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Home My WebLink About206-014• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q ~ - ~ ~ ~- Well History File Identifier Organizing (aone> RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: M ~ ~ x 30 = ~~ + ~ =TOTAL PAGES_~ (Count does not include cover sheet) _- Date: ~n I (,.~.. O ~ lsl Production Scanning r IIIIIIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: _ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date:/ ~~D V /s/ r Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III () II II I II II I I III Re3canned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III II'I III ~,.~,a~ iuiiiiiiiuiuim DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: f Q Date: ~iiiumuii~if6 /s/ ae=~,~~~,aed iiiuiiiiiuiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other.: P P 10/6/2005 well History File Cover Page.doc Schwartz, Guy L (DOA) From: Rauchenstein, Jessica [Jessica.Rauchenstein@pxd.com] Sent: Monday, August 02, 2010 12:58 PM To: Schwartz, Guy L (DOA) Cc: Campoamor, Kathy; Hazzard, Vance; Smith, Bonnie Subject: RE: Cronus No. 1 and Hailstorm No. 1 • Page 1 of 2 ~-~ a p~- o ~ `f Attachments: Pioneer Field Trip Report 08-08-06.pdf; Email Coorespondence for Agency Tundra Inspection August 2006.pdf Hetlo Mr. Schwartz, As requested, we reviewed our records and confirmed that Cronus #1 and Hailstorm #2 site areas were inspected fall 2006. As part of our review, we noted the following: 1. Email correspondence with ADNR staff regarding scheduling the site visit the week of August 7, 2006 (attached) 2. Field trip report from site visit August 8, 2006 (attached), which included: o List of attendees: R. Lewellen (Pioneer Consultant), D. Graika (Pioneer Representative), and G. Schultz and L. Byrne (ADNR) o Summary of site visit o Discussion regarding terrain and tundra vegetation o GPS coordinates o Discussion of photo log and photographs taken by R. Lewellen during site visit July 26, 2006 3. Completion reports dated 09-18-06 submitted to ADNR and NSB which included reference to final site inspection conducted with ADNR 4. Semi-annual status reports dated 10-31-06 submitted to ADNR DOG which stated no activities had been conducted for the reporting period If you have any further question, please contact us. Thank you, Jessica Rauchenstein ~,<!~'~k~ ~ ~_, U i,~ ~; ~ 2 ~11r# Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Office (907) 343-2171 Cell (907) 903-1380 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, July 27, 2010 10:15 AM To: Campoamor, Kathy Subject: Cronus No. 1 and Hailstorm No. 1 Could you please confirm that Cronus No. 1 and Hailstorm No. 1 have had site visits documented since the P &A's were completed back in 2006. There is nothing in our file such as follow-up pictures of the area..... Thanks, 8/2/2010 • • Page 2 of 2 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (ofFce) 444-3433 (cell) This email was sent on 7/28/10 at 2:52 PM by rauchenj. This email was sent on 7/28/10 at 4:26 PM by rauchenj. This email was sent on 7/29!10 at 5:15 PM by rauchenj. This email was sent on 8/2/10 at 12:57 PM by rauchenj. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 8/2/2010 r~ L • Smith, Bonnie From: Smith, Bonnie Sent: Tuesday, July 27, 2010 8:35 PM To: Smith, Bonnie Subject: FW: PNR Tundra Travel Routes Inspection -----Original Message----- From: AES - LYNX Pioneer Environmental [mailto:PioneerEnvironmental(lasrcenergy.com] Sent: Thursday, 7uly 13, 2006 5:24 PM To: john_easton~dnr.state.ak.us Cc: Steve Schmitz; Aaron A. Weaver; john R. Easton; AES - LYNX Pioneer Environmental; Smith, Bonnie Subject: RE: PNR Tundra Travel Routes Inspection Hi ]ohn, We have Gary Schultz and Larry Bryne scheduled for the week of August 7th and were