOPR f 0.30 i 0.24 I I 1.53 I ~ ~ ~ 0.90 i ~ ~ ~ 1 411 I , i 501 295 77 0.13 I Baseline Resolution, Inc., 143 Vision Park Blvd., Shenandoah, Texas 77384 Phone: 281-681-2200 Fax: 281-681-0326 Email: info@brilabs.com Com an CONOCOPHILLIPS Noatak #1 Pro'ecf #: 07-247-A • • • Lab ID: CP282487, Client ID: US138719, Prep: NOPR Well Name: NOATAK-1, Depth: 8173 8.80 8.30 7.80 7.30 6.80 6.30 5.80 5.30 600 S1: 0.24 S2: 1.53 S3: 0.90 550 Tmax:411 Leco TOC: 0.30 HI: 510 Oi: 300 500 450 US138719 - NOPR -GOOD Temp °C 400 350 300 4.80 250 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Humble Geochemical Services Apri110, 2007 Division of Humble Instruments & Services, Inc. P.O. Box 789 Humble, Texas 77347 218 Higgins Street Humble, Texas 77338 Telephone:281-540-6050 Fax:281-540-2864 Web. site: www.humble-inc.coin Email: humble@humble-inc.com Client Id: ConocoPhillips Attn: Albert Holba Well: Noatak~~l Introduction: One SWC sample from 8173 ft. as analyzed for vitrinite reflectance (%Ro), visual kerogen, and thermal alteration index (TAI) determination. Maturity data indicate that this sample is in the `Oil window maturity' zone (Table 1). Ro data are consistent with the TAI (Thermal Alteration Index or `spore color') and fluorescence data. Amorphous kerogen dominates over terrestrial kerogen in this sample. Discussion: _ The %Ro value is 0.92%. There is only fair organic recovery for visual study. Vitrinite particles are very rare in this sample and less than the desired 40 readings were obtained. However, vitrinite reflectance data quality is still considered to be reasonably good. ~ Palynomorphs are present in this sample and allow for a more confident TAI determination. Framboidal pyrite is very abundant in this sample (Table 3). It's actually more abundant than the organics recovered. It may be indicative of marine influence. The sulfate reducing bacteria activity on organic matter in marine deposits reportedly can result in this type of pyrite. It is normally most common in hydrogen rich (reducing) marine source rocks. Marine palynomorphs (dinoflagellates and acritarchs?) are noted in this sample. Fluorescence of pollen and spores is generally lost in the approximate vitrinite reflectance range of 1.0% to 1.1%. Low palynomorph fluorescence is still easily visible in this sample, which is consistent with this general guideline (Table 2). Vitrinite and TAI values are generally divided into the following categories of thermal maturity: Immature: 0.20% to 0.60% TAI up to 2+ (2.3) Oil window maturity: 0.60% to 1.10% TAI 2+(2.3) up to 3+(3.3) Condensate and /or wet-gas window: 1.10% to 1.40% TAI 3+ (3.3) Dry gas window: 1.40% to 3.0 or 4.0% TAI 4-(3.7) and higher Dan Pearson For Humble Geochemical Services C • • • n a n 0 07-4480-178738 A o Well: Fido-1 a e Client ID: CP282487 °o Depth: 8173 ft. a a a n a a 0 0 0 a 0 0 a n Q O Q tl A d O Q O d q A O O O O O O b O A O Q Q 4 8 O Q P O O O b O U O O ~ O O O O O O R A A O d • TOC and ROCK•EVAL DATA REPORT ConocoPhillips, Noatak #1 HGS Wetl I Depth I Depth I Depth ~ roient I Sample ( TOC I " I St I S2 S3 I (°C) I %Ro I Y.Ro. I HI ` OI I S2fS3 I S77TOC I PI ~ Checks o Pyroprsm No. Name 07-4480.178738 Noatak #1 8173 8173 CP282487 swc 0.59 0.34 0.74 0.20 441 0.78 125 34 4 5R n 31 c tc ndfR2sh Note: "-1" indicates not measured or meaningless ratio `Tmax data not reliable due to poor S2 peak TOC =weight percent organic carbon in rock S1, S2 = mg hydrocarbons per gram of rock S3 = mg carbon dioxide per gram of rock Tmax = °C HI =hydrogen index = S2 x 100 / TOC OI =oxygen index = S3 x 100 / TOC S1ITOC =normalized oil content = S1 x 100 / TOC PI =production index = S1 / (S7+S2) Calculcated~oVRo = 0.0180 xTmax - 7.18 (Jarvie et al., 2001) Measured %Ro =measured vitrinite reflectance Notes: c =Rock-Eval analysis checked and confirmed Ic = Leco TOC analysis checked and confirmed Pyrogram: n=normal ItS2sh =low temperature S2 shoulder ItS2p =low temperature S2 peak htS2p =high temperature S2 peak f =Flat S2 peak na = pdnter malfunction pyrogram not available Humble Geochemica/ Servkes Division • f LOGL•_ORGANIC ~ IbG2:"HYbRCICAR330N~ j ~I 13iCFINE.~S ~- 1 7F00 I f Organic I Rich I I I I ~: 1 I I 8200 ^ 8400 ~ k^ i 0 JI 8800 { ~b ' PO'1'ENTiAL I 1 Excellent I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I - 00 50 10.0 D:: S -10 IS 10 i ~ 7'O(: (.rt.%) .. OII,1'OTiJ'11TAL (ST) oLmer. c.«+.wnl' otames. c~onww~aearlm _ __- Figure 1. Geochemical log of TOC, remaining potential (S2), kerogen type (HI), normalized oil content, and calculated and measured vitrinite reflectance. Humble Geochemical Services Division Geochemical Log ConocoPhillins_ Noatak #1 LOG 3: ORGANIC MA7TERTXPE -: ' 3,OG4: NOft11La7I7Fn0IL _ CONTENT ~': LOGS: GtLCt1LATF.n i11ATURLTY` -- -- LOCr6: MEASURED, MATURITY I I I -Gass M7xl 011 I Oll O ~I Y I Y I 01 Q I ~' 1 o 1 I I I I I ' i I m I t° t c 1 0'1 ~ 0 o N I I (f88/.) I. (IeC.) o:l y l m l ip ~ I I I 1 . 1 ~ I ~ N i f I. m l : 1 ~ I I I I I ~'. I E I ~ ~ i I- I ~_ I p I p I ~ I I I I ~ I E I I 1 I ~1 I N I 'NO l o ~ i I I I I b I I 1 I I I I I ~ I I i i m 1 U m I ~ I 1Cp 1 C [• I E I S I C I I I I I 1 I I I I i C I O 1 1 V I I I I I b I O I= 1 ~ I a I I I 1 I I I 1 I I I f J I W I ~ I Q I I l C I I I I I I 1 I I 6 I I 'I I I I g I I I a I I I N I I I I I I I 1 i 1 1 I I I I I I I I I I I I ~ I I I ~ 1 I I I I I I i I I i I I I I I I I I I I I' I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i I I i I I 1 I I I I I I I I I I I I I I I I I I I I I ~ I I® I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I i I I i I I I I I 1 ~ I i I I i I 1 i I I i I I I 1 I I I I I I I I I I I 1 I I I I I 1 ~ I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I i I I i I I I I I i I I i I I i I I I I I i I I I I I i I I ~ I I I I I I I I I I I I I I I I I I I I i I I I I I 1 I I 1 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I i I I i i I i I ' I i I '~ I I I I I I I I I 1 I I 1 I I 1 I I I I I I I I I I I I I ~ I I I I I I 1 I I 1 I I I I I I I I i i ' ~ ~ I I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I i I I 1 I t 1 I I i I I 1 I I i I I i I I I I I 1 I I I I I I I I I I I I I I I I I I ~~ ~ I I I I I I ~ ~ I I I I I I I I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I I t I I I I I I i I I I 1 I I i I I I I I I I I I I I I I I I I I I I I ~~ I I I I I I I I I I 1 I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I ~ ~~ I I I I I i 0 20n. ia) !AO 800:-._10 00. o~- SO .100,. is0 20 0-: 6 .2 :. 0.7 1.2~,. 19 2 2 0. 2 ,0.7. 12 1.7 i 2 ': IIYDROf;EN~INUEX (HI) NORMALIZED OIL CONTBN'C - I:ALCU L„1THD%Ro VlIRNITE @BF[.i'CTANCE olurN~G~eetreiYUl9 ~MOU elamtle G~od~wfiul Sw Ha: - _ alaau. ^-.-.._.•__• oNnde Gtorl~wnfo.leN wu • 18 0 ~, ~ 16 '~ a~ I U I 2 I ~ 14 M ~ I ~ F 12 i z '~ w ~" a 10 z 0 m ~ g a U O ' 0 6 z 4 z ~ ~ 0 ~ 0 0.5 1 i 1.5 2 2.5 3 3.5 4 4.5 5 TOTAL ORGANIC CARBON (TOC, vvf.%) (% Humble Geochemical Services Figure 2. Kerogen Quality Humble Geochemical Services Division • 1000 ~ 900 i'00 I v O t-- ~ V 600 I c~ I_ E 500 '~ X Z Z I W C7 400 o' r 300 i 200 KEROGEN TYPE ConocoPhillips, Noatak #1 800 Type f Oil -Prone Type I1(usu, marine) Dil Prone nniXea Type Ir / Irl Di1I Gas Prone Type llt Gas Prone 0 20 40 60 80 - 100 120 140 160 180 200 OXYGEN #NDEX {Ot, mg C02/g TOC) Humble Geochemical Services Figure 3. Kerogen type Humble Geochemical Services Division i~ .7 800. 700;> :. v 4 60n ~ O> ~ ' 000 (str: rr~ar~e} o ~ z I z w t7 ~ 400 0 _ ~ ~m ~n 300 IV#%X$d. Tyl}e ~I II/f. 6 '~i ~{~l{I ~s'~$ I~tfl~~~ 20th ~„ .>~. ~QOo 940 8dD KEROGEN TYPE and MATURITY ConocoPhillips, Noatak #7 _ • ... -~.. ~ - 0.55%VRo ~~~ Ty~te:l p~~.~~ C7il 1?rone (r~su. dacusfrlr~eJ 70~' ~;< U A 6QQ T}fpe i'I O Oit Frcarae ~ ~t~~u, ~ anarine} D ' ' ~I ~ Z j W C7 ~ 4Q0 0 r x 300 ' IV1Ixed:TYp f11 /it a ~i ~~~ ~ p MP/Y$tJ".A _t • Figure 4b. Kerogen Type and Maturity (Tmax calculated °!°VRo) Humble Geochemical Services Division • • • ConocoPhillips, Noatak #1 A All 0 0 /, 0 a x w 0 0 z z 0 0 U ~ 0 0 O a 0 0 0 0 i Humble Geochemical Services Division 380 430 480 530 580 MATURITY (based on Tmax (°C)) © Humble Geochemical Ser Figure 5a. Kerogen conversion and maturity (based on Tmax). • • • ,. 0.7 a x 0 0.6 z z0 0.5 U 0 0.4 O a „ ., ConocoPhillips. Noatak #1 Humble Geochemical Services Division 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00 2.20 MATURITY (calculated vitrinite reflectance from Tmax) © Humble Geochemical Services Figure 5b. Kerogen conversion and maturity (calculated %VRo from Tmax). _.~ ~~ ~ .-~ a 0 ca Q 07-4480-178738 Well: nom ~~ Glient ID: CP2$2487 ~p Depth: 8173 ft. a a q c~ gs a a cs n ct a a cr ~s 0 p q A t9 Ct~ G1 Q Ci q Q C} q Ct Q Q Q O A CY q p Ct q q ~s ~ ~ CY a a a cs p a Q a~ a • • • Noatak-1 V 40 35 30 25 20 15 10 5 0 Unknown Formation 8173' SWC Mixed Kerogen LL ^ Average %Ro = 0.92 Std. Dev. = 0.06 No. Pts. = 17 ^ Cave/Suppress? Vit. ^ Recyc/Oxid Vitrinite ^ Inertinite O ~. D< <o R~ O 1. 0< <o O O ~. D< <o ~b O ~. D< <o ~b O O/O R 07-4480-178738 O Humble Geochemical Services • • Table 1 Dispersed Organic Matter Thermal Alteration, Kerogen Type and Total Compositional Analysis ConocoPhillips ., % S ource Ma terial P rese rvation Re covery %Kerog en Com p. Vitri nite "' c ~ _r .c ~ E ~ c w ~ v 0 ~ aE v d ... a` ~ O g ' m « m 'c m v o o m D E n p c m c r x° « y $ c Y m Y m K d ~ c o LY ~ ~+ c ~ m « ` j n •c O ro E c ~ ~ a d ~ m ° w ~ a ` °' E o o j m a; w ¢ r d m v e 0 a c m ~ Z 5 c ar o `o m a o m A >. °o ~ o v t m m i, •. -C c ~ e m ,-° of ' ~ =y d m - T o 4 E c m o o O1 m o ie o d °o a~i 1O 'O m a"i d o = E `0 0 0 v 5 v ¢ LL x 3 v ¢ a t9 a o. > m e e ~ u Comments 07-4480-178738 Noatak-1 8173 CP2$24$7 swc OB, LB 2.7, 3 85 10 3 2 X X X 1 2 1 tr tr 96 27 1.05 17 0.92 dinofla ellates, acritarchs?, 1 s ore, rite in hi her abundance than kero en Color Abrbreviations: GLY Green-Light Yellow Y Yellow YO Yellow-Orange OB Orange-Brown LB Light Brown e Brown DBDG Dark Brown-Dark Gray DGBL Dark Gray-Black BLK Biack tr = tr 7AI Scale: 1=Unaltered 3+ or 3.5 1+ or 1.5 4=Strong alteration 2=Slight alteration 4+ or 4.5 2+ or 2.5 5=Severe alteration 3=Moderate alteration Humble Geochemical Services • • Table 2. Kerogen Fluorescence colors and brightness intensities (subjective determinations) ConocoPhillips • 0 = No fluorescence noted 1 =very low intensity G =Green 2 =low intensity Y =Yellow 3 =medium intensity O =Orange 4 =high intensity B =Brown 5 =very high intensity HGS ID Well Depth Client Type Pollen/Spores Amorphous Mounting Medium Name ft. Id. G Y O B G Y O B G Y O B 07-4480-178738 Noatak-1 8173 CP282487 swc 2 1 1 1 Humble Geochemical Services • • ~ Table 3. Pyrite types and abundance in kerogen ConocoPhillips 1 =very rare 2 =rare 3 =common 4 =abundant 5 =very abundant HGS ID Well Depth Client Type Pyrite types Name ft. Id. Finely Disseminated Euhedral Framboidal 07-4480-178738 Noatak-1 8173 CP282487 swc 4 2 5 Humble Geochemical Services • • • Table 4. Individual Reflectance Readings HGS ID 07-4480-178738 Well Name Noatak-1 De th1 ft. 8173 Indigeno All Data us Data 0.83 0.83 0.85 0.85 0.85 0.85 0.85 0.85 0.86 0.86 0.87 0.87 0.88 0.88 0.91 0.91 0.91 0.91 0.91 0.91 0.92 0.92 0.94 0.94 0.97 0.97 0.98 0.98 0.99 0..99 1.01 1.01 1.04 1.04 1.1 1.13 1.16 1.2 1.2 1.22 1.33 1.34 1.53 1.63 Average %R° 1.05 0.92 Standard Dev. 0.06 # of Points 27 17 Humble Geochemical Services ~ ConocoPhillips Alaska, Inc. FINAL WELL REPORT - MUDLOGGING DATA NOATAK #1 SECTION 22 - T12N - R5W, U.M. NORTH SLOPE BOROUGH, ALASKA Approved by: ~~NF\~~N~\a~ Compiled by: Brian O'Fallon Patrick Walker Date: 03/14/07 • Distribution:05/07/07 X05 -O`~/a ~ / 5~~~ Gor~ocA`P11x'itips ,-~. Noatak #1 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW .............................................................................................. 3 1.1 Equipment Summary ................................................................................................................. ... 3 1.2 Crew .......................................................................................................................................... ... 3 2 WELL DETAILS ................................................................................................................................ ... 4 2.1 Well Summary ........................................................................................................................... ... 