hoping a representative of DOG and Waska with the NSB would also be available that week. As for the dates you mentioned below, we will check on the helicopter availability. Keep us posted if something changes. and we will look into the helicopter schedule. Thanks, Don D'on Graika / Zane Henning PNR Oooguruk Field Env. Coordinators Ph. (987) 240-4687 Email: PioneerEnvironmentaltaasrcener~y.com From: ]ohn Easton [mailto:john_easton(kinr.state.ak.us] Sent: Tue 7/11/2006 4:54 PM To: Bonnie.Smith~pxd.com; AES -LYNX Pioneer Environmental Cc: Steve Schmitz; Aaron A. Weaver; john R. Easton Subject: RE: PNR Tundra Travel Routes Inspection Don, Thanks for the invite; I wanted to let you know that I am scheduled to be on the Slope 7uly 31st thru Aug 4th and Aaron Weaver will be on the slope August 21st thru the 25th. Please let us know if is possible to get Aaron or myself out to the exploration sites / travel corridors for site inspections. Talk with you later. John Easton 269-8815 -----Original Message----- From: Steve Schmitz [mailto:steve_schmitz@dnr.state.ak.us] • • Sent: Friday, Tune 30, 2006 4:25 PM To: john R. Easton; Aaron A. Weaver Cc: Steve Schmitz Subject: FW: PNR Tundra Travel Routes Inspection -----Original Message----- From: AES - LYNX Pioneer Environmental [mailto:PioneerEnvironmental(lasrcenergy.com] Sent: Friday, Tune 30, 2006 4:19 PM To: Waska.Wiliiams@north-slope.org; Steve Schmitz; Aaron A. Weaver Cc: AES - LYNX Pioneer Environmental; Smith, Bonnie; Vance.Hazard(~pxd.com Subject: PNR Tundra Travel Routes Inspection Waska, Steve, and Aaron: Would August 9th or 10th work for you to view PNR's tundra travel routes and exploration locations. If not, please let me know what dates will work for you. Thanks, Don Don Graika / Zane Henning PNR Oooguruk Field Env. Coordinators Ph. (907) 240-4687 Email: PioneerEnvironmental(atasrcenereY.com This email has been scanned by the MessageLabs Email Security System. For more information please visit http://www.messa~eiabs.comlemail z i FIELD TRIP REPORT ON CRONUS WINTER ICE ROAD Submitted to: Pioneer Natural Resources Alaska, Inc. Date of Examination: 8 August 2006 Field Investigator: Robert Lewellen, Ph.D. Accompanying Pioneer Representative: Don Graka. ~~ ~J Utilizing helicopter support, Lewellen and Graka examined the tundra conditions at the Cronus project location. Also, on site, were Gary Schultz and Larry Byrne of DNR, State of Alaska. From the air, approaching with the helicopter, we were unable to spot any disturbance. The pilots finally located the drill pad well site and landed. The four of us walked over the tundra and completely missed the disturbed areas between the drill pad and the water source lake. Lewellen finally found the old GPS point and got back to where the disturbance was examined on July 26, 2006. The field examination revealed a significant regrowth of new sprouts; compare the photographs from 26 July versus 8 August. I cannot see any long term problems with this drill site and associated roads. Gary Schultz told me that he did not think there was any long term disturbance. We all agreed that the problem was the travel over a tundra terrain which did not have an adequate processed snow cover. Larry Byrne mentioned that there were differences between the terrain at Hailstorm and the terrain at Cronus. He was pointing out the relative smooth wet sedge meadows of Hailstorm and the tussock dominated areas of Cronus. He was implying that the road construction techniques had to be different. The difference in terrain is not of any significance because any type of tundra terrain has to be protected. It is the degree of work and snow/ice material required to provide the protection. The road building techniques are the same from Alaska to Minnesota and Canada to Finland. When I left Prudhoe, I saw Dave Cruz in the airport. He brought up the Cronus site voluntarily. He mentioned something about the Volvo water trucks were out of the road alignment, and traveling on tundra which had insufficient protection. The information in my report of 26 July is still valid; there was a lack of training for the individual equipment operators and a lack of supervision. Any operator should know when to stop his equipment and notify the supervisor there is a problem with inadequate tundra protection. Lewellen Arctic Research, Inc. Pioneer Sites Visited July and August 2006 Datum: NAD 2? Alaska Thaw season field investigation. Wa Point Created Latitude Lon itude Site 2 CRTD 07:30 26-JUL-06 N70 03 59.8 W150 42 07.8 Cronus 3 CRTD 07:52 26-JUL-06 N70 03 58.8 W150 41 52.9 Cronus 4 CRTD 08:15 26-JUL-06 N70 03 58.8 W150 41 52.9 Cronus 6 CRTD 08:27 26-JUL-06 N70 09 55.0 W148 46 54.9 Hailstorm 7 CRTD 11:37 08-AUG-06 N70 03 59.4 W150 41 59.8 Cronus 8 CRTD 11:41 08-AUG-06 N70 03 59.2 W150 42 05.1 Cronus The photographs taken on 8 August are self explanatory as a comparison with the earlier photos of 26 July (the helicopter is sitting on the site of the drill pad near the well bore). However, one interesting aspect appears in photo image # 1397. When I turned over this piece of tussock (which had been separated from a tussock) the vegetation had sprouted on the side lying against the tundra. surface. The plants were growing on both the fragment and on the tundra surface, but were light green, and yellow from the lack of sun. But, the plants were growing. The dark aspect of this fragment is because the tussock was predominately made of peaty organic material and very little mineral soil. END 2 Lewedlen Arctic Research, Inc. • '~,, ` .~ `~`. ~' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER T-.HIS PAG E C;\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~ DATA SUBMITTAL COMPLIANCE REPORT 5!20/2008 Permit to Drill 2060140 Well Name/No. CRONUS 1 Operator PIONEER NATURAL RESOURCES AL API No. 50-103-20523-00-00 MD 7941 TVD 7920 Completion Date 3/28/2006 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR, DSL, XMAC, HDIL, ZDL/CN, MR EX, RCOR (data t aken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Sonic 25 Col 2437 7927 Open 4/25/2006 Multipole Array Acoustilog 4-Apr-2006 ,lJe6'g „CO(ud Log 1 Col Open 4/25/2006 Engineering Log 1"!100' Measured Depth ,Fjpt Sample Open 6/29/2006 CoreLabs -Conventional ', (/~ Core Analysis ~Rpt Report: Final Well R Col 0 0 Open 4/25/2006 Transmittal, Gen Info, !~ Daily Sum, Morn Rep, Bit ', Rec, Mud Rep, Show Rep, ', Days vrs. Depth, Surv ', Rep -Baker Info. 1-Mar- ~~ D C Las 13828 Report: Final Well R 0 0 Open 4/25/2006 2006 Gen Info, Daily Sum, Morn ', Rep, Bit Rec, Mud Rep, Show Rep, Days vrs. Depth, Surv Rep -Baker Info. 1-Mar-2006 I~g Mud Log 1 Col 1 -4 98 7912 Open 4/25/2006 Combo Mud Log 1-Mar- 2006 tr.og Mud Log 2 Col 1 -4 98 7912 Open 4/25/2006 Combo Mud Log 1-Mar- 2006 // Cog Mud Log 5 Col 1 - 4 98 7912 Open 4/25/2006 Combo Mud Log i-Mar- 2006 ' Log Mud Log 1 Col 1 - 4 98 7912 Open 4/25/2006 Gas Ratio Show log 1-Mar- , / 2006 ' uiL.og /Pressure 1 Col Open 4/25!2006 Engineering log Well ~ ' r Diagram -Pore Pressure ~ ~ Log Sonic 2 Col 2437 7927 Open 4/25/2006 Multipole Array Acoustilog Azimuthal Anisotropy ~ l .. __ __ Analysis 23-Mar-2006 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060140 Well Name/No. CRONUS 1 Operator PIONEER NATURAL RESOURCES AL API No. 50-103-20523-00-00 MD 7941 TVD 7920 Completion Date 3/28/2006 Completion Status P&A Current Status P&A UIC N D C Las 13832 Sonic 2 2437 7927 Open 4/25/2006 Multipole Array Acoustilog ' ', Azimuthal Anisotropy Analysis 23-Mar-2006 ~,efg Magnetic Resonance 5 Col 3 6200 7942 Open 4/25/2006 