4 2.2 Hole Data ................................................................................................................................... ... 4 3 GEOLOGICAL DATA ........................................................................................................................ ... 6 3.1 Lithostratigraphy ........................................................................................................................ ...6 3.2 Mudlog Summary ....................................................................................................................... ... 7 3.3 GAS(ISOTUBE) Samples (GAS BAG supplement numbered in parenthesis} ........................... . 12 3.4 Connection Gases ..................................................................................................................... . 14 3.5 Trip (Wiper) Gases ......................................................................................................•----......... . 14 3.6 Sampking Program !Sample Dispatch ....................................................................................... .15 4 PRESSURE /FORMATION STRENGTH DATA ............................................................................... .16 4.1 Formation Integrity/Leak Off Tests ............................................................................................ . 16 4.2 Wireline Formation Tests .......................................................................................................... . 16 4.3 Pore Pressure Evaluation introduction ...................................................................................... . 16 4.4 Pore Pressure Evaluation Conclusions ..................................................................................... . 17 4.5 Pore pressure evaluation .......................................................................................................... . 23 5 DRILLING DATA ............................................................................................................................... . 24 5.1 Survey Data ............................................................................................................................... . 24 5.2 Bit Record .................................................................................................................................. . 26 • 5.3 Mud Record ................................................................................................................................ 27 6 MORNING REPORTS ..................................................................................•-----•--............................ 30 Enclosures 2"/100' Formation Log (MD) 2"/100' Drilling Dynamics Log 2"1100' Gas Ratio Log 2"/100' LWD / Lithology Lag 2"/100' Pore Pressure Log • ~~iJl.,r~ 2 cao~r~ .~. Noatak #1 1 MUDLOGGfNG EQUIPMENT 8~ CREW 1.1 Eauipment Summary • Parameter Equipment Type f Position Total Downtime Comments QGM Agitator (Mounted in possum Possum belly belly} very small and Ditch gas Flame ionization total gas & 0 no jet system chromatography. to remove cuttin s. Effective Circulating Density From Sperry-Sun 3000' to TD 0 Calculated in ECD surface hole Hook Load / Wei ht on bit Pason WITS Feed 2 hrs 1043-1228' Mud Flow in Derived from Strokes/Minute and 0 Pum Out ut Mud Flaw Out Pason WITS Feed 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 s stem Ri watch Mudlogging unit DAC box In-unit data callectionldistribution 0 center Pit Volumes, Pit Gain/Loss Pason WITS Feed 0 Pum Pressure Pason WITS Feed 0 Pum stroke counters Pason WITS Feed 0 Pason Well Monitoring Pason computer networked in 0 Com onents Mudlo in Unit Rate of enetration Pason WITS Feed 60 min. Driller's error RPM Pason WITS Feed 7 hrs 8049-8193' Tor ue Pason WITS Feed 0 1.2 Crew Unit Type Double Unit Number - ML Mudloggers Years D ~ys Sample Catchers Years Days Technician Days Brian O'Fallan 18 28 Tom Novell 1 28 Steve Forrest 6 Patrick Walker 1 28 Dan Lee 1 21 Ramon Me'ia 1 7 ;' Years experience as Mudlogger '~ Days at we(Isite between spud and total depth of well ~~~~~ 3 Cor-~coPhillips ,, ~. Noatak #1 • 2 WELL DETAILS 2.1 Well Summary • Well: Noatak #1 API Index #: 50-279-20013-00 Lat: 74° 22' 46.9"N Long: 153° 07' 59.0"W Surface Co- 5998239'N, 1255233'W Field: NPRA Ordinates: NAD 83 Zane 4 Meridian U SEC 22 T12N R5W 2504 FNL 1932' FWL Borough: North Slope Primary Target Depth: MD: 8191' {-8066' TVDSS} State: Alaska TD Depth: 8425' MD / 8300' TVD Rig Name !Type: Kuukpik #5 /Arctic Double Rig Release Date 03/16/07 Primary Target: Alpine "C' Equivalent Area: NPRA Spud Da#e: 2111/2007 Ground Elevation: 104.5' Ground Completion Date: 3/15/2007 RT Elevation: 125' Completion Status: P&A Secondary Target: None De the Classification: Exploration TD Date: 3/1112407 TD Formation: UJU Days Testing: NONE Days Drilling: 2$ 2.2 Hole Data Maximum De th Mud Casing Shoe De th FIT Hole Section MD ~ft1 TVDSS ~~ TD Formation Weight ~PP91 Dev. o (inc) Coring 1 Liner MD (ft} TVDSS (ft} IPF~) Conductor 105 -20 Colville Gr. NA 0.06 NA 16" 105 -20 N/A 12 114" 3000 2875 Nanushuk 10.0 4.14 NA 9 5/8" 2987 2862 18.2 8 314" 8148 8023 Miiuveach 11.3 0.46 NA 7» 8146 8021 N/A 6118" 8425 $300 UJU 10.0 0.29 NA N/A N/A N/A NIA Additional Comments The Noatak #1 was spudded on February 11, 2007, and plugged on March 15, 2007. Total depth was reached on March 11, 2007 at 8425'MD. All drilling parameters, exclusive of gas, was acquired from Pason through a WITS feed. Epoch provided a WITS gas feed to Pason. Surface hole was drilled to 3000'. Gas readings were erratic due to cuttings accumulating in the possum belly and plugging up the base of the trap, especially through clay sections. The rig has very small possum bellies, and does not have a jet system to remove cuttings. Cuttings were removed by shovel. Cuttings would often accumulate at a ra#e to make gas detection unmanageable. The 8 s/." intermediate hole section was drilled to 8148'. Gas detection on only one occasion was restricted by accumulated cuttings in the possum belly, and quickly remedied. Pump #2 was lost at 7700', and drilling ~~~~H 4 Ca~oco'Phil~ips ~. Noatak #1 commenced for the remainder of the hole section using only pump #1. A Dowell pump was used periodically to assist, but interfered with LWD real time data. A trip at 7550' for BHA was made to enable gamma detection near to the bit for picking casing point. Drilling was slow without a motor with or without the Dowell pump. A section, 8084'-8100', was drilled with the Dowell pump and followed with a MADD pass for correlation, but the process proved awkward and time consuming. Drilling was resumed without the Dowell pump until casing paint was reached. The 6 118" production hole was drilled to completion at 8425' to provide approximately 100 feet of rathole below the base of the objective Alpine equivalent. Mud lasses began at 8188' at the top of the Alpine equivalent when drilling with a 9.9 ppg mud. Flow rates were reduced, and mud weight was reduced to 9.6 at 8225' and later 9.5, but losses continued while drilling, though static with the pumps off or at very low pump rates. At total depth, mud weight was raised to 10.0 due to the well flowing with a 9.5. Some minimal fosses occurred while tripping and logging with the 10 ppg mud. Three wireline logs were run, DSI and PEX logs, and sidewall cores. A decision to plug and abandon the well came after examination of the sidewall cores. Epoch was released before plugging procedures were completed. • C] ~ ~PC~CH 5 Conoao`Phillips ~. Noatak #1 3 GEOLOGICAL DATA 3.1 Lithostratipraphy • LWD tops refer to provisional picks provided by the Wellsite Geologist. PROGNOSED LWD PICK FORMATION MD (ft} TVDSS (ft) MD ft} TVDSS (ft} Base Permafrost 875 750 860 735 Nanushuk 1325 1200 1405 1280 Torok 3225 3100 3387 3262 HRZ 7525 7400 7389 7264 Base HRZ NIA N/A 7532 7407 MiluveachlLCU 7755 7630 7642 7517 Jurassic Alpine Equiv Sands 8275 8150 8191 8066 UJU 8405 8280 8320 8195 TD 8925 8800 8425 8300 C~ ~PC)CH Conocv'~Phillips . ~. Noatak #1 • 3.2 Mudlog Summary Surface to Base of Permafrost {Colville Group) First Returns 105' to 860` MD (-20` to 735' NDSS} Drill Rate ftthr} Tots! Gas {units } Maximum Minimum Avera a Maximum Minimum Avera e 1029 5 54 17 0 1 The Noatak #1 drilled out of the conductor at 105' RKB into a massive well sorted slightly conglomeratic sand to 150', followed by interbedded, clay, silt, sand and sandstone, coal and carbonaceous matter, and minor ash fall tuff to 550'. The remaining 300' is less carbonaceous with no coal ar ash. Sands below 150' are medium to fine and fine to very fine grained, mostly subanguiar to subrounded, 60- 80% quartz, and 40-20°t° gray to dark gray to green to tan silicates and lithics. The quartz grains are often stained a yellowy to orangish yellow color. The sands are grain and matrix supported, and sandstone friable to moderately consolidated, grain supported, with slight siliceous cement, and locally calcareous cement. Clays are medium light to medium gray, occasionally with a light brownish to brownish hue, soft and soluble, variably silty to sandy, grading to silt and sand, with traces to slightly scattered silts of carbonaceous matter, and occasional organic clay. Background gas increased from 0 to 2 units through this section. Gas was recorded as high as 17 units in a thin coal bed, all methane. Base of Permafrost to #op Nanushuk (Colville Group) 860' to 1405' MD (735' to 1280' NDSS) Drill Rate (ft/hr) Total Gas {units } Maximum Minimum Avera a Maximum Minimum Avera e 159 9.9 81 5 1 2 Continuing in the Colville Group, the iithology is the same as the interbedded sequence in the lower 300' of the permafrost, except the basal 70' above the Nanushuk. The quartz grains, however, no longer have a yellowy stain. The base features a very light gray, greasy ash fall tuff, massive to interbedded with claystone. All recorded gas, up #0 5 units, was methane. Nanushuk to top Torok 1405' to 3387' MD (1280' to -3262' NDSS} Drill Rate (ftlhr} Total Gas {units } Maximum Minimum Avera a Maximum Minimum Avera e 696 4 68 200 0 32 The Nanushuk is notably very clayey, with interbedded clayey sand, claystone, and clayey siltstone, often gradational The upper part is sandier, and the lower Nanushuk dominantly claystone. Sands are a medium light gray to medium gray, with locally faint brownish or olive to greenish hues. Grains are very fine to fine, fine to medium, or fine to coarse lower, typically angular, to locally subangular to subrounded especially coarser fraction, poorly to moderately sorted, matrix and grain supported, with typically abundant intergranular clay even in grain support. Composition ranged from 65-80°lo quartz, and 35 to 20°~ dark brown to black to gray to dark gray to green to tan lithics, including cafion lithics, silicates and [~ ~Pfl~H 7 COt'1000~11~~ipS A~Ska, hic. Noatak #1 chert, chlorite, siderite, and other lithics. Chlorite and sideri#e are more common in upper sands, as well as some scattered aggregate pyrite. Sands are soft with soluble matrix, and apparently loosely consolidated, with occasional friable to moderately consolidated calcareous sandstone streaks and thin beds. claystone and siltstone is also medium light gray to medium gray, with same very faint brownish hues where slightly organic, and rare brownish gray organic clays. Grains are typically angular and dominantly silty to very fine grained quartz and silty to very fine grained. Trace to slight silts and flakes of carbonaceous matter are pervasive. Gas peaked at 200 units, with ethane first detected at 1460', and iso-butane ap{~aring anomalousEy at 16~'. The same phenomenon occurred at approximately the same depth on the 2 Kokoda wells, detecting iso- butane wi#houtdetecting propane, or the heavier gases, normal butane and pentanes. Some small increases over background gas were detected in sandy intervals, but no oil indicators were absented. The ethane and iso butane gradually diminished after peaking at 1635'. Peaks De th TG C1 C2 C3 C41 C4N C5t C5N 1524 97 17320 36 1635 66 8645 1505 335 1770 200 32841 647 907 2208 108 19131 90 47 2455 103 19157 28 26 2518 93 15736 47 29 Torok to tap HRZ 338T to 7389' MD 13262' to 7264" TVDSS) Drill Rate {fti'hr) Total Gas (units ] Maximum Minimum Average Maximum Minimum Avera e 278 5 83 222 1 24 The Torok includes claystone, siltstone, sandstone, and minor shale, with claystone the dominant litholagy. The Torok interval from approximately 3700' to 5790' was especially dominated by claystone, white the first 300' and the lower 600' had some bedded sandstone and sand, including oil bearing sands with shows, beginning at 7045' to the base of the Torok. The claystones are medium to dark gray, often with brownish hues to brownish gray, soluble, soft, and mushy to pasty in samples, to moderately soft and subblocky with a slight flaky cuttings fracture. The clays are characterized by overall slight but pervasive carbon silts and flakes, micro micas, and micro pyrite, and scattered thin carbonaceous partings. The flakiness is due to the planar orientation of the carbon matter, micas, and pyrite rather than structure. Pyrite also occurs as traces of silt to fine grained sized aggregate scattered throughout. Traces to slight loose silts to very fine sand grains, mostly quartz, is atso pervasive, and it is estimated the claystone is overall slightly silty to sandy, and commonly gradational to, or interlaminated to interbedded with siltstone, sand, and sandstone. The claystone is also non calcareous except some loose calcite and calcite (columnar) fill below 5600'. Silts are dominantly quartz and carbon matter, and siltstone is generally of similar structure and composition #o the claystone except with increases in silt sized quartz grains. As siltstone grades to sand and sandstone, grain composition is similar to that of sand or sandstone, but with higher percentages of quartz. Sandstone was very fine to fine grained, mostly angular to subangular grains, mostly poorly to some moderately consolidated, with clay and slight calcite matrix. Grains included 70-90°k quartz, and 30-10°k ~PC~CH 8 conocoPtrt~ips .~. Noatak #1 mostly carbon and minor other "argillaceous" lithics, and minor silicates, some weathered, including glauconite, micas, and feldspar. Same cleaner sands had higher percentages of quartz and fine grains, locally some subrounded grains, overall a very slight increase in glauconite, and were dominantly grain supported with a white matrix. As sands graded to dominantly very fine grained and siltstone, the matrix became more argillaceous with same matrix support from light brownish gray clays. Occasional carbonaceous partings were also observed. Porosity was generally very poor to poor, even in the cleaner sands. Propane increased from #race amounts at the top of the Torok, until a full suite of gases, methane through pentane, was recorded at 3575'. Propane, butane, and periodically pentane were subsequently recorded in small to trace amounts despite relatively low background gas. Significant quantities of all gases occurred with gas peaks in the lower sandstone intervals. Oil was present in the lower Srookian sands but fluorescence and cut were relatively weak Shows were considered mostly poor to occasiona{ly fair. Peaks • De th TG C1 C2 C3 C41 C4N C51 C5N 7064 104 15568 1574 1020 199 284 89 69 7096 122 18042 1964 1265 221 343 97 75 7205 141 20259 2751 1947 241 546 123 130 7241 222 24695 3249 2434 305 752 168 197 7373 116 16045 1474 1117 120 365 69 85 HRZ to Base HRZ 7389' #0 7532' MD {7264' to 7407' TVDSS} Drill Rate (ftlhr) Total Gas (units Maximum Minimum Avera a Maximum Minimum Avera e 102 7 39 120 32 81 The HRZ includes hot shales and some minor apparent ash fall tuff. The shales are medium dark gray to dark gray, with brownish hues, slightly firm to firm, and characterized by laminations of slightly to some moderately organic clays separated by moderate to abundant remnant to very thin partings of carbonaceous matter. The carbon matter is often partially to occasionally completely replaced by micropyrite. Some thinly interlaminated argillaceous siltstone and very fine grained sandstone otxurs just below the Torok. The shales exhibit some spotty pinpoint effervescence in HGt_ to slightly calcareous, diminishing lower. Approximately 2% of the two 30 foot samples from 7410-7470' was what appeared to be ash fall tuff. The ash was light bluish white to yellowish gray to olive gray, the white ash appearing as mastfy chalky and soft, and the yellowish to olive grays and occasionally the bluish white had a greasy luster, splintery habit, were slightly firm, and had scattered traces of micropyrite throughout. The ash was non calcareous. Gas ranged from 32 to 120 units, and included methane through pentane. Some outgassing was observed on the cuttings. While not fluorescing, the shales had a pervasive light bluish white instantaneous to slow straw cut. ~PO~H 9 Canooo`Pi~illips .~. Noatak #1 U Base HRZ to top MiluveachJl.CU 7532' to 7642' MD (7407 #0 7517 TVDSS) Drill Rate (ft/hr) Total Gas units ) Maximum Minimum Avera a Maximum Minimum Avera e 153 2 24 92 9 28 This thin section is dominantly shale, grayish black to brownish black to yellowish brawn, and distinguished from the HRZ by the lack of distinctive micro partings of carbonaceous matter or residue. Some of the darker shales overall appear to be more organic than the HR2, and same "hot shale" is still seen on the gamma response. Trace to moderate micro pyrite replacement is pervasive, but less planar and more scattered, and the scatter appears also to include micro micas. The shales appear to be interlaminated with some soft siltyJvery fine sandy brownish gray to gray claystone, with lightly scattered up to sift sized pyrite. The shales are non calcareous. No fluorescence but a bluish white slight instantaneous and slaw straw cut was observed. LCU to top Jurassiic Alpine Equivalent Sands 7642' to 8191" MD (7517" to 8066' TVDSS} Drill Rate (ft/hr) Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 208 2 24 79 3 38 The LCU appears to have a characteristic "yellowish brown" hue, with colors from dusky yellowish brown to moderate yellowish brown to brownish gray to pale yellowish brawn. Occasional carbonaceous shales grade to a dusky brown. Slight to moderate micro pyrite, micro mica, and mica are scattered throughout, often exhibiting a resinous to velvety texture. The shales are mostly non to slightly silty, occasionally grading to or with interbedded siltstone, but become sillier and sandier {very fine grains} towards the base, grading argillaceous sandy siltstone, especially in the "red zone". Trace to very slight very fine to medium floating quartz grains are pervasive throughout, with rare local sand clusters indicating thin sandstone streaks. A trace of cuttings were hard and siliceous. Below 8120', glauconite is common especially in the grainier shales and siltstone. Cuttings habit was subplaty to subspiintery in the shales with common incipient to visible fissility, to grading claystone. siltstone and silty shale tended to be subblocky to subplaty with irregular cuttings fracture. It should be noted that despite same very high gamma, overall trending higher downward, very little carbonaceous shale was observed in the LCU. Jurassic Alpine Equivalent Sands to top UJU 8191' to 8320' MD (8066' to 8195' TVDSS} Drill Rate (ftlhr) Total Gas (units ) Maximum Minimum Avera a Maximum Minimum Avera e 179 5 41 1324 63 446 The sandstone is dark greenish gray to olive gray, with fine to very 1•rne and locally some medium lower grains, subangular to angular, moderately to moderately well sorted, moderately to well consolidated, with a slight siliceous and trace calcite cement, to rarely with a slight calcareous cement or slight calcite in the matrix. The composition is 30-60% quartz grains, 30-60°~ glauconite, and 10-60°~ dark brown argillaceous matrix and clasts. The glauconite is largely altered and appears as grayish green pseudo grains to a greenish soluble support matrix. Some loose grains and small clusters observed in the samples are ~PC~CH 10 Conoct Phillips . ~. Noatak #1 dominantly quartz with minor argillaceous matter, with the glauconitic matter probably washed out. Non to very poor visible porosity appears in part the result of the breakdown of the glauconite into a support matrix. High gas throughout the interval peaked at 1324 units, and a full suite of gases, methane through pentane were recorded in significant quantities. There was no visible oil, no oily odor, and traces of very faint yellow fluorescence could be attributed to mud properties. The samples did however cut, a very slight yellow white instantaneous cut, followed by a slight diffuse green yellow cut, and trace to slight yellow white straw cut. A trace of the visible very poor pin point porosity had slow bleeding gas. Overall, shows were considered very poor to poor. Peaks • De th TG C1 C2 C3 C41 C4N C51 C5N BGG 20 2014 254 118 18 31 6 8 8190 223 33547 4972 2090 241 377 $8 86 8205 567 101021 4797$ 17043 1821 2906 635 650 8232 205 30911 5406 2907 387 638 170 171 8266 390 126293 29261 10602 9201 1939 442 408 8295 1300 268275 97104 57428 7911 13378 3222 3327 8310 575 192577 48041 47616 3391 6024 1371 1696 UJU to Total Depth 8320' to 8425' MD /8195' to 8300' TVDSSI Drift Rate ftlhr Total Gas {units ) Maximum Minimum Avera a Maximum Minimum Avera e 161 8 23 891 43 91 The UJU appears abruptly as a grayish brown to yellowish brown to brownish gray shale and siltstone in sharp contrast to the overlying sandstone. The 8310' to 8320' sample contained some very firm dense sub platy quartzitic coarse siltstone of a yellowish brown color, but succeeding samples were mare argillac~ous, mostly shale, and slightly firm to firm with wedge to sub platy to flaky habit. Some resinous texture was due to scattered micro pyrite. C~ ~P~~H 11 ConocoyPli~llips ~. Noatak #1 3.3 GAS(ISOTUBE} Samples (GAS BAG supplement numbered in parenthesis} 1 unit = 0.05°~- Methane Eauiva{ent L._J Sam {e De th Units C1 C2 C3 iC4 nC4 iC5 nG5 # (feet} 1u=0.05°~ M.E. (ppm) (ppm) (ppm} (ppm} (ppm} (ppm} (ppm} 1 500 1 127 0 0 0 0 0 0 2 750 1 250 0 0 0 0 0 0 3 1000 2 332 0 0 0 0 0 0 4 1250 2 398 0 0 0 0 0 0 5 1500 78 13871 47 0 0 0 0 0 6 1724 54 9223 555 0 122 0 0 0 7 2000 41 7627 66 0 41 0 0 0 8 2298 57 10551 40 0 26 0 0 0 9 2500 62 10973 16 0 14 0 0 0 10 2750 40 8029 8 0 0 0 0 0 11 3020 16 2589 0 0 0 0 0 0 12 3255 37 6830 19 0 0 0 0 0 13 3500 71 11973 70 16 3 5 0 0 14 3750 19 3583 20 0 0 0 0 0 15 4000 30 5577 54 22 3 4 0 0 16 4250 35 6220 76 25 5 7 0 0 17 4500 22 4300 55 23 5 5 0 0 18 4750 20 4454 51 15 5 3 0 0 19 5000 13 2793 31 13 3 1 0 0 20 5250 12 3123 36 22 7 3 0 0 21 5500 14 3345 46 27 12 6 0 0 22 5750 26 4898 87 61 18 15 8 3 23 6000 22 3818 83 62 20 21 9 4 24 6250 15 3169 71 42 15 10 4 2 25 6500 13 2672 91 52 14 10 5 2 26 6750 29 4221 246 148 47 40 10 4 27 7000 16 2243 203 139 33 47 12 6 28 7063 102 15248 1565 1018 198 283 89 69 29 1 7096 122 18042 1964 1265 221 343 97 75 30 2,3 7240 222 24695 3249 2434 305 752 168 197 31 7250 41 3155 492 565 98 245 65 79 32 7314 62 8411 985 790 $9 261 54 67 33 4 7360 88 12059 1465 1155 126 368 80 94 34 5 7372 112 15506 1963 1469 155 472 87 104 35 6 7420 120 16739 1951 1396 147 477 93 128 36 7500 90 10990 1541 1324 155 498 99 124 37 7750 37 3674 554 508 90 175 44 54 38 8000 38 3964 713 605 111 209 58 71 39 7 8160 15 1597 194 93 12 30 12 7 40 8 8170 18 1904 230 108 23 38 12 15 41 9 8180 20 2014 254 118 18 31 6 8 42 8190 DISCARD D UE LAG ADJUSTM ENTS 43 10 8188 87 10664 1339 539 65 111 32 16 44 11 8202 DISCARD D UE LAG ADJUSTM ENTS ~PC~CH 12 Conoco'Pttuilips .~. Noatak #1 • • Sam fe De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1u=0.05°~ M.E. (ppm) (ppm) (ppm) (ppm) {ppm) (ppm) {ppm) 45 12 8190 223 33547 4972 2090 241 377 88 86 46 13 8195 546 195012 37913 16114 1686 2613 535 532 47 14 8205 567 101021 47978 17043 1821 2906 635 650 48 15 8225 C.G. 750 225576 45551 20182 2114 3309 684 640 49 16 8232 205 30911 5406 2907 387 638 170 171 50 17 8243 260 49463 9589 4876 632 1031 281 333 51 18 8253 350 89091 17080 8185 1004 1588 421 472 52 19 8266 390 126293 29261 10602 1201 1939" 442 408 53 20 8280 245 39716 6906 3431 423 709 171 151 54 21 8295 1300 268275 97104 57428 7911 13378 3222 3327 55 22 8298 670 219219 57580 32500 3874 6783 1575 1645 56 23 8310 575 192577 48041 47616 3391 6024 1371 1696 57 24 8317 122 10172 2127 1471 292 515 195 188 58 25 8330 85 7100 1374 858 177 357 144 164 59 26 8360 50 5235 1104 645 127 275 107 127 60 27 8375 70 9345 1681 899 178 362 136 163 61 28 8425 54 7150 1427 694 106 256 104 101 EPOCH 13 GonocoPhiOips . ~. Noatak #1 3.4 Connection Gases 1 unit = O.Q5°lo Methane Eauivalent Depth Gas over BGG feet units 7162 30 7345 5 7407 20 7469 10 7532 10 8166 14 8193 70 8225 510 8287 740 8317 850 8349 1250 8381 1060 8411 780 3.5 Trip (Wiper) Gases 1unit = 0.05°~ Methane Equivalent De th Tri to Gas Downtime feet feet units hours 230 0 0 10 1542 460 49 3.5 3000 220 129 15 3000 0 8 29 RIH w/CSG 3576 2950 64 9 4516 3576 92 6 6025 4515 76 7.75 7550 0 30 44 8148 7550 21 1.75 8148 0 215-297 42 RIH wlCSG • ~PC~GH 14 COI'1000~11~~1pS Alaska, tnc. Noatak #1 • • 3.6 Sampling Pros~ram /Sample Dispatch Set Ty e t Pa ose Fre uency Interval Dls atched to CPAI A Unwashed Biostratigraphy 30' 105' - 8148` MD ABV 100 St 102 h Set owner: CPAI 10'(X3) 8148 -8425' MD e AK 995 2ve Anchaaage Attn: D. P o'ski Unwashed Biostratigraphy 30' 105' - 8148` MD CPAI Bayview Geologic Faality B Set owner: Pioneer 10' 8148 -8425' MD 619 East Ship Creek Ave Ste 14 Resources Anchorage, AK 99501 Attn: D. P 'ski 265-6340 CPAI C Unwashed Biostratigraphy 30' 105' - 8148` MD Bayview Geologic Facility 619 E k A 14 t Shi C St Set owner: Anadarko 10' 8148 -8425' MD as ree ve p e Anchorage, AK 99501 Attn: D. P o'ski 265-6340 Washed, screened 8 30' 105' - 8148` MD CPAI Bayview Geologic Faality D dried Reference Samples 10' 8148 - 8425' MD 619 East Strip Creek Ave Ste 14 Set owner: CPAI Anchorage, AK 99501 Attn: D. P 'ski 265-6340 Washed, screened & 30' 105' - $148` MD CPAI Bayview Geologic Facility E dried Reference Samples 10' 8148 -8425' MD 619 East Strip Creek Ave Ste 14 Set Owner: CPAI Anchorage, AK 99501 Attn: D. P o'ski 265-6340 Washed, screened & CPAI F dried Reference Samples 30' 105' - 8148` MD Bayview Geologic Facility 619 E t Shi C k A St 14 Set owner: Pioneer 10' 8148 -8425' MD as p ree ve e Anchorage, AK 99501 Resources Attn: D. Przywojski 265-6340 Washed, screened $ 30' 105' - 8148` MD Bayview Geologic Facility G dried Reference Samples 10' 8148 -8425' MD 619 East Ship Creek Ave Ste 14 Set owner. AOGCC Anchorage, AK 99501 ' Attn: D. P ski 265-6340 Washed, screened & 30' 105' - 8148` MD CPAI Bayview Geologic Faality H dried Reference Samples 10' 814$ -8425' MD 619 East Ship Creek Ave Ste i4 Set owner: BLM Anchorage, AK 99501 Attn: D. P ' ki 265-6340 Washed, screened 8~ 30' 105' - 8148` MD CPAI Bayview Geologic Facility I dried Reference Samples 10' 8148 - 8425' MD 619 East Ship Creek Ave Ste 14 Set owner: Anadarko Anchorage, AK 99501 Attn: D. P o'ski 265-6340 Isatubes (Table Sec 3.3) 250'{31) 500' - 8000` MD Routine intervals and Peaks(7) 7063' - 7420' MD Isotech Laboratories, [nc. J significant peaks above 10-30'{23) 8160' -8425' MD [L 61 21 Champaign background {TOTAL = 61) , Set owner: CPAI Cali bond as ba S g g Peaks {6) 70~' - 7420' MD gaAl yview Geologic Facility K Supplement to Isotubes in 10 -30 {22) , - 8160 8425 MD fii9 East Ship Creek Ave Ste 14 A A 95 1 target intervals nchorage, K 9 0 Attn: D. Przywojski 285-6340 J Onsite Samplex Samples 10' 10 trays random To on-site geologist Sample frequency was locally altered according to drill rate constraints and zones of interest. ~1 ~P~}GH 15 Gonoco'Pfiiflips .~. Noatak #1 r: 4 PRESSURE /FORMATION STRENGTH DATA 4.1 Formation lntec~rity/Leak Off Tests MD TVDSS FIT 1 LOT FORMATION ft ft EMW 3000 2875 18.2 Nanushuk 8148 8023 not re uired Miluveach E uivalent mud wei ht EMW is calculated from rata table. LOT {Leak Off Test) in bold italics. 4.2 Wireline Formation Tests None Conducted. 4.3 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pare pressure trends during the drilling of a well; Background Gas (BG} Resistivity (RES) Hole Conditions {HC} Wiper Gas (WG) Quantitative Methods Trip Gas (TG) Mud Weight (MW) Connection Gas (CG} Pore Pressure (PP) D exponent (DX) Corrected D exponent {DXC) Equivalent Circulating Density (ECD} The primary indicators used far pore pressure evaluation were gas trends relative to MW and ECD, including increases in BG, appearance and trends of CG, and magnitudes of TG and WG. Regional pore pressure trends from sonic data, provided by ConocoPhi!lips, and surface manifestations of hole conditions were also considered. As a reference, PP is calculated initially with a formula provided by Epoch, and than modified using the indicators described above, and DXC and RES data. The formula uses DX, ECD, and BG: PP =ECD - (1-{{.001 *BG)+{0.052"DX))) The formula has limitations such as it doesn't allow for a PP more than 1 ppg less than ECD, BG must be differentiated from show gas and gas carried #rom over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping establish a PP range, when establishing trends, as with DXC data, with data points in shale intervals. DXC and RES data were plotted versus depth for each hole section. A normal trend [ine was established through shale and claystone intervals an the DXC plot, although DXC data for sandy {including show} intervals is not excluded from the plot. ECD, GAS, and PP were plotted on the RES chart for reference and illustration. RES and ECD data were provided by Sperry Sun, except ECD was nat measured on surface hole and was calculated. Pore Pressure is evaluated below for each hole section. [~ EPC)CH ,~ GonoaoyPt~illlips . ~. Noatak #1 • 4.4 Pore Pressure Evaluation Conclusions 1 }Surface Hoie -12.25" (105' to 3000'} Pore pressure is estimated to range from 8.7 to 9.1 ppg in the surface hole. Surtace hole was drilled with a 10.0 to 10.2 ppg mud, with ECD calculated at approximately 10.2 to 10.4 ppg. A lack of CG indicates PP remained well below MW and ECD. Pore pressure is estimated at a normal gradient of 8.7 ppg above the base of the permafrost and through the Nanushuk, and to have increased to approximately 9.1 below the base of the permafrost while gradually tapering off to 8.7 ppg just above the Nanushuk. These estimates are consistent with sonic estimates which indicate an increase in pore pressure below the permafrost and otherwise normal gradients. DXC and RES data appear to loosely support these estimates. 2) 8.75" hole (3000' #0 8148') Pore pressure is estimated to vary from 8.7 ppg to 9.6 ppg. iv1W varied between 9.7 and 10.1 from 3000' to 7283', when MW was increased from 9.9 to 11.0 in anticipation of the HRZ. MW varied from 11.0 to 11.3 from 7283' to 8148'. ECD was measured by Sperry Sun, and varied from 10.2 to 12.2, peaking in the HRZ. Connection gas was observed only after drilling into oil bearing Brookian Sands and a degassing HRZ, and were of short duration, low amplitude relative to background, and gas always returned to background. Connection gas was probably due in part to supercharging of tight gaseous zones while circulating with high ECD, and release of gaseous mud back into formation during connections, and in • part to the solubility of the HRZ clays in the mud system. A high ECD also suggests HRZ breaking down into the mud system. it is estimated that pare pressure was always considerably less than MW, especially above 7000', above the oil bearing sands. The negative cut back observed in DXc versus Depth plot is a function of the fithology, with the organic rich HRZ having a low density. Below 7000', a pore pressure trend is suggested from velocity results from ConocoPhiilips, lower and downward trending DXC, and downward trending RES. Some relatively high TG when running in with casing also supports these conclusions. Little gas was observed when circulating volume above the casing shoe, and only 75 units at 7020' after first breaking circulation below the shoe. While washing in with casing from 8081' to 8148' due to fill, bottoms up gas was observed after picking up casing joints at 8085' {297u) and 8127' {215u), and again after downtime at 8148' {257u), with each lag slightly longer, and each peak of less duration than the previous peak. Another, sharper peak of 288u {8148') was observed during cement procedures after 4 hours of downtime. It is believed that time, the breakdown of shale, casing surge, and an increase in pore pressure may ai! have contributed to the gas. The combination of data suggests a relatively normal gradient to 7000', with PP varying from 8.7 to 8.9, and a slight upward trend from 8.7 to 9.6 beginning in the Brookian Sands down to casing point. 3} 61/8" hole {8148' to 8500') Hole conditions indicate pore pressure in this section to have peaked between 9.5 and 10.0. High connection gases and the well flowing with a 9.5 mud indicate pressures above 9.5, while mud losses while drilling and with a 10.0 static mud indicate pressures under 10.0. Pore pressure is estimated to have peaked at approximately 9.8. • ~ EPflCH 17 Conoco`Phillips Alaska, Inc. Noatak #1 DXC vs DEPTH -12.25" ^ DXC • 8.7 PPG C] ~~ ~I~oc,H • • 18 0 500 1000 1500 2000 2500 3000 3500 100 GonocoPhillips Alaska, Inc. Noatak #1 DEEP RES and GAS vs DEPTH -12.25" S '_• ~•~ • • BASE Pig-RMAfjftOST @ 860` • •t~ ~. : 10 I.• 9518° CASING DEPTH @ 3040' 1~ 0 _ ~ 500 1000 1500 2000 ~ EPOCH • • DP ~ GAS(ME)+1 x ECD ~C PPG 2500 3000 3500 19 r. COI'lOCO~'1l~~iPS Alaska. Inc. Noatak #1 DXC vs DEPTH - 8.75" 2 1 . ~. ^ ~ i ~' ^ ^ ^ ^ • Remove Mud Motor @ 7550' Casing Depth @ 8148' o +-- 3000 . ^ • ^ ~ ^ ^ ^ ~ ^ ^ ^ ~ Inc MW s.g to- 11.0 @ 7282'- ' ~ • ~Rr@ 738s' ~ ^ i • ~ ! Torok a~ 3387' ~ • ' r ^ ^ : ^ ^ ^ ~^ ^ ^ ~ ^ ^ ^ ^ ^ ^-___ ^ ~~L ^ ^ ~ 4000 5000 6000 7000 8000 E~ EPOCH ~ ~ ^DXC • 8.7 PPG 9000 • ~o ConocoPhillips Alaska, Inc. Noatak #1 DXC vs DEPTH - 6.125" 2 1 0 -E- 8100 Alpine Equiv @ 8187' ^ • ti ^ ^ ^^ ~ ^ ^ ^ ~ ' Total Depth ~ &425' ~I~i ^ . T ^ ~-^ tir^ ^ ~ ~i ~^ ^ • • ~^ ^ ~ ~•r ^ ^^ r ^ ^ • ^ ^ • ^ ^ •^ ^ ~ ^^ ti ^ •^ •~ •^ • ~~ ~ • ^ ^ ^ ^ ^ ~ ¢ • ^ ^^ ~ ^ ^ ~ ^^ ^ ^ ~ • ^ ^ ^ ^ ^ ^• ^ ^ ~ ^ ^ ^ ^ ^^ 8150 8200 8250 8300 ~~ EPOCH • 8350 8400 8450 ^DXC • 8.7 PPG ~J 21 ~ ~ O O O O N O O N O w 0 0 w w 0 A O O A O ~ O O O ~~ • ~ ~~ ~~~ • ~ ~• .~ . ~ ~~ `• ~ I • •r .• .. .• •.. . • .• • ~ r• .• ~. • „ .. • ~ • ~ • • ~ ~ ~ • .• ~: ~ ~~ ~• ~~ • • • ~ I ~` ~ ~ ~ . 'U C7 r ~ c~v~ m v x n w m z -v ~ ~ ~ ~ ( _ ~~ ~ ~~ N ConocoPhillips .~~. Noatak #1 4.5 Pore pressure evaluation ti F Primary Secondary Interval To s Pare Pressure (EMW) T d Source of orma on Interval Lithology (%) Lithology (%) MD (ft) TVDSS ft) Min (pp) Max (ppg) Trend ren Indicators Quantitative Estimate Permafrost CI st/Sltst 50% Sd/Sst 40% 105 -20 8.7 8.8 Flat BG RES, DXC Base Permafrost CI st/Sltst 60°~ Sd 30% 860 735 8.7 9.1 Sli U -Dn BG,WG,TG RES, DXC Nanushuk CI st/Sltst 70% Sd 30°~ 1405 1280 8.7 8.7 Flat BG,WG RES, DXC Torok Formation CI st/Sh 70% Sltst 20°~ 3387 3262 8.7 8.9 Flat BG,WG RES, DXC Torok ob'ective Sst 40% CI st/Sh 50°~ 7038 6913 8.7 $.9 Flat BG,CG RES, DXC HRZ Sh 95% Ash 2% 7389 7264 8.9 9.2 Sli U BG,CG RES, DXC LCU Sh/CI st 80% Sltst 15% 7639 7514 9.2 9.6 Sli U BG,WG,TG RES, DXC U Jur AI ine C Sst 80% CI st/Sh 15% 8187 8062 9.6 9.7 Flat BG,CG,HC RES, DXC UJU Sh 70°k Sltst 30% 8320 8195 9.7 9.8 Sli U BG,CG,HC RES, DXC Total De th 8425 8300 9.8 9.8 NOTE: Clyst = Claystone/Clay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Sst =Sandstone, Ash =Ash Fall Tuff C~ EPOCH 23 ~ ~ ~ Gonvco`Pl~Ilips . ~. Noatak #1 5 DRILLING DATA 5.1 Survey Data Measured Depth Incl. {°} Azim. {°~ Tn~e Vertical Depth Northings {ftj Eastings {ft) Vertical Section Dogleg Rate 20.50 0.00 0.00 20.50 0.00 0.00 0.00 TiE-IN 132.13 0.06 105.79 132.13 -0.02 0.06 -0.02 0.06 220.13 0.19 314.99 220.13 0.07 0.00 0.07 0.27 315.13 0.32 340.02 315.13 0.43 -0.20 0.43 0.18 407.65 0.50 329.68 407.65 1.02 -0.49 1.02 0.20 528.48 0.28 306.43 528.47 1.65 -0.99 i .65 0.22 715.93 0.29 345.63 715.92 2.38 -1.48 2.38 0.10 901.75 0.40 13.25 901.74 3.46 -1.45 3.46 0.10 1083.08 0.17 338.66 1083.07 4.32 -1.41 4.32 0.15 1277.84 0.26 1.66 1277.82 5.04 -1.50 5.04 0.06 1461.68 0.20 345.00 1461.66 5.77 -1.57 5.77 0.05 1650.28 0.56 349.96 1650.26 7.00 -1.82 7.00 0.19 1906.09 0.14 342.00 1906.06 8.52 -2.13 8.52 0.17 2041.07 0.09 204.38 2041.04 8.58 -223 8.58 0.16 2215.43 0.06 195.79 2215.40 8.37 -2.31 8.37 0.02 2405.08 0.06 89.06 2405.05 8.27 -2.23 8.27 0.05 2595.64 0.06 177.71 2595.61 8.17 -2.12 8.17 0.05 2781.77 0.09 184.48 2781.74 7.93 -2.13 7,93 Q01 2920.21 0.14 76.36 2920.18 7.87 -1.98 7.87 0.13 3027.23 0.36 2.82 3027.20 8.23 -1.84 8.23 0.33 3149.85 0.26 357.44 3149.82 8.89 -1.83 8.89 0.09 3275.36 0.15 358.64 3275.33 9.34 -1.84 9.34 0.0$ 3400.00 0.19 9.17 3399.97 9.72 -1.82 9.72 0.04 3528.15 0.23 24.73 3528.12 10.16 -1.67 10.16 0.05 3652.89 0.12 20.82 3652.86 10.52 -1.52 10.52 0.09 3779.36 0.06 54.62 3779.33 10.68 -1.42 10.68 0.06 3904.56 0.19 299.16 3904.53 10.82 -1.56 10.82 0.18 4030.38 0.33 292.13 4030.35 11.06 -2.08 11.06 0.11 4154.89 0.45 301.68 4154.85 11.45 -2.83 11.45 0.11 4276.48 0.64 278.80 4276.44 11.$0 -3.90 11.80 0.23 4404.79 0.83 275.15 4404.74 12.00 -5.53 12.00 0.15 4531.86 0.85 275.46 4531.79 12.17 -7.38 12.17 0.02 4656.13 0.8$ 278.70 4656.05 12.40 -9.25 12.40 0.05 4782A9 0.95 283.00 4781.99 12.78 -11.23 12.78 a.a8 4908.96 1.14 296.19 4908.84 13.58 -13.39 13.58 0.24 5034.65 1.39 284.06 5034.50 14.50 -15.99 14.50 0.29 5158.50 1.49 281.05 5158.31 15.17 -19.03 15.17 0.10 5284.87 1.57 286.65 5284.64 15.98 -22.30 15.98 0.13 ~1 ~PQCH 24 Conoco'~Phillips . ~. Noatak #1 J • Measured D{eipj h Incl. {°} Azim. {°} True Vertical D filth Nor'things {ft} Eastings {ft} Vertical Section {ft} Dogleg Rate {°110t?Ft} 5410.66 1.40 280.72 5410.38 16.77 -25.47 16.77 0.18 5536.09 1.33 285.42 5535.78 17.44 -28.38 17.44 0.11 5661.02 1.20 290.13 5660.68 18.27 -31.01 18.27 0.13 5787.07 1.16 289.28 5786.70 19.15 -33.45 19.15 0.03 5913.55 1.04 298.95 5913.16 20.13 -35.66 20.13 0.17 6038.45 0.97 297.50 6038.04 21.16 -37.59 21.16 0.06 6163.84 0.76 307.09 6163.42 22.15 -39.19 22.15 0.20 6288.71 0.46 303.54 6288.28 22.93 -40.27 22.93 0.24 6413.88 0.67 320.94 6413.44 23.78 -41.15 23.78 0.21 6544.03 0.91 323.21 6539.58 25.15 -42.21 25.15 0.19 6668.80 0.62 337.11 6668.34 26.61 -43.10 26.61 0.27 6730.74 0.49 343.86 6730.28 27.17 -43.30 27.17 0.23 6978.60 0.22 335.98 6978.13 28.63 -43.79 28.63 0.11 7229.96 0.24 19.63 7229.49 29.58 -43.81 29.58 0.07 7482.98 0.16 342.21 7482.51 30.41 -43.74 30.41 0.06 7608.93 0.53 6.13 7608.45 31.16 -43.74 31.16 0.31 7734.82 0.60 4.16 7734.34 32.39 -43.63 32.39 0.05 7923.47 0.63 4.04 7922.98 34.40 -43.48 34.x0 0.02 7986.75 0.58 6.35 7986.25 35.06 -43.42 35.06 0.08 80$1.08 0.46 8.10 8080.58 35.91 -43.32 35.91 0.13 8198.44 0.31 6.98 8197.94 36.70 -43.21 36.70 0.12 8232.53 0.33 8.67 8232.03 36.89 -43.18 36.89 0.05 8326.07 0.29 355.$9 8325.57 37.39 -43.16 37.39 0.09 PRQJECTED 8425.00 0.29 355.89 8424.50 ~i EPC~C~-I 25 Ca~tc~ao/Phillips Aia~dca, Inc. Noatak #1 5.2 Bit Record Depth to Total Bit Avg' WOB PP Bit Make Type / 5# Jets / TFA Footage Hrs O ) R (Ktbsj RPM psi) Wear BHA N SS (ft) tl (f hr 12.25 " Hote 1 Hughes MXL-1 / 1x12,3x18 105 / -20 125 4.6 27 2 69 220 1-1-NO-A-E-I-NO-BHA 1 6054705 / 0.856 2rr1 Hughes MXL-1 / 1x12,3x1$ 230/ 105 2770 35.9 77 7 74 1512 2-2-NO-A-E-I-NO-TD 2 6054705 / 0.856 8.75" Hole 3 Reed DS70FNPV 6x15 / 3000 ! 2875 4550 61.4 74 8 80 2848 1-1-GT-A X-1-ER-BHA 3 H calo / 208648 1.035 4 Reed DS70FNPV 3x18,3x16 7550/7425 598 42 8 14 7 141 2233 2-2-CT-A-X-O-PN-TD 4 H calog i 204795 / 1.335 . 6.125 " Hale 5 Reed DSX613M- 3X10 3X12 8148/8023 277 12.4 22 6 62 1801 1-1-NO-AA-X-I-NO-TD 5 H Cato B4 / 113683 ' .G~CJ~..f~ 26 ~ ~ ~ Corwc Phillips .~~. Noatak #1 5.3 Mud Record Contractor: MI Mud Tvge: 6% KCI Spud /KCI Polvmer Date Depth MW (ppg) ECD (ppg VlS (s/qt) PV YP Gels FL (cc) FC Sols (°~) ONV Ratio Sd (°~) H p CI (ml/I) Ca (ml/I) 12'/4" section 2/9107 0 10.0 - 16 30 9/14 2/10/07 67 10.0 - 180 27 55 12/15/19 4.0 2 4A /96 10.0 30000 400 2/11!07 162 10.0 - 110 25 54 17/20/21 6.4 1 8.0 /92 1.0 10.0 30000 60 2111/07 230 10.0 - 99 23 51 14/18!20 6.1 1 8.0 /92 1.25 10.0 27500 80 2/12/07 622 10.0 - 140 20 47 17/21/22 5.7 1 8.0 /92 1.5 10.0 33000 250 2/12/07 1290 10.2 - 128 20 44 13/20/24 5.6 1 8.0 /92 1.7 9.5 31500 280 2/13/07 1543 10.0 - 70 20 44 16121/23 5.8 1 8.5 Tr/92 1.6 10.0 35000 250 2/13/07 2233 10,2 - 94 25 53 13/22/25 5.5 1 8.5 Tr/92 1.8 10.A 33500 250 2/14/07 2611 10.0 - 72 20 43 16/22/25 5.5 1 8.5 Trl92 1.25 9.0 34000 260 2/14/07 3000 10.0 - 70 20 41 11 /23125 5.3 1 8.5 Tr/92 1.5 9.5 35000 280 2/15/07 3000 10.1 - 60 18 37 15/26/29 7.5 1 9.0 Tr/91 1.1 9.0 30000 240 2/15/07 3000 10.2 - 60 15 36 11/25/27 7.2 1 9.5 Tr/91 1.3 10.0 31000 240 2/16/07 3000 9.9 - 72 16 37 12/22/25 6.2 1 8.5 Tr/92 1.4 9.0 28500 280 2!16/07 3000 9.9 - 74 17 31 10/21 /24 7.5 1 8.0 Tr/92 1.6 10.0 24500 280 2/17/07 3000 10.1 - 72 11 22 7/12/15 7.6 1 8.0 Tr/92 1.4 9.0 27000 220 8 3/4" section 2/18/07 3000 9.7 - 71 17 29 9/12/13 4.9 1 7.0 Tr/93 0.60 10.0 33000 240 2/19/07 3000 9.7 - 77 18 27 9111 /13 4.7 1 7.0 Tri93 0.50 10.0 34500 240 2/20/07 3000 9.7 - 65 11 23 10111 /12 5.4 1 7.0 1 /93 1.6 9.9 34500 120 2/20107 3000 9.7 - 70 11 24 9/11/12 5.1 1 7.0 Tr/93 1.6 10.0 3550 120 2/21 /07 3139 9.7 10.46 45 12 18 10/13/14 6.8 1 7.5 Tr/93 0.75 10.0 29500 120 2/21107 3584 9.8 - 45 14 21 7/12114 7.0 1 7.5 Tr/93 0.45 9.5 26500 160 2/22/07 3639 9.7 10.53 53 15 21 9/12!14 6.2 1 $.0 1/92 0.50 9.9 30000 120 2/22107 3987 9.9 11.0$ 53 14 22 8/12!15 6.0 1 9.0 1 /91 0.50 9.9 30000 120 2/22/07 4330 9.9 11.17 51 16 29 9/19124 6.5 1 8.0 1192 0.45 9.5 30000 140 2/23/07 4610 9.9 11.15 63 17 23 9!13/16 6.6 1 9.0 1/91 0.50 9.9 29000 120 2/23107 4886 10.1 11.00 68 16 27 10/15/17 6.9 1 9.0 1/91 0.35 9.0 31000 160 2/24/07 5146 9.8 10.70 54 13 32 16/1$/23 5.4 1 9.0 1 i91 0.50 9.3 34000 120 2/24/07 5472 9.7 10.79 62 21 27 11 /18/23 4.8 1 9.0 1 /91 0.30 9.4 33000 120 E1 EP4CH 27 ~ i • C;or~oco`rPhillips Alaska, Inc. Noatak #1 2/24107 5818 9.8 10.64 56 20 29 7120/22 4.6 1 9.0 1 /91 0.40 9.0 30000 120 Date Depth MW (p ) ECD (p) VIS (sigt) pV YP Gels FI_ cc FC Sols %) OIW Ratio Sd °~ pH CI (mUl Ca (ml/I 8 3/4" section (continued) 2125/07 6101 9.8 10.47 61 20 28 9/18123 4.6 2 9.5 1 /90 0.40 9.4 31000 80 2/25/07 6276 9.7 9.93 64 19 30 11/22/22 4.4 2 9.0 1 i90 0.40 9.3 30000 80 2125/07 6276 9.7 10.09 63 21 27 10/20/20 4.6 2 9.0 1190 0.40 9.2 29500 80 2/26/07 7157 9.9 10.47 79 28 28 10/24/25 3.2 1 9.0 2/90 0.50 9.3 30500 $0 2/26/07 7232 9.9 10.42 71 21 26 6/14/15 3.3 1 9.0 2/90 0.45 9.2 30000 80 2127107 7283 11.0 - 68 30 23 8/16/17 2.2 1/2 13.0 2/86 0.40 9.1 27500 80 2127/07 7466 11.0 - 73 32 26 7/10/12 2.4 1/2 13.0 2/86 0.43 9.2 29500 80 2/28/07 7550 11.1 - 70 31 31 719110 2.8 1 /2 14.0 2/85 0.50 9.4 31000 80 212$107 7550 11.1 - 72 32 35 8110/11 2.6 1 /2 14.0 2185 0.41 9.3 31000 $0 3/01 /07 7550 11.1 - 72 32 30 8110112 2.6 1 /2 14.0 2185 0.41 9.4 31000 80 3/01 /07 7550 11.2 - ?4 33 30 9/11!12 2.5 1 /2 14.0 2185 0.39 9.2 31000 80 3/02107 7598 11.3 11.49 84 36 28 8/15/24 2.6 1!2 15.0 2/83 0.50 9.4 34000 40 3/02/07 7620 11.3 11.40 74 33 26 9114/22 2.$ 1/2 16.0 2/82 0.25 9.3 32000 40 3/03/07 7798 11.3 11.36 69 34 28 9/14/22 2.8 1/2 16.0 2/$2 0.25 9.2 29500 80 3/03/07 7916 11.3 11.47 73 33 27 8/13119 2.6 1/2 16.0 2/82 0.25 9.3 28000 60 3104107 8042 11.3 11.43 62 32 26 517/8 2.4 1 /2 16.0 2/83 0.25 9.4 28000 60 3104/07 8100 11.3 11.47 65 33 33 5/7/9 2.6 112 15.0 2/84 0.25 9.3 25000 60 3/05/07 8148 11.3 - 58 28 26 61719 2.9 1 /2 16.0 1 /83 0.20 9.3 26000 60 3/05/07 8148 11.3 - 64 29 25 71819 2.8 1/2 15.0 1184 0.25 9.4 26000 60 3106/07 8148 11.2 - 55 29 26 6/719 2.6 1 /2 15.0 2184 0.25 9.3 24000 40 3/07/07 8148 11.2 - 65 30 24 7/8/10 3.0 1 / 15.0 1 /84 0.20 9.0 23500 - 3107/07 8148 11.3 - 59 29 24 6/8/9 2.9 1 / 15, 0 1184 0.25 9.0 23000 - 61/8" section 3108/07 8148 9.9 - 50 14 23 416/8 4.3 1!2 11.0 2188 tr 9.7 14500 60 3/09/07 8148 9.$ - 102 15 19 617/8 3.5 1 / $.5 1 /91 0.15 9.8 39000 60 3/09/07 8148 9.8 - 66 14 23 6/7/8 3.6 11 7.5 1192 tr 9.5 27500 40 3/ 10/07 8198 9.9 10.4 50 17 18 5!617 3.6 1 /2 8.0 1 /92 0, 50 9.0 26000 300 ~ 3/10/07 $287 9.5 10.5 53 20 21 7/10/14 3.4 112 7.0 1/93 0.25 9.1 32000 240 3/11 /07 8425 9.8 10.5 50 19 25 9/11 /14 3.4 1 /2 8.0 1 /92 0.40 9.2 26000 40 3/11/07 8425 10.0 10.3 54 20 26 10/12/15 3.2 1/2 9.0 1/91 0.25 9.3 27500 40 3/12107 8425 10.0 - 47 13 21 7/9110 4.2 1 /2 $.5 1 /91 0.25 9.9 25000 40 3112/07 8425 10.0 - 54 13 22 8/10112 3.4 1/2 9.0 1191 0.25 9.6 25500 40 3/13/07 8425 10.0 - 54 11 21 6/8/9 4.2 112 8.0 1192 0.25 9.4 27000 40 ~P~t~H 28 ~ ~ ~ Ca-noc Phillips a~~, rec. Noatak #1 3/13/07 8425 10.0 - 57 12 21 7110/11 4.4 1/2 9.0 1/91 tr 9.4 27000 40 Abbreviations MW =Mud Weight WL =Wafer or Filtrate Lass Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength Sd =Sand content CI =Chlorides VIS =Funnel Viscosity PV =Plastic Viscosity Sols =Solids ECD =Effective Circulating Density FC =Filter Cake O/V11=Oil to Water ratio [~ EPOCH 29 • • i ConocoPhillips Alaska Inc. Exploration Well Noatak #1 ~J • • Report far: Ray Springer/Mike Winfrey Dick Owens Date: 2!10107 Time: 00:00 Current Depth: 105 Operation: Rig Up Yesterdays Depth: 105 24 hr Footage: 0 Drilling Parameters ROP: Current: Max: To ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Circulation: Strokes: Time: ECD: Current: Max: Mud Properties MW: 10.0 FV: 16 PV 16 YP: 30 FL; Gels: 9114/ Sol: H: CC~ Ca+ MW Change: Depth: From: Mud Loss event: Depth: Volume: To: Reason: Gas Data Ditch Gas: Current: Max: De the Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C5f C5N Connection Gas De th TG C1 C2 C3 C41 C4N C5! C5N Peaks Lithologies: Current: Last 24 hrs. Rig continued preparations for Spud. Epoch completed rig up. Epoch Operational Summary: instrumentation includes gas detection only. All drilling parameters provided by Pasan through wilts feed to Epoch Rigwatch. Epoch Rigwatch provides total gas wilts feed to Pason (3`~ Party Gas). Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None Ts ~ ~PO~H 30 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Ray Springer I Mike Winfrey Dick Owens Date: 2111107 Time: 00:00 Current Depth: 67 Operation: Drilling out Conductor Yesterdays Depth: 105 24 hr Footage: 0 Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Circulation: Strokes: Time: ECD: Current: Max: Mi ~ti Prnnerties MW: 10.0 FV: 180 PV 27 YP: 55 FL: 4.0 Gels: 12/15/19 Sol: 4 pH: 10.0 CI"~ 30400 Ca++__ 400 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De the Gas Events Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C5! C5N Tri Gas De th TG C1 C2 G3 C41 C4N C51 G5N Connection Gas De th TG C1 C2 C3 C41 C4N C5{ C5N Lithologies: Current: Last 24 hrs: Operational Summary: Prepare for spud. Thawed out frozen lines. Drilling out conductor (set@105 ft). Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None • ~PQ~H 31 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 • Report for: Ray Springer /Mike Winfrey Dick Owens Date: 2112107 Time: 00:00 Current Depth: 273 Operation: Drilling Yesterdays Depth: 105 24 hr Footage: 168 Drillino Parameters ROP: Current: 89 Max: 1029 Tor ue: Current: NA Max: NA WOB: Current 2K Max: 5K RPM: Current: 68 Max: 80 PP: Current: 780 Max: 806 La Strokes: 702 Time: 3.3m Circulation: Strokes: 758 Time: 3.4m ECD: Current: 10.2 Max: 10.2 Mud Proaerties MW: 10.0 FV: 1$0 PV 27 YP: 55 FL: 4.0 Gels: 12/15/19 SoL• 4 H: 10.0 C1"~ 30000 Ca+~`~ 400 MW Change: Mud Loss event: Depth: NONE From: Depth: NONE Volume: To: Reason: Gas Data Ditch Gas: Current: 0 Max: 0 De the Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 230 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 Peaks De th TG C1 C2 C3 C41 C4N C5l C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N none Lithologies: Current: 40°lo Claystone, 30°k Siltstone, 30% Sand and Sandstone Last 24 hrs: 30°~ Glaystone, 20°~ Siltstone, 40°~ Sand and Sandstone, 10°~ Carbonaceous Matter Operational Summary: Drilled out conductor to 105 ft, circulated hole clean. Drilled to 230' with HWDP, POOH and picked up BHA, Drilled to 273'. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None • [~ ~P~~H 32 ConocoPhillips Alaska Inc. NPRA Exploration Wel! Noatak #1 .Report for: Ray Springer /Mike Winfrey Dick Owens Date: 2/13/07 Time: 00:00 Current Depth: 1367 Operation: Drilling Yesterdays Depth: 273 24 hr Footage: 1094 Drilling Parameters ROP: Current: 95 Max: 206 Tor ue: Current: NA Max: NA WOB: Current 5K Max: 5K RPM: Curren#: 83 Max: 86 PP: Current: 1408 Max: 1589 La Strokes: 3385 Time: 14.8 m Circulation: Strokes: 3640 Time: 15.9m ECD: Current: 10.2 Max: 10.4 Mud Properties MW: 10.2 FV: 128 PV 20 YP: 44 FL: 5.6 Gels: 13/20/24 Sal: 8.0 pH:_ 9.5 _ CI"~ _31500 Ca+~'~ 280 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: 2 Max: 17 De the 484 Gas Events Freaks De th TG C1 C2 C3 C41 C4N C5i C5N Tri Gas De th TG C1 C2 C3 C4i C4N C5i C5N N/A Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 Gas Sam les No. De th TG C1 C2 C3 C41 C4N C5i C5N 1 500 1 127 2 750 1 250 3 1000 2 332 4 1250 2 398 Lithologies; Current: 60°~ Ciaystone, 10% Siitstone, 30°r6 Ash Fall Tuff Last 24 hrs: 50% Ciaystone, 20°~ Siitstone, 30°~ Sand and Sandstone Operational Summary: Drilled to 273' to 1367' Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None • ~~~~H 33 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Ray Springer !Mike Winfrey Dick Owens Date: 2114/07 Time: 00:00 Current Depth: Yesterdays Depth; 24 hr Footage: Drilling Parameters 2447 Operation: Drilling 1080 ROP: Current: 117 Max: 696 Tor ue: Current: 2170 Max: 5740 WOB: Current 7K Max: 17K RPM: Current: 80 Max: 124 PP: Current: 1853 Max: 2155 La Strokes: 6286 Time: 26.3 m Circulation: Strokes: 6692 Time: 28.0 m ECD: Current: 10.4 Max: 10.4 Mud Properties MW: 10.2 FV: 94 PV 25 YP: 53 FL: 5.5 Gels: 13/22!25 Sol: 8.5 H: 10.0 CI"~ 33500 Ca~`~ 250 MW Change: Mud Loss event: Depth: NONE From: Depth: NONE Volume: To: Reason: Gas Data Ditch Gas: Current: 32 Max: 200 De the 1770 r,as FvPnts Tri Gas De th TG C1 C2 C3 C41 C4N C51 G5N 49u 1542 Connection Gas De th TG C1 C2 C3 C4f C4N C5# C5N 0 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 1524 97 17320 36 1770 200 32841 647 107 2208 108 19131 90 47 2455 103 19157 28 26 Gas Samples No. De th TG C1 C2 C3 C41 C4N C51 C5N 1 1500 7$ 13871 47 2 1724 54 9223 551 122 3 2000 41 7627 66 41 4 2298 57 10551 40 26 5 2500 62 10973 16 14 Lithologies: Current: 70°~ Claystone, 20°~ Siltstone, 10% Sand Last 24 hrs: 50% Claystone, 20% Siltstone, 30% Sand Operational Summary: Drilled 1367 to 1542', cleaned hole and POOH to 460', TlH, and drill 1542 to 2447'. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None [~ EPC)~H ConocoPhillips Alaska Inc. NPRA Explanation Well Naatak #1 Report for: Ray Springer / Dink Heim Drilfino Parameters Dick Owens Date: 2115/07 Time: 00:00 Current Depth: 3000 Opera#ion: Wiper Trip Yesterdays Depth: 2447 24 hr Footage: 553 - __ ROP: Current: 60 Max: 696 Tor ue: Current: 2198 Max: 3962 WOB: Current 9K Max: 17K RPM: Current: 70 Max: 88 PP: Current: 2133 Max: 2155 la Strokes: 7750 Time: 30.7 m Circulation: Strokes: 8320 Time: 33.0 m ECD: Current: 10.2 Max: 10.4 Mud Properties : MW: 10.0 FV: 70 PV 20 YP: 41 FL: 5.3 Gels: 11/23125 Sol: 8.5 H: 9.5 GI-~ 35000 Ca +~ 280 MVt/ Change: Mud Loss event: Depth: NONE From: Depth: NONE Volume: To: Reason: Gas Data Ditch Gas: Current: 30 Max: 93 De the 2518 Comas Events Tri Gas De th TG C1 C2 C3 C41 C4N G5f C5N Connection Gas De th TG C1 C2 C3 C4f C4N C5f C5N 0 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 2518 93 15736 47 29 (was Samales No. De th TG C1 C2 C3 C4f C4N C5f C5N 10 2750 40 8029 8 Lithotogies: Current: 70°~ Claystone, 20°~ Siltstone, 10% Sand Last 24 hrs: 50°~ Claystone, 20°l° Siltstone, 30°~ Sand Operational Summary: Drilled 2447' to 2550', repair charge pump. Drift to 3000', casing depth, circulate out, and wiper trip. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~P~~H 35 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 .Report for: Ray Springer / Dink Heim Dick Owens Date: 2116/07 Time: 00:00 Cu Ye 24 DriOina Parameters Trent Depth: 3000 Operation: POOH for Casing sterdays Depth: 3000 hr Footage: 0 ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La : Strokes: 7750 Time: 30.7 m Circulation: Strokes: 8320 Time: 33.0 m ECD: Current: 10.2 Max: 10.4 Mud Pmoerties MW: 10.2 FV: 60 PV 15 YP: 36 FL: 7.2 Gels: 11/25f27 Sol: 9.5 H: 10.0 CI"~ 31000 Ca ~ 240 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: 4u before tri Max: 129u De the Gas Events Peaks De th TG C1 C2 C3 C41 C4N C51 C5N NONE Tri Gas De th TG C1 C2 C3 G4! C4N C51 C5N 129u 3000' Connection Gas De th TG C1 C2 C3 C41 C4N C5f C5N 0 Gas Samples No. De th TG C1 C2 C3 G41 C4N C5i C5N NONE Lithoiogies: Current: 70°~ Claystone, 20°~ Siltstone, 10°k Sand on bottom. Last 24 hrs: NIA POOH to collars, mostly back reaming. TIH with HW, and picked up and RIH Operational Summary: with 4"' DP to 2450', and DP stands to bottom, washing and reaming from 2205' to 3000'. POOH to 1060' at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None • ~~0~~ 36 ConocoPhillips Ataska Inc. NPt~A Exptora#ion Well Noatak #1 .Report for: Ray Springer / Dink Heim Dick Owens Date: 2117/07 Time: 00:00 Current Depth: 3000 Operation: RIH with Landing Jt. Yesterdays Depth: 3000 24 hr Footage: 0 Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3531 Time: N1A Circulation: Strokes: 4194 Time: NlA ECD: Current: 10.2 Max: 10.2 Mud Properties MW: 9.9 FV: 74 PV 17 YP: 31 FL: 7.5 Gels: 10/21/24 Sol: 8.0 H: 10.0 Cl-~ 24500 Ca ~ 280 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: 2u Max: 8u De the 2350' Gas Events Peaks De th TG C1 C2 C3 C41 C4N C5l C5N NONE Comas Samples Tri Gas De th TG C1 C2 C3 C4l C4N C51 C5N 8u 3000' Connection Gas De th TG C1 C2 C3 C4l C4N C5i C5N 0 No. De th TG C1 C2 C3 C4l C4N C51 C5N NONE Lithologies: Current: 70°~ Claystane, 20% Siltstone, 10°~ Sand on bottom. Last 24 hrs: N!A POOH and L/D BHA, downloading MWD. Rig up and run 9 5/8" casing to Operational Summary: bottom, circulating at 1300' and 2350', maximum 8 units of gas. Running in hole with landing joint at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~~Q~H 37 GonocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 • • Report for: Ray Springer I Dink Heim Dick Owens Date: 2/18107 Time: 00:00 Current Depth: 3000 Operation: POOH wl DP. Yesterdays Depth: 3000 24 hr Footage: 0 Drilling Parameters ROP: Current: Max: To ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3531 Time: N/A Circulation: Strokes: 4095 Time: NIA ECD: Current: 10.3 Max: 10.3 Mud Pranerties MW: 10.1 FV: 72 PV 11 YP: 22 FL: 7.6 Gels: 7/12115 Sol: 8.0 H: 9.0 Cl~~ 27000 Ca;+~ 220 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: Ou Max: 2u De the 3000' (;as Fvants Tri Gas De th TG C1 C2 C3 C4{ C4N C51 C5N NIA Connection Gas De th TG C1 C2 C3 C4{ C4N C5{ C5N N/A Peaks De th TG C1 C2 C3 C41 C4N C51 C5N NONE No. De th TG C1 C2 C3 C4{ C4N C51 C5N NONE Gas Sam ies Lithologies: Current: 70% Claystone, 20°~ Siltstone, 10% Sand on bottom. Last 24 hrs: NIA Circulate hole clean. Transfer fluids to mud pump. R{H with 4" DP to casing Operational Summary: shoe, and perform cementing procedures. POOH with 4" DP to 2500' at midnight. Ca{ibrations: Calibrated Total Gas and Gas Chromatograph Failures: None [~ ~Pt~~H 38 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 . Report for: Ray Springer 1 Dink Heim Dick Owens Date: 2119107 Time: 00:00 Current Depth: 3000 Operation: Nipple U~BOP Yesterdays Depth: 3000 24 hr Footage: 0 Dri{lina Parameters • • ROP: Current: Max: Tar ue: Current: Max WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3531 Time: N1A Circulation: Strokes: 4095 Time: N1A ECD: Current: 9.7 Max: 9.7 Mud Praoerties MW: 9.7 FV: 71 PV 17 YP: 29 FL: 4.9 Gels: 9!12/13 Sol: 7.0 H: 10.0 C("~ 33000 Ca+ ~ 240 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: Ou Max: Ou De the 3000' Gas Events De th TG C1 C2 C3 C4t C4N C51 C5N NONE °eaks Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N NIA Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NIA No. De th TG C1 C2 C3 C41 C4N C51 C5N NONE 3as Sam les Operational Summary: POOH with 4" DP from 2500'. Nipple down diverter and begin nipple up BOP. Lithotogies: Current: 70% Claystone, 20°~ Siltstone, 10% Sand on bottom. Last 24 hrs: NIA Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~~~~H 39 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 • Report for: Ray Springer 1 Dink Heim Drilling Parameters Dick Owens Date: 2/20107 Time: 00:00 Current Depth: 3000 Operation: PIU 8HA Yesterdays Depth: 3000 24 hr Footage: 0 ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3531 Time: NIA Circulation: Strokes: 4095 Time: NIA ECD: Current: 9.7 Max: 9.7 Mud Praoerties • MW: 9.7 FV: 77 PV 18 YP: 27 Ft_: 4.7 Gels: 9/11113 Soh 7.0 H: 10.0 CI-~ 34500 Ca++~ 240 MW Change: Depth: NONE Fram: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: Ou Max: Ou De the 300Q' Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N N/A Connection Gas De th TG C1 C2 C3 C41 C4N C5i C5N NIA De th TG C1 C2 C3 C41 C4N C51 C5N NONE Peaks No. De th TG C1 C2 C3 C41 C4N C51 C5N NONE Gas Sam les Lithologies: Current: 70% Ciaystone, 20% Siltstone, 10% Sand on bottom. Last 24 hrs: NIA Operational Summary: Nipple up and test BOP. Begin picking up BHA. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None EPt~CH 40 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 • Report for: Donnie Lutrick l Dink Heim Dick Owens Date: 2/21107 Time: 00:00 Current Depth: 3000 Operation: Test Casing Yesterdays Depth: 3000 24 hr Footage: 0 • Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3393 Time: 18.4 Circulation: Strokes: 3970 Time: 21.5 ECD: Current: 9.7 Max: 10.0 Mud Properties : MW: 9.7 FV: 65 PV 11 YP: 23 FL: 5.4 Gels: 10/11/12 Sok 7.0 H: 9.9 CI-~ 34500 Cat+~ 120 MW Change: Depth: NONE Fram: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: Ou Max: Ou De the 3000' Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N N/A Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NIA De th TG C1 C2 C3 C41 C4N C51 C5N NONE Peaks No. De th TG C1 C2 C3 C41 C4N C51 C5N NONE was Sam les Lithologies: Current: 70°~ Claystone, 20°~ Siltstone, 10°~ Sand on bottom. Last 24 hrs: NIA Operational Summary: Pick up BHA. Pick up and stand back DP. RIH to 2794' and tag cement. Prepare to test casing to 3000 psi. Calibrations: Calibrated Totat Gas and Gas Chromatograph Failures: None [~ EP+QCH 41 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 • Report for: Donnie Lutrick / Dink Heim Dick Owens Date: 2/22/07 Time: 00:00 Drilling Parameters Current Depth: 3579 Operation: Cut and Slip Yesterdays Depth: 3000 24 hr Footage: 579 ROP: Current: 99 Max: 432 Tor ue: Current: 2112 Max: 6512 WOB: Current 3 Max: 19 RPM: Current: 84 Max: 102 PP: Current: 2400 Max: 2538 La Strokes: 3760 Time: 15.7 Circulation: Strokes: 4428 Time: 18.5 ECD: Current: 10.9 Max: 11.2 Mud Properties MW: 9.8 FV: 45 PV 14 YP: 21 FL: 7.0 Gels: 7!12/14 Sol: 7.5 H: 9.5 GE"~ 26500 Ca++~ 160 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Cun'ent: 57u Max: 83u De the 3489' Gas Events • Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N NIA Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 Peaks De th TG C1 C2 C3 C41 C4N C5t C5N NONE 3as Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N 11 3020 16 2589 0 0 0 0 0 0 12 3255 37 6830 19 0 0 0 0 0 13 3500 71 11973 70 16 3 5 0 0 Lithologies: Current: 80°~ Claystone, 20°~ Siltstone. Last 24 hrs: 70°~ Claystone, 20°k Siltstone, 10°~ Sand Test casing to 3000 psi. Drill cement, shoe track, and formation to 3020'. Operational Summary: Displace to 9.7 ppg mud, and F.LT. to 18.2 ppg EMW. Drill to 3576', POOH 3 stands, and slip and cut drill line. r1 U Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~PC~CH 42 • C7 • ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Donnie Lutrick! Dink Heim Dick Owens Date: 2123!07 Time: 00:00 Current Depth: 4440 Operation: Drilli Yesterdays Depth: 3579 24 hr Footage: 861 DriiGna Parameters ROP: Current: 50 Max: 279 Tor ue: Current: 2463 Max: 6575 WOB: Current 10 Max: 12 RPM: Current: 62 Max: 100 PP: Current: 2640 Max: 2839 La Strokes: 4763 Time: 20.7 Circulation: Strokes: 5595 Time: 24.3 ECD: Current: 11.1 Max: 11.4 Mud Pranerties MW: 9.9 FV: 51 PV 16 YP: 29 FL: 6.5 Geis: 9/19/24 Sol: 8 H: 9.5 C(-~ 30000 Ca+ ~ 140 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: 18u Max: 52u De the 3862 Gas Events Peaks Tri Gas De th TG C1 C2 C3 C4i C4N C51 C5N 64u 3576 64u Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 De th TG C1 C2 C3 C41 C4N C51 C5N NONE No. De th TG C1 C2 C3 C41 G4N C51 G5N 14 3750 19 3583 20 0 0 0 0 0 15 4000 30 5577 54 22 3 4 0 0 16 4250 35 6220 76 25 5 7 0 0 17 4500 22 4300 55 23 5 5 0 0 Gas Sam les Operational Summary: p midnight. Lithofogies: Current: 90°~ Claystone, 10% Siltstone. Last 24 hrs: 70°lo Ciaystone, 20% Siltstone, 10°~ Sand Finish sli and cut drill line POOH from 3384' to shoe Drill 3576' to 4440' at Calibrations: Calibrated Tota! Gas and Gas Chromatograph Failures: None ~P~~H 43 ConocoPhillips Alaska Inc. NPRA Explora#ion Weli Noatak #1 Report for: Justin MacDonald I Dink Heim Dick Owens Date: 2!24/07 Time: 00:00 Current Depth: 4980 Operation: Drilling Yesterdays Depth: 4440 24 hr Footage: 540 • LJ Drillina Parameters ROP: Current: 12 Max: 196 Tar ue: Gurrent: 5173 Max: 7509 WOB: Current 17 Max: 19 RPM: Current: 96 Max: 104 PP: Current: 2612 Max: 3077 La Strokes: 5498 Time: 25.2 Circufatian: Strokes: 6454 Time: 29.6 ECD: Current: 11.1 Max: 11.4 Mud Pmc~erties MW: 10.1 FV: 68 PV 16 YP: 27 FL: 6.9 Gels: 10!15!17 Sol: 9.0 H: 9.0 CI-~ 31000 Ca+`~ 160 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: 8u Max: 27u De the 4940 Gas Events Tri Gas De th TG C1 C2 C3 C4f C4N C51 C5N 92u 4516 92u Connection Gas De th TG C1 C2 C3 C41 G4N C51 C5N 0 De th TG C1 C2 C3 C41 C4N C51 C5N NONE Peaks No. De th TG C1 C2 C3 C41 C4N C51 G5N 18 4750 20 4454 51 15 5 3 0 0 19 5000 13 2793 31 13 3 1 0 0 3as Sam les Lithologies: Current: 80°~ Claystone, 10% Siltstone, 10°~ Shale. Last 24 hrs: 75°~ Claystone, 20°lo Siltstone, 5% Shale Drill from 4440' to 4516', circulate hole Gean, pump weighted slug, wiper trip to Operational Summary: 3577', and begin RiH at 6 am. Finish RIH, and drib from 4516' to 4980', at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~ ~PflCH ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 • Report for: Justin MacDonald 1 Dink Heim Dick Owens Date: 2125/07 Time: 00:00 Gurrent Depth: 6003 Operation: Drilling Yesterdays Depth: 4980 24 hr Footage: 1023 • • Drilling Parameters ROP: Current: 77 Max: 141 Tor ue: Current: 3388 Max: 8228 WOB: Current 7 Max: 23 RPM: Current: ~ Max: 101 PP: Current: 2932 Max: 3224 La Strokes: 6598 Time: 32.5 Circulation: Strokes: 7759 Time: 38.2 ECD: Current: 11.1 Max: 11.15 Mud Prnnerties MW: 9.8 FV: 56 PV 20 YP: 29 FL: 4.6 Gels: 7!20/22 Sol: 9 H: 9.0 CI~~ 30000 Ca ~ 120 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Gurrent: 15u Max: 26u De the 5861 Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N NIA Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 ~eaKs De th TG C1 C2 C3 C41 C4N C51 C5N NONE No. De th TG C1 C2 G3 C41 C4N C5t C5N 20 5250 12 3123 36 22 7 3 0 0 21 5500 14 3345 46 27 12 6 0 0 22 5750 26 4898 87 61 18 15 8 3 23 6000 22 3818 83 62 20 21 9 4 Gas Sam !es Lithoiogies: Current: 50% Glaystone, 20% Siltstone, 20°~ Sand 10% Shale. Last 24 hrs: 60% Glaystone, 20% Siltstone, 10°~ Sand, 10% Shale. Operational Summary: Dril! from 4980' to 6003' at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~P~~H 45 ConocoPhiliips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Justin MacDonald 1 Dink Heim Dick Owens • • Date: 2/26107 Time: 00:00 Current Depth: 6721 Operation: Drill Yesterdays Depth: 6003 24 hr Footage: 718 Drilling Parameters ROP: Current: 95 Max: 216 Tor ue: Current: 3425 Max: 10721 WOB: Current 9 Max: 18 RPM: Current: 95 Max: 101 PP: Current: 3294 Max: 3647 La Strokes: 7530 Time: 33.6 Circulation: Strokes: 8848 Time: 39.5 ECD: Current: N/A Max: N1A Mud Properties MW: 9.7 FV: 63 PV 21 YP: 27 FL: 4.6 Gels: 10/20120 SoL 9.0 H: 9.2 CI"~ 29500 Ca +~ 80 MW Change: Depth: NONE From: To: Reason: Mud Loss event: Depth: NONE Volume: Gas Data Ditch Gas: Current: 28u Max: 33u De the 6687 Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 76u 6025 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 De th TG C1 C2 C3 C4l C4N C5! C5N NONE Peaks No. De th TG C1 C2 C3 C41 C4N C5l C5N 24 6250 15 3169 71 42 15 10 4 2 25 6500 13 2672 91 52 14 10 5 2 26 6750 29 4221 246 148 47 40 10 4 Gas Sam les Lithologies: Current: 40% Claystone, 30% Siltstone, 10°~ Sandstone, 20°l° Shale. Last 24 hrs: 50% Claystone, 20°k Siitstone, 20°~ Sandstone, 10°~- Shale. Drill from 6003' to 6025', pump sweep and circulate hole clean, pump slug, Operational Summary: and POOH to 4460'. RIH and drill from 6025' to 6100', work on pump. Drill to 6721' at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~~~~~ 46 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Mike Winfrey / Dink Heim Dick Owens Date: 2127107 Time: 00:00 Current Depth: 7231 Operation: Repair Kelly Hose Yesterdays Depth: 6721 24 hr Footage: .510 Driltina Parameters • • ROP: Current: 84 Max: 156 Tor ue: Current: 7605 Max: 9557 WOB: Current 10 Max: 17 RPM: Current: 88 Max: 101 PP: Current: 3322 Max: 3632 La : Strokes: 7981 Time: 35.8 Circulation: Strokes: 9386 Time: 42.1 ECD: Current: NIA Max: NIA Mud Properties : MW: 9.9 FV: 71 PV 21 YP: 26 FL: 3.3 Gels: 6114115 Sol: 9.0 H: 9.2 Cl"~ 30000 Ca++~ 80 MW Change: Mud Loss event: Depth: From: Depth: Votume: To; Reason: Gas Data Ditch Gas: Current: 35u Max: 141 u De the 7206 Gas Events Tri Gas De th TG C1 C2 C3 C4t C4N C51 C5N N1A Connection Gas De th TG C1 C2 C3 C41 C4N C5t C5N 30 7165 Peaks De th TG C1 C2 C3 C4t C4N C51 C5N 7064 104 15568 1574 1020 199 284 89 69 7096 122 18042 1964 1265 221 343 97 75 7205 141 20259 2751 1947 241 546 123 130 7241 222 24695 3249 2434 305 752 168 197 Gas Samoies No. De th TG C1 C2 C3 C4t C4N C51 C5N 27 7000 16 2243 203 139 33 47 12 6 28 7063 102 15248 1565 1018 198 283 89 69 '~ 29 7096 122 18042 1964 1265 221 343 97 75 i 30 7240 222 24695 3249 2434 305 752 168 197 31 7250 41 3155 492 565 98 245 65 79 Litholagies: Current: 10°~ Claystone, 30°~ Sittstone, 60% Sandstone. Last 24 hrs: 30°~ Claystone, 30°~ Siltstone, 30°~ Sandstone, 10% Shale. Operational Summary: Drill from 6721' to 7231'. POOH two stands and work an ketly hose to midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None EP~~H 47 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Mike Winfrey / Dink Heim Dick Owens Date: 2!28107 Time: 00:00 Current Depth: 7541 Operation: Repair Pump Swab Yesterdays Depth: 7232 24 hr Footage: 309 Drilling Parameters • • ROP: Current: 45 Max: 152 Tor ue: Current: 2811 Max: 9043 WOB: Current 4.3 Max: 14 RPM: Current: 83 Max: 100 PP: Current: 3434 Max: 3618 La Strokes: 7938 Time: 38.9 Circulation: Strokes: 9343 Time: 45.8 ECD: Current: Max: M~~ri Praoerties MW: 11.0 FV: 73 PV 32 YP: 26 FL: 2.4 Gels: 7/10/12 Sol: 13 H: 9.2 CI"~ 29500 Ca'+~ 80 MW Change: Mud Loss event: Depth: 7282 From: 9.9 To: 11.0 Reason: HRZ Depth: Volume: Gas Data Ditch Gas: Current: 76u Max: 222u De the 7242 Gas Events Tri Gas De th TG C1 G2 C3 C41 C4N C51 C5N N/A Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 10u 7533 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 7373 116 16045 1474 1117 120 365 69 85 C~ac ~amnlas No. De th TG C1 C2 C3 C41 C4N C51 C5N 32 7314 62 8411 985 790 89 261 54 67 33 7360 88 12059 1465 1155 126 368 80 94 34 7372 112 15546 1963 1469 155 472 87 104 35 7420 120 16739 1951 1396 147 477 93 128 36 7500 90 10990 1541 1324 155 498 99 124 Lithoiogies: Current: 90°k Shale, 10% Claystone last 24 hrs: 50°~ Shale, 10% Siltstone, 40°lo Sandstone Continue work on Kelly hose until 1 am. RIH and drill from 7231' to 7282'. Operational Summary: Work on pump at 6 am unti12:30 pm. Drill from 7282' to 7541' at midnight, and pump swab failure. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~P~~~ 48 ConocoPhillips Alaska Inc. NPRA Explora#ion Weil Noatak #1 Report for: Mike Winfrey / Dink Heim Dick Owens Date: 3!1/07 Time: 00:00 Cu Yes 24 DriHina Parameters rrent Depth: 7550 Operation: Test BOP terdays Depth: 7541 hr Footage: 9 ROP: Current: 154 Max: 154 Tor ue: Current: 5942 Max: 7728 WOB: Current 5 Max: 9 RPM: Current: 91 Max: 93 PP: Current: 3399 Max: 3568 La Strokes: 8112 Time: 41.2 Circulation: Strokes: 9547 Time: 48.5 ECD: Current: Max: Mori Pr~nerties C] MW: 1 i .1 FV: 72 PV 32 YP: 31 FL: 2.6 Gels: $110111 Sal: 14 H: 9.3 CI"~ 31000 Ca +~ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 64u Max: 92u De the 7544 Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N N1A Connection Gas De th TG C1 C2 C3 C4t C4N C51 C5N N/R De th TG C1 C2 C3 C41 C4N C51 C5N Peaks Gas Sam les No. De th TG C1 C2 C3 C4t C4N C51 C5N Lithologies: Current: $0°~ Shale, 10°~ Claystone, 10% Siltstone Last 24 hrs: 80% Shale, 10°~ Claystone, 10°!° Siltstone Operational Summary: Change out pump swab, drill 7541' to 7550', circulate hole clean, POOH, lay down BHR, and download MWD. Begin testing BOP before midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None C~ ~PC~~H 49 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #9 Report far: Mike Winfrey / Dink Heim Dick Owens r C Date: 312/07 Time: 00:00 Current Dep#h: 7550 Operation: Begin MADD Pass Yesterdays Depth: 7550 24 hr Footage: 0 Driilina Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 8115 Time: 41.2 Circulation: Strokes: 9550 Time: 48.5 ECD: Current: Max: Mud Praoerties MW: 11.2 FV: 74 PV 33 YP: 30 FL: 2.5 Gels: 9111 /12 Sol: 14 H: 9.2 CI'~ 31000 Ca +~ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 13u Max: 124u De the Circulatin at 3980' Comas Fvants De th TG C1 C2 C3 C4t C4N C51 C5N 'eaks Tri Gas De th TG C1 C2 C3 C41 C4N C51 G5N NIA Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N NIA 3as Sam Les No. De th TG C1 C2 C3 C4i C4N C5i C5N Lithologies: Current: 80°k Shale, 10°~ Claystone, 10°~ Siltstone (on bottom) Last 24 hrs: Finish testing BOP, lay down test tools, and work on keHy hose til 6 am. Make Operational Summary: up BHA, and pick up and RIH with 4" DP to 1920'. RIH with 4W DP (stands} to 4000 and circulate hole clean. RIH to 6400 and circulate hole clean to midnight. Calibrations: Calibrated Tota! Gas and Gas Chromatograph Failures: None EP~~H 50 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #'1 Report for: Mike Winfrey 1 Dink Heim Dick Owens • Date: 3/3107 Time: 00:00 Current Depth: 7622 Operation: Drill Yesterdays Depth: 7550 24 hr Footage: 72 Drilling Parame#ers ROP: Current: 13 Max: 85 Tor ue: Current: 6244 Max; 9226 WOB: Current 22 Max: 32 RPM: Current: 183 Max: 183 PP: Current: 2230 Max: 3726 La Strokes: 8351 Time: 45.0 Circulation: Strokes: 9829 Time: 57.1 ECD: Current: 11.4 Max: 11.5 Mud Pmeerties MW: 11.3 FV: 74 PV 33 YP: 26 FL 2.8 Gefs: 9/14122 Sol: 16 pH: 9.3 CI-~ 32000 Ca++~ 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 12u Max: 28u De the 7561' Gas Events De th TG C1 C2 C3 C41 C4N C51 C5N Peaks Tri Gas De th TG C1 C2 C3 C41 C4N G51 C5N 30u 7550' Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 7675' 3as Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 50°~ Shale, 30% Claystone, 10°~ Siltstone, 10°~ Sandstone Last 24 hrs: 60°I° Shale, 20°~ Claystone, 15°~ Siltstone, 5°~ Sandstone Operational Summary: MADD pass 6400 to 7550'. Drill 7550' to 7622' at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~17~~H 51 GonocoPhiHips Alaska Inc. NPRA Exploration Well Noatak #1 Report far: Mike Winfrey / Dink Heim Dick Owens Date: 3/4/07 Time: 00:00 Current Depth: 7943 Operation: Drilling Yesterdays Depth: 7622 24 hr Footage: 321 C7 • Driliina Parameters ROP: Current: 21 Max: 156 Tor ue: Current: 5216 Max: 8556 WOB: Current 9 Max: 29 RPM: Current: 172 Max: 184 PP: Current: 2950 Max: 3291 La Strokes: 8351 Time: 45.0 Circulation: Strokes: 9829 Time: 57.1 ECD: Current: 11.4 Max: 11.5 Mud Properties MW: 11.3 FV: 73 PV 33 YP: 27 FL: 2.6 Gels: 8!13119 Sol: 16 H: 9.3 Cl'' 28000 Ca++~ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 25u Max: 69u De the 7664' teas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 G5N N/A Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N 0 7990' De th TG C1 C2 C3 C41 C4N C51 C5N Peaks No. De th TG C1 C2 C3 C41 C4N C51 C5N 37 7750 37 3674 554 508 90 175 44 54 38 8000 38 3964 713 605 111 209 58 71 Gas Sam les Lithologies: Current: 80°~ Shale, 20°~ Claystone Last 24 hrs: 70°~ Shale, 20% Claystone, 10°~ Siltstone Pump nut plug sweep to bottom and clean bit. Drill 7622' to 7698', and pump Operational Summary: #2 failure. Drill 7698' to 7943' at midnight, using Dowel! pump at 4 bpm in addition to pump #1 beginning 7854'. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None [~ EP{~~H 52 GonocoPhiilips Alaska fnc. NPf~A Exploration We11 Noatak #1 Report for: Mike Winfrey 1 Dink Heim Dick Owens Date: 315/07 Time: 00:00 Current Depth: 8100 Operation: Yesterdays Depth: 7943 24 hr Footage: 157 • Drilling Parameters MADD Pass ROP: Current: 15 Max: 139 Tor ue: Current: 3112 Max: 17804 WOB: Current 2 Max: 34 RPM: Current: 151 Max: 175 PP: Current: 2985 Max: 3061 La Strokes: 9968 Time: 66.0 Circulation: Strokes: 11737 Time: 77.7 ECD: Current: 11.4 Max: 11.5 Mud Properties MW: 11.3 FV: 65 PV 33 YP: 33 FL: 2.6 Gels: 51719 Sof: 15 H: 9.3 CI-~ 25000 Ca+ ~ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 13u Max: 79u De the 7956' Comas Events Tri Gas De th TG C1 C2 C3 C4! C4N C51 C5N N!A Connection Gas De th TG C1 C2 C3 C41 C4N C5! C5N Q 8057' De th TG C1 C2 G3 C4t C4N C5t C5N Peaks Gas Sam les No. De th TG C1 C2 C3 C4! C4N G51 C5N Lithotogies: Current: 80°~ Shale, 20°~ Siltstone Last 24 hrs: 70°1o Shale, 10% Ctaystone, 15°~ Siltstone, 5°~ Sand Drill from 7943' to 8029' using Dowell pump with pump #1 after 7950'. Operational Summary: Circulate out and MADD pass 7950' to 8029'. Wait on orders to drill ahead. Drill to 8084 ,add Dowell pump and drill to 8100 . Circulate out, MADD pass 8084' to 8100' at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None [~ EPOCH 53 ConocoPhiliips Alaska Inc. NPRA Exploration Well Naatak #1 Report for: Mike Winfrey / Dink Heim Toby Archuleta Date: 3!6/07 Time: 00:00 Current Depth: 8148 Operation: Yesterdays Depth: 8100 24 hr Footage: 48 • Dritlina ParamPtPrG LID BHA ROP: Current: 24 Max: 41 Tor ue: Current: 4133 Max: 5074 WOB: Current 4 Max: 9 RPM: Current: 148 Max: 156 PP: Current: 1710 Max: 2984 La Strokes: 10028 Time: 66.0 Circa{ation: Strokes: 1 i 808 Time: 77.7 ECD: Current: 11.4 Max: 11.5 Mud PranPrties MW: 11.3 FV: 64 PV 29 YP: 25 FL: 2.8 Ge{s: 71819 Sol: 15 H: 9.4 CI"~ 26000 Ca++~ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 18u Max: 29u De the 8124' C-:ac FvPntc Gas Sam les No. De th TG G1 G2 C3 C4{ C4N C51 C5N De th TG C1 C2 C3 C41 C4N C5i C5N Peaks Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N 21u 8148 Connection Gas De th TG C1 C2 C3 C4i C4N C5i C5N 0 8117' Litho{ogies: Current: 40°~ Shale, 50°!o Siltstone, 10°~ Sandstone Last 24 hrs: 50°!o Shale, 40°~ Si{tstone, 10% Sandstone Finish 16' MADD to 8100' just after midnight, and wait on orders to drill ahead. Operational Summary: Drill to 8113', circulate, and drill to 8148', casing depth. Pumped hi vis sweep and circulated out. Wiper trip to 7500. RIH to bottom, pump hi vis sweep, and circulate and condition. POOH to col{ars and begin L/D BHA at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None EP~~H ~ ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Mike Winfrey ! Dink Heim _ Toby Archuleta Date: 3/7107 Time: 00:00 Current Depth: 8148 Operation: RIH with 7" Casing Yesterdays Depth: 8148 24 hr Footage: 0 :~ Drilling Parameters ROP: Current: Max: To ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 4734 Time: 61.5 Circulation: Strokes: 11381 Time: 147.8 ECD: Curren#: 11.5 Max: 11.5 Mutt Properties MW: 11.2 FV: 55 PV 29 YP: 26 Ft_: 2.6 Gels: 6/719 Sok 15.0 H: 9.3 CI"~ 24000 Ca++~ 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 49u dis laced mud Max: 49u De the Casin 5370' dis laced mud Gas Events Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Peaks Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C5i C5N Lithologies: Current: 40°~ Shale, 50°~ Siltstone, 10°lo Sandstone on bottom last 24 hrs: N/A Operational Summary: UD BHA and download MWD. Rig up to run casing, thaw flowline, and RtH with 7 casing to 5370 at midnight, circulating volume at 2000 and 2970'. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~~~~H 55 GonocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 . Report for: Mike Winfrey /Ray Springer Toby Archuleta Date: 318107 Time: 00:00 Current Depth: 8148 Operation: Change Rams Yesterdays Depth: 8148 24 hr Footage: 0 Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 4734 Time: 61.5 Circulation: Strokes: 11381 Time: 147.8 ECD: Current: 11.5 Max: 11.5 Mind Pmoerties MW: 11.3 FV: 59 PV 29 YP: 24 FL: 2.9 Gels: 61819 Sol: 15.0 H: 9.0 Ci'~ 23004 Ca'+~ NID MW Change: Mud Loss event: Depth: From: Depth: Volume: To: Reason: Gas Data Ditch Gas: Current: 48u after cement Max: 297u De the Casin 'oint 8085' C;ac Fvants Tri Gas De th TG G1 C2 C3 C41 C4N C51 C5N 297u 8148' 50239 3900 2159 272 539 130 150 Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N Peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 40°~ Shale, 50°~ Siltstone, 10°~ Sandstone on bottom Last 24 hrs: NIA RIH with 7" casing from 5370' to 7020', pump volume and clean hole, maximum 75 units to 18 units when shut off pumps. RIH to 8081' at 6:20 am. Wash casing from 8081' to bottom at 8148' at 11:35 am, 297units bottoms up after 8085' joint, 215 units bottoms up after 8127', and 87 units when finish Operational Summary: circulating. Make up hanger and cement head. Circulate and condition 3:10 pm to 4:41 pm, 257 units bottoms up, to 70 units when finish circulating. Test lines to 2500 psi and commence cement procedures, 288 units bottoms up, to 48 units when finish circulating. Finish cement procedures and rig down at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None - [~ EPC)C~-I ConocoPhiNips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Mike Winfrey /Ray Springer Toby Archuleta Date: 3/9107 Time: 00:00 Current Depth: 8148 Operation: Trip in Yesterdays Depth: 8148 24 hr Footage: 0 Drilfina Parameters ROP: Current: Max: To ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3$29 Time: N/A Circulation: Strokes: 5750 Time: NIA ECD: Current: Max: Mud Prr~~ertirac MW: 9.9 FV: 50 PV 14 YP: 23 FL: 4.3 Gels: 4/6/8 SoL• 11.0 H: 9.7 CI"~ 14500 Ca~~ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De the Gas Events Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C4f C4N C5t C5N Peaks I Depth 4 TG I C1 l C2 I C3 I C41 I C4N ( C5t # C5N f No. ! Depth I TG I C1 I C2 I C3 I Cot I C4N ( C51 } C5N I Lithologies: Current: 40°1o Shale, 50°~ Siltstone, 10°~ Sandstone on bottom Last 24 hrs: N/A Operational Summary: Change rams, test BOP, work on motor for mud pump, and thaw out top drive. Make up BHA and test MWD at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~PCJ~H 57 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Mike Winfrey I Ray Springer Toby Archuleta Date: 3/10/07 Time: 00:00 Current Depth: 8148 Operation: Drill shoe track Yesterdays Depth: 8148 24 hr Footage: 0 Drillino Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3898 Time: 35.8 Circulation: Strokes: 5772 Time: 53.0 ECD: Current: Max: Mud Properties MW: 9.8 FV: 66 PV 14 YP: 23 FL: 3.6 Gels: 617/8 Sol: 7.5 H: 9.5 Cr= 27500 Ca++- 40 MW Change: Depth: From: To: Reason: Mud Lass event: Depth: Volume: Gas Data Ditch Gas: Current: 25u Max: 214u De the Bottoms u after drill throw h float teas Fvents Peaks Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 40°~ Shale, 50°~ Siltstone, 10°~ Sandstone on bottom Last 24 hrs: NIA Finish MIU BHA and RIH with 4" DP to shoe track at noon. Cut and slip drill Operational Summary: line. Test casing to 2500 psi. Begin drilling shoe track, bottoms up 214 units at midnight lagged from under float. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None [~ El'C~~H 58 ConocoPhillips Alaska Inc. NPRA Exploration Welf Noatak #1 Report for: Mike Winfrey /Ray Springer Toby Archuleta Date: 3/11/07 Time: 00:00 Curre Yeste 24 hr Drilling Parameters nt Depth: 8313 Operation: Girculatiog rdays Depth: 8148 Footage: 165 • ROP: Current: 23 Max: 208 Tor ue: Current: 1449 Max: 5162 WOB: Current 3 Max: 23 RPM: Current: 77 Max: 86 PP: Current: 1491 Max: 2450 La Strokes: 3898 Time: 35.8 Circulation: Strokes: 5772 Time: 53.0 ECD: Current: 10.4 Max: 10.5 Mud MW Change: Depth: 8148 From: 11.3 To: 9.9 Reason: Alpine MW Change: Depth: 8225 From: 9.9 Ta: 9.5 Reason: Mud loss Mud Loss event: Depth: 8190-8313 Volume: 338 Gas Data Ditch Gas: Current: 269u Max: 1312u De the 8295 ras Fvents Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG G1 C2 C3 C41 C4N C51 C5N 850 $317 De th TG C1 C2 C3 C41 C4N C5! C5N See below Peaks Gas Sam les No. De th TG C1 C2 C3 C4i C4N C51 C5N 39 8160 15 1597 194 93 12 30 12 7 40 8170 18 1904 230 108 23 38 12 15 41 8180 20 2014 254 118 18 31 6 $ 42 8190 DISCARD DUE LAG ADJUSTMENTS 43 8188 87 10664 1339 539 65 111 32 16 44 8202 DISCARD DUE LAG ADJUSTMENTS 45 8190 223 33547 4972 2090 241 377 8$ 86 46 8195 546 195012 37913 16114 1686 2613 535 532 47 8205 567 101021 47978 17043 1821 2906 635 650 48 8225 C.G. 750 225576 45551 20182 2114 3309 684 640 49 8232 205 30911 5406 2907 387 638 170 171 50 8243 260 49463 9589 4876 632 1031 281 333 51 8253 350 89491 17080 8185 1004 1588 421 472 52 8266 390 126293 29261 10602 1201 1939" 442 408 53 8280 245 39716 6906 3431 423 709 171 151 54 8295 1300 268275 97104 57428 7911 13378 3222 3327 55 8298 670 219219 57580 32500 3874 6783 1575 1645 56 8310 575 192577 48041 47616 3391 6024 1371 1696 Lithologies: 50°~ Sandstone, 10°~ Sand, 30% Siltstone, 10°~ Shale Current: 70% Sandstane, 20% Sand, 10% Shale Last 24 hrs: N/A ~ EPOCH 59 Drill to shoe and circulate, gas down to 11 units. No cement returns, test casing. Displace old 11.3 mud to new 9.8 mud, and driN out shoe. Drill from 8148' to 8190', losing mud {-60bbls}. Circulate and pump pill with reduced flow. Operational Summary: Drill from 8190' to 8313', and circulating after high gas, 1340 units, at midnight. Lasing mud while drilling, and arcxakating and building mud volume with reduced flow at 8225'(-95bbls}, 8283'(-135}, 8287'(-10}, and 8313'(-38), and reducing MW 9.9 to 9.6 at 8225'. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~~ ~P~JCH so ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Mike Winfrey /Ray Springer Toby Archuleta Date: 3112107 Time: 00:00 Current Depth: 8425 Operation: Circulating Yesterdays Depth: 8313 24 hr Footage: 112 DritGna Parameters ROP: Current: 47 Max: 179 To ue: Current: 2177 Max: 6762 WOB: Current 6 Max: 32 RPM: Current: 53 Max: 95 PP: Current: 2060 Max: 3004 La Strokes: 4020 Time: 191 Circulation: Strokes: 5950 Time: 282 ECD: Current: 10.3 Max: 10.4 MEd PrnrsPrties MW: 10.0 FV: 54 PV 20 YP: 26 FL: 3.2 Gels: 10/12/15 Sol: 9.0 H: 9.3 Cl"~ 27500 Ca +~ 40 MW Change: Depth: 8425 From: 9.5 To: 10A Reason: Flowing Mud Loss event: Depth: 8425 Volume: 705 Gas Data Ditch Gas: Current: 53u Max: 891 u De the 8349 C~ac Gvanfc Tri Gas De th TG C1 C2 C3 C4l C4N C51 C5N Connection Gas De th TG C1 C2 C3 C4l C4N C5l C5N 780 8412 De th TG C1 C2 C3 C4l C4N C5l C5N none peaks Na. De th TG C1 G2 C3 C4l C4N C5l C5N 57 8317 122 10172 2127 1471 292 515 195 188 58 8330 85 7100 1374 858 177 357 144 164 59 $360 50 5235 1104 645 127 275 107 127 60 8375 70 9345 1681 899 178 362 136 163 3as Sam les Lithologies: 30°l° Siltstone, 70°~ Shale Current: 30% Siltstone, 70% Shale Last 24 hrs: NIA Operational Summary: Dri118313 to 8425', total depth at 10:30 hours. Weight up to 10.0 due to well flowing. Lasing mud while circulating and building mud volume. Calibrations: Gafibrated Total Gas and Gas Chromatograph Failures: None EPC~~~-I 61 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for: Mike Winfrey J Ray Springer Wayne Champaine Date: 3/13107 Time: 00:00 Current Depth: 8425 Operation: Rig Up E-log Yesterdays Depth: 8425 24 hr Footage: 0 Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 4020 Time: NIA Circulation: Strokes: 5950 Time: N/A ECD: Current: N/A Max: 10.4 M~ Sri Prnnartiae MW: 10.0 FV: 54 PV 13 YP: 22 FL: 3.4 Gels: 8/10/12 Sol: 9.0 H: 9.6 CI-~ 25500 Ca++~ 40 MW Change; Depth: From: To: Reason: Mud Loss event: Depth: 8425 Volume: 280 Gas Data Ditch Gas: Current: N/A Max: 28u De the Circulatin 8425' (~~e Gven4c • Tri Gas De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas De th TG C1 C2 C3 C41 C4N C51 C5N F~eaKs De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 G4N C51 C5N Lithologies: Current: 30°~ Siltstone, 70°,6 Shaie (ON BOTTOM) Last 24 hrs: NIA • Finish weight up to 10.0 due to well flowing. Losing mud while circulating and Operational Summary: building mud volume. POOH to collars 4:20 to 16:30 hrs. POOH and UD collars, download MWD, and rig up for a-logs at midnight. Calibrations: Calibrated Total Gas and Gas Chromatograph Failures: None ~1 EPC)CH 62 ConocoPhillips Alaska Inc. NPRA Exploration Well Noatak #1 Report for. Mike Winfrey /Ray Springer Wayne Champaine Date: 3114107 Time: 00:00 Current Depth: 8425 Operation: Trip in for Plug Well Yesterdays Depth: 8425 24 hr Footage: -0 r)ri{iinn Paramatprc ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 4020 Time: N/A Circulation: Strokes: 5950 Time: N/A ECD: Current: N/A Max: N/A Mi ~rl Prnnartiac MW: 10.0 FV: 57 PV 12 YP: 21 FL: 4.4 Gels: 7114/11 Sal: 9A H: 9.4 CI ~ 27000 Ca+~~ 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 8425 Vaiume: 1 bb!/hr Gas Data Ditch Gas: Current: 1 u Max: 1 u De the Circulate at shoe (sae Fvcntc A Tri Gas De th TG C1 C2 C3 C4i C4N C5i C5N Connection Gas De th TG C1 C2 C3 C4f C4N C51 C5N peaks De th TG C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th TG C1 C2 C3 C41 C4N C51 C5N Lithatogies: Current: 30°~ Siltstone, 70°~ Shale {ON BOTTOM) Last 24 hrs: N/A Run two a-logs and sidewall cores. Lay down cores and wait on orders. Begin Operational Summary: trip in to plug well at 9 pm. Tripping in at midnight and 6 am. EPOCH RELEASED TO R1G DOWN 8 am. Calibrations: Calibrated Total Gas and Gas Chromatagraph Failures: None [~ ~1'(~~H 63