Explorer Log 19-Mar-2006 G/`v C Las 13833 Magnetic Resonance 5 3 6200 7942 Open 4/25/2006 Explorer Log 19-Mar-2006 l,Xog Directional Survey Col 1 0 2500 Open 4/25/2006 DS 3-Mar-2006 ', ED C Las 13833 Directional Survey 1 0 2500 Open 4/25/2006 DS 3-Mar-2006 • L9g Gai y S~.t~ 5 Col 3 6268 7812 Open 4/25/2006 Rotary Sidewall Coring ~ ~„~/~ Tool 20-Mar-2006 1~ED C Las 13833 Gamma Ray 5 3 6268 7812 Open 4/25/2006 Rotary Sidewall Coring Too120-Mar-2006 Induction/Resistivity 25 Col 1 0 2500 Open 4/25/2006 High Def Induction Log, !, Compensated Z-Densilog, i '~ Comp Neutron Log, ' GR/Caliper 5-Mar-2006 C Las 13833 Induction/Resistivity 25 1 0 2500 Open 4/25/2006 High Def Induction Log, i Compensated Z-Densilog, Comp Neutron Log, ~ GR/Caliper 5-Mar-2006 Gamma Ray 25 Col 1 0 2500 Open 4/25/2006 Xmac Elite GR 5-Mar-2006 C Las 13833 Gamma Ray 25 1 0 2500 Open 4/25/2006 Xmac Elite GR 5-Mar-2006 ~,,le6g ySa~+c Sa.- Il1o~~1 125 Col 1 0 2500 Open 4/25/2006 Dig Spectralog 5-Mar-2005 C Las 13833 N,-T~ ~ Senic S w 125 1 0 2500 Open 4/25/2006 Dig Spectralog 5-Mar-2005 ~~ C Pdf 13971 Sample Open 6/29/2006 CoreLabs -Conventional ! Core Analysis PDF, Excel C Exc 13972 Sample 0 0 Open 6/29/2006 Core Lab -Grain Size (apt 13971 Sample 0 0 Open 6/29/2006 CoreLabs -Conventional Core Analysis ~t __ _ 13972 Sample __ _ 0 0 Open 6/29/2006 Core Lab -Grain Size Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent R eceived Number Comments Cuttings 0 7940 3/22/2006 1214 Cores a nd/or Samples are required to be v submitted. This record automatically created from Pe rmit to Drill Module on: 2/8/2006. DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060140 Well Name/No. CRONUS 1 Operator PIONEER NATURAL RESOURCES AL API No. 50-103-20523-00-00 J MD 7941 TVD 7920 Completion Date 3/28/2006 Completion Status P&A Current Status P&A UIC N ADDITIONAL INFORMATION Well Cored? ®/ N '~ e'~ev.1 ~ ~ ~ t ~~.,(,~ Daily History Received? ~ N Chips Received? -~'tQ'"' Formation Tops ~/ N Analysis ~/ N Received? Comments: _ _ __ - _ _ - O`~ - - _ - ~t1`JV Compliance Reviewed By: __ _ _ _ Date __ • Maunder, Thomas E (DOAj From: Gary Schultz [gary_schultz@dnr.state.ak.us] Sent: Thursday, June 21, 2007 12:02 PM To: Steve Schmitz Cc: 'Larry Byrne'; Aaron A. Weaver; 'leonl ; 'Thomas Maunder' Subject: Re: Pioneer Cronus lease Surrender Page 1 of 2 aoc~-o~y Steve, I agree that AOGCC and DNR have overlapping jurisdiction with the well head locations. As the manager of the surface estate, we should not abdicate our responsibilities as the land manager just because there is an agency with overlapping authority. We can certainly use the AOGCC inspection information as a basis for making our decisions. However, we should not release the lessee until the conditions of the lease are satisfied. If Pioneer really wants to get out of the lease, maybe we could have Pioneer get a land use permit to cover the restoration of the well bare and any other surface disturbance issues on the lease. They could sign a restoration agreement and post a band.... Gary Steve Schmitz wrote: Gary The "method' is to let AOGCC do their job. It's part of their inspection list to ensure there is a mound and that it's not a pond. If it's not performing when they do their Location Clearance, they don't sign off on the LC until the lessee demonstrates compliance. It may take another trip or photos may do. I don't know how they tie up that loose end, but they are pretty good at it so far. Tom Maunder can respond better or one of the inspectors. In the real world, you won't know for several years after if the mound is performing or not. In the end, I suspect they will fix it if a subsequent visit indicates it's necessary. Especially if they are still doing business up here which Pioneer will be for at least a while. Tom-is Cronus on your list of sites to hit this summer? !f so, let us know and we can either come along or get your report. Please let Lands know too as they may be up there the week you guys go out and could go along. The lessee wants to cut the lease loose and we need to know the condition of the site one way or another. Steve From: Gary Schultz [malto:gary_schultz@dnr.sta_te.ak_.us] Sent: Thursday, June 14, 2007 11:42 AM To: Larry Byrne Cc: 'Aaron Weaver'; leonl; Steve Schmitz Subject: Re: Pioneer Cronus Lease Surrender Aaron, ~~`~ ~/" 8/8/2007 '~-' Page ~ of 2 • I don't have any photos of the pad area. One question I have is that when they drr)t they disturb an area around the weft bore. This area is backfilled and needs to be monitored to verify that there is no ponding and is revegetated. Does DO&G have a method to make sure that this takes place if the lease is terminated? Gary Larry Byrne wrote: Aaron, Gary and I along with Don Graika and Bob Lewellen were there the summer after the well was sunk. If you are not aware, we had a real problem with Cruz Construction concerning tundra damage in conjunction with the ice road. We had to issue a letter of violation to them. Gary may have some photos of the pad area. t thought I did but can't find them. You may want to ask Don Graika about the trip out there and his recollection. Sincerely, Larry Byrne From: Aaron Weaver [mailto;aaron_weaver~dnr.state_ak.us] Sent: Monday, June 11, 2007 10:48 AM To: gary schultz@dnr.state._ak.us; larry_byrne@dnr.state.ak.us; 'Leon Lynch' Cc: Steve Schmitz; John R. Easton Subject: Pioneer Cronus Lease Surrender Larry, Leon, & Gary: The Division has received a request to surrender teases associated with the Cronus Unit. Specifically: ADL 389161 and 389056. We are trying to find out if any one of you have been out to inspect the site during the summer. Pioneer has historically done a pretty good job in cleaning up their sites, but we want to ensure that at feast one state representative has visited the site. Have any of you been there during the summertime? if not, either Steve, John or !will try to make our way out there this summer. Thanks in advance, t will be on the slope this week so if you want to chat, calf the slope office number 659-2830. Aaron Weaver 269-8804work 229-5147ce11 8/8/2007 Re: FW: Lease Surrenders • . Subject: Re: FW: Lease Sun•enders From: Thomas Maunder <tom_maunder@atmin.state.ak.us> Date: Mon, 04 Jun 2007 10:05:46-0800 '1'0::aarorz ~~"~~w,:r- ~~~ir€~~~ wc~~~~r'~r;dnr.sta~e.ak.us-= CC: St~~~e tich~~litr s~~~l;dnr.tit~itc.ak.us=-, AOGCC i~urth Slope Oflicc ~~-a~~~~cchrudhoe bav~cr,uhr~in.state.ak.us> Aaron and Steve, I have examined our file and I do not find any record that an AOGCC Inspector has visited this well site during either summer 2006 or 2007. We do have one photo provided by ConocoPhillips taken August 12, 2006 that shows a graveled area with a survey stick in the middle of a "puddle/pond". It is possible that the survey stick is marking the well location. According to the records that are available, the well was properly plugged and abandoned. An AOGCC Inspector witnessed the tag of the cement plug set at the surface casing shoe and another Inspector was present when the wellhead was cutoff. It would be appropriate to visit the well location as planned.. When a schedule is determined, please let us know and we can determine if an Inspector might be available to accompany you. Call or message with any questions. Tom Maunder, PE AOGCC Aaron Weaver wrote, On 6/1/2007 1:59 PM: T€x, Per Steve's instructioc~, I am requesting your assistanec ita Landing gut if t'kOGCC dad a location clearance at tl~e Cronus 1 Tnit_ -- f=11)I:., J89161 ~ 38906. Tl~e unit O®~ners are requesting a lease surredc;r and eve need to find. caul ifs anyone has inspected the site in the summer in orde~• to be comfortable with the le;~see's surrendering of the leases. Either John, Step-e or 1 wilt inspect. flee area. this scorrimer, unless AOGCC has already been to the site during the sulnrnertime and determined that the area ~~°as sufficiently clew€i. 'T`hanks in advance. t~aron Weaver 26~)-8804 From: Steve Schmitz [maiito:steve schmitz@dnr.state.ak.us] Sent: Friday, May 25, 2007 11:43 AM To: Aaron A. Weaver Cc: John R. Easton; Jeanne M. Frazier; Temple Davidson' Subject: FW: Lease Surrenders flacon 1?lease reply to Tom b`~ sometime next week regarding the ADL's mentioned belodv. Whey drilled one i~-ell ar~d we should reply to "1'om tivith d~~hat ADL that was on and the LOINS #, ~~~here it teas, and any coanents we hatre regarding the visits we made. Did you or Sohn get €>ut: to this site last sumnaea- for a post seascxl look`?). I.~o€~k at the ale for a c.ompietion rep€~rt. A.lsc~, contact /~t)C:aCC:". t€~ find out iftey dicl a location cleara~~ce. Steve 1 of 2 6/4/2007 10:24 AM Re: FW: Lease Surrenders ~_~ • From: Tom Dearlove [maifto:thomas dearfove~dnr.state.ak.us] Sent: Friday, May 25, 2007 10:02 AM To: Steve Schmitz Cc: ~onne_sfemonsC~dnr.state.afc.us Subject: Lease Surrenders Dear Steve: As per our phone conversation yesterday, I wanted to inform you that the following leases have a request for surrender from Pioneer Natural Resources Alaska, Inc.: Received May 24, 2007 • Request for surrender of leases ADL 389161 & 389056 Cronus Unit, North Slope - Contacted Temple Davidson and she was aware of this action and approves Please advise if you have any conflicts on the Permitting side that need to be addressed before we take action on the above request. Regards, Tom Tom Dearlove Natural Resource Specialist Division of Oil and Gas 550 W. 7th Ave. Suite 800 Anchorage, AK 99501 Phone: (907) 269-8803 Fax: (907) 269-8943 ~v~ti~tiv.do~.cit~r..st_atc:.ak.aas; oily 2 of 2 6/4/2007 10:24 AM r ~,. , ~~z,~ 1: ~~~.. Letter of Transmittal ~°~~ ~,,~~ ~1~~~ Alaska ~ t Uv5 411 c~ Gas ions Aachoraga ~°~»ission Date: June 27, 2006 FROM TO Tavia Bicklein Pioneer Natural Resources 700 G Street, Suite 600 Anchora e, AK 99501 Steve Davies AOGCC 333 W. 7~' Avenue, Suite 100 Anchora e, AK 99501 INFORMATION TRANSMITTED ^ Letter ^ Ma s X Reports ^ A reement x Other: CDs DETAIL QTY DESCRIPTION Cronus #1 1 Copy -Core Analysis CoreLab Report w/ CD 1 Cop -Grain Size/Point Count Summa Michael Wilson Report w/ CD Received by: Date: ~ ~ ~ Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Kim 700 G Street Suite 600, Anchorage AK 99508 907-343-2190 fax ~~ n/`{ I~~°?,";y a ~ ~ u X15 STATE OF ALASKA ALASK AND GAS CONSERVATION COMMIS ~i~ska U-1 ~~ ,~,~, WELL COMPLETION OR RECOMPLETION REPORT AND LO~arj , 1a. Well Status: Oil^ Gas ^ Plugged Q Abandoned Q Suspended ^ WAG ^ 2oaac2s.ios 2oAACZS.iio GINJ^ WINJ^ WDSPL^ No, of Completions One Other 1 b. Well Class: Development ^ Exploratory Service. ^ StratigraphicTest^ 2. Operator Name: Pioneer Natural Resources Alaska Inc. 5. Date Comp., Susp., or Aband.: 03/28/06 12. Permit to Drill Number: 206-014 3. Address: 700 G Street, Suite 600 Anchorage, AK 99501 6. Date Spudded: 03/02/06 13. API Number: 50-103-20523-00 4a. Location of Well (Governmental Section): Surface: 4079' FSL, 3022' FEL, SEC 8, T8N, R6E, UM 7. Date TD Reached: 03/19/06 14. Well Name and Number: Cronus#1 Top of Productive Horizon: N/A 8. KB Elevation (ft): 17T 15. Field/Pool(s): Exploratory Total Depth: 4301' FSL, 3202' FEL, SEC 8, T8N, R6E, UM 9. Plug Back Depth(MD+TVD): Surface 4b. Location of Well (State Base Plane Coordinates): Surface: x- 413055 y- 5874246 zone-aNAO2~ 10. Total Depth (MD +TVD): 7,941' MD / 7,920' TVD 16. Property Designation: ADL 389161 TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 412875 y- 5874469 zone-arvno2~ 11. Depth Where SSSV Set: N/A 17. Land Use Permit: 24013 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1,144' (Approx.) 21. Logs Run: DIR, DSL, XMAC, HDIL, ZDL/CN, MREX, RCOR 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT ~ TOP BOTTOM TOP BOTTOM PULLED 16" 65# H-40 Surface 80' Surface 80' 20" 7J yds Arctic Set 9-5/8" 40# J55 BTC Surface 2,501' Surface 2,501' 12-1/4" 50o sx Class'G', 220 sx Class 'G' plug #1 6,250' 7,941' 8,244' 7,920' 800 sx Class 'G' plug #2 2,381' 2,651' 2,381' 2,650' 125 sx Class 'G' plug #3 5' 155' 5' 155' 85 sx Class 'C' 23. Perforations open to Production (MD +TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~--- Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). - ;' Submit core chips; if none, state "none". 6~f '~, r1~~Y ~ ~ 2~a6 ~ ""~~~~ ~~~f Rotary Cores C 6288', 6301', 6307', 7112', 7117', 7127', 7144', 7153', 7158',7172', 7756', 7250', 7262', 7269', 7282', 7289', 7296', 7347', 7384', 7755', 7756', 7757', 7758', 7759', 7772', 7793', 7797', 7810', 7812'. (Core analysis report to follow) Form 10-407 Revised 12/2003 ~ R ` ~ ~ ~ TINUED ON REVERSE ~j 28. GEOLOGIC MARKER 29. FORMATION TESTS NAME M TVD Include and briefly su a test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None Colville 2,144' 2,144' Top HRZ 7,464' 7,449' LCU 7,761' 7,742' Milluveach 7,852 7,832' 30. List of Attachments: Summary of Daily Drilling Reports, Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vance Hazzard 343-2116 Printed Name: Kathy Campoamor Title: Engineer Tech II I _ ~~~~'~~ Phone: 343-2183 Date: c-' C Signature: ~ ~ ' a ~ ~~ F a ~ 0.~~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item ta: 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 elevation in feet above mean low low water. 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 AOGCG must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. 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: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • • Pioneer Natural Resources Alaska Inc OperatSons S~rirunary Report Legal Well Name: Cronus #1 Common Well Name: Cronus #1 Spud Date: 03/02/06 Contractor Name: Doyon/Akita JV Drilling Rig Release: 03/24/06 Rig Name: Arctic Fox #1 Depth ~ Drilling Mud Date of Report -report time progress Density (TMD) (ft) (ft) (ppg) Operation Summary Descriptions 02/28/06 0 0 8.6 CONTINUE WITH RIG UP AT CRONUS 1. CONTACTED JOHN CRISP W/ AOGCC ~ 0730 HRS FOR 24 HOUR NOTICE ON DIVERTER FUNCTION. 03/01/06 0 0 8.7 COMPLETE R/U. FUNCTION TEST DIVERTER WITNESS BY JOHN CRISP W/ AOGCC. PRE-SPUD MEETING. BEGIN PU BHA. 03/02/06 1,358 1,358 9.2 P/U BHA & CLEAN RIG. TIH & TAG AT 96' RKB. DRILL 12-1/4" HOLE 86' TO 1358'. 03/03/06 990 2,348 9.5 DRILL & SURVEY 1358' TO 1644'. CBU, WIPER TRIP TO 361'. DRILL & SURVEY FROM .1644' TO 2348'. 03/04/06 167 2,515 9.5 DRILL TO TD OF 2515', CBU, WIPER TRIP TO 1644'. CBU, TOOH FOR LOGS. RU LOGGERS, COULD NOT PASS 350'.. POOH WL, TIH BHA & TAG AT 441'. WASH TO 474', TIH. 03/05/06 0 2,515 9.5 TIH, CBU, TOOH. RUN LOGS - OK. RUN 9-5/8" CASING, PREP TO CEMENT 03/06/06 0 2,515 8.9 CMT 9 5/8" CSG W/ 180 BBLS TO SURFACE, RD CEMENTERS. FLUSH DIVERTER & LANDING JT, LD LANDING JT &DIVERTER. INSTALL VETCO WELL HEAD & TEST TO 5000 PSI, NU BOPS. 03/07/06 0 2,515 8.9 NU BOPE & TEST ANNULAR T/ 3500 PSI, WITNESSED BY JOHN SPAULDING W/ AOGCC. PULL TEST PLUG, INSTALL WEAR BUSHING. PU 8-1 /2" BIT & BHA. TIH T/ 2408', TEST CSG, DRILL CMT, FLOAT COLLAR, SHOE TRACK. 03/08/06 726 3,241 8.9 CSG TEST TO 2900 PSI, DRILL FLOAT EQUIP, DRILL 20' NEW HOLE. 16.2 PPG EMW LOT. DRILL F/ 2515' TO 3241'. GYRO SINGLESHOT SURVEY W/BAKER, DRILL AHEAD. 03/09/06 1,274 4,515 8.9 DRILL & SURVEY FROM 3241' TO 4515', WIPER TRIP TO SHOE. 03/10/06 1,013 5,528 9.4 FINISH W IPER TRIP TO BTM. DRILL & SURVEY FROM 4515' TO 5528'. 03/11/06 1,145 6,673 9.8 DRILL & SURVEY FROM 5528' TO 6673', 03/12/06 440 7,113 10 DRILL & SURVEY FROM 6673' TO 7113', TWIST OFF, PU CROSS-OVER, BUMPER SUB, OVERSHOT DRESSED FOR 5", MU FISHING TOOLS &RIH. MILL OVER & ENGAGE FISH f~ 165' RKB, BREAK CIRC. JAR FREE. PREP TO CIRC. 03/13/06 0 7,113 10.1 FISH STUCK PIPE, RECOVER FISH. TOOH & LD DAMAGED DRILLSTRING COMPONENTS. TEST BOPS, WITNESS WAIVED BY CHUCK SCHEVE W/ AOGCC. TIH W/DRILLING BHA. 03/14/06 415 7,528 10 PU HWDP TO REPLACE DAMAGED PIPE &RIH TO 6824'. REAM TO 7113'. DRILL F/ 7113' TO 7528'. STUCK PIPE WHILE MAKING CONNECTION. BIT ~ 7500'. 03/15/06 0 7,528 9.9 CONT TO TORQUE & SLUMP DOWNWARD. FIRE JARS. RU & RUN FREE POINT TOOL. PREP TO RUN BACK OFF CHARGE 03/16/06 0 7,528 9.9 RIH W/ BACK OFF CHARGE. SHOOT CHARGE & BACK OFF ~ 7422'. CBU. HOIST & LD TOOLS. MU &RIH W/MINI SLAM ALTAS TOOLS. LD LOGGING TOOLS & MU FISHING TOOLS. SLIP & CUT DRLG LINE. PU & RE-TORQUE U. KELLY CONN'S. 03/17/06 0 7,528 9.6 MU FISHING TOOLS. RIH. SCREW ONTO FISH & BUMP DOWN FOR APPROX BHRS. NO JAR ACTION AFTER 2 HRS. CUT MW F/ 9.9PPG TO 9.6 PPG. NO SUCCESS FISHING. ATTEMPT TO BACK OUT. JAR UP ONCE & POP FISH FREE. CBU & POH W/ DISH TO 4,826'. 03/18/06 0 7,528 9.6 POH WITH FISH. RECOVER & LD FISH, FULL RECOVERY. RIH WITH DRILLING BHA. PRECAUTION REAM F/ 6,913' TO 7,528'. DRILL F/ 7,528' TO 7,630'., 03/19/06 413 7,941 9.8 DRILL TO FINAL TD ~ 7,941'. WIPER TRIP T/ 6881'. POH FOR WIRELINE LOGS. CLEAR & CLEAN FLOOR. PU & MU WIRELINE LOGS &RIH W/SAME. LOG WELLBORE W/QUAD COMBO. 03/20/06 0 7,941 9.8 LD QUAD COMBO TOOLS. MU ROT CORE TOOL &RIH, ATTEMPT CORES -UNSUCCESSFUL. POH & MU 2ND CORE TOOL &RIH. GET CORES AS REQUIRED. POH & MU MREX TOOL &RIH. RECEIVED 24 HR EXTENSION ON BOP TEST BY TOM MAUNDER W/ AOGCG. Pioneer Natural Resources Page 1 of 2 Cronus #1 Ops Summary • • 03/21/06 0 7,941 9.8 FINISH MREX LOGS & POH SAME. LD TOOLS & RU WIRELINE UNIT. RIH W/ 1300' 2-7/8" DP & CONT IN HOLE W/ 4" DP. RIH TO 7,941' &CBU. RU CEMENTERS & PUMP BOTTOM PLUG, PUMPED 82 BBLS 15.9 PPG CMT. POH 20 STDS SLOWLY TO 6,649'. 03/22/06 0 7,941 9.8 CBU FROM 1ST CMT PLUG. PUMPED 82 BBLS 15.9PPG CMT. 2ND PLUG. POH 18 STDS. CBU. LD 90 JTS 4" DP. PUMP 3RD PLUG C~3 SHOE COVERAGE. POH 6 STDS 4" DP. CBU & WOC 6 HRS.. TAG PLUG C~ 2381', WITNESSED BY JOHN CRISP W/ AOGCC. LD 4" DP FROM DERRICK & OUT OF HOLE. POH TO 155'. CMT 4TH PLUG IN PLACE WITHIN 5' OF SURFACE. 03/23/06 0 7,941 9.8 FLUSHED ALL MUD PUMPS & HIGH PRESSURE LINES. CLEAN FLOOR OF OBM & ND KATCHKAN. ND BOP STACK & NU TREE. LD KELLY & RATHOLE. LD MOUSE HOLE. CONT TO CLEAN OBM FROM PITS. 03/24/06 0 7,941 9.8 FINISH CLEANING OBM FROM TANKS & CELLAR AREAS. RELEASE RIG C~3 1200 HRS. PREPARE FOR RIG MOVE. 03/25/06 0 7,941 CONTINUE TO RD & MOVE RIG OFF CRONUS. 03/26/06 0 7,941 CONTINUE TO MOVE RIG OFF CRONUS. DEMOB RIG & ASSOCIATED EQUIP. 03/27/06 0 7,941 CONT TO DEMOB RIG & EQUIP. HAUL TO CPAI LOCATION. NOTIFIED JEFF JONES W/ AOGCC OF NON-RIG P&A ACTIVITES. BUILT TENT OVER WELLHEAD TO THAW AREA AROUND CELLAR.REMOVE CELLAR & CLEAN OUT MUDS & DEBRIS FROM AROUND TREE. CUT OFF WELLHEAD. CONDUCTOR & INTERIOR TUBULAR CUT OFF 42" BELOW TUNDRA MAT LEVEL. SCRAPE ICE PAD & REMOVE DEBRIS & FROZEN FLUIDS FROM ICE PAD & CELLAR AREAS. 03/28/06 0 7,941 FINISH CLEANING OBM FROM TANKS & CELLAR AREA. FOUND CMT ~ 8'. AOGCC REQUIRED CEMENT TO SURFACE. USED .01 CYD TO BRING ARCTICSET CEMENT TO SURFACE. JEFF JONES W/ AOGCC APPROVED INSTALLATION OF 16" WELDED CAP PLATE. REUSED PREVIOUSLY REMOVED MATERIAL FROM CELLAR TO BACK FILL HOLE. MOUNDED 5' ABOVE TUNDRA LEVEL TO ALLOW FOR SETTLING. Pioneer Natural Resources Page 2 of 2 Cronus #1 Aps Summary Pioneer Natural Resources Alaska, Inca Final Deviation Survey Well Name: CRONUS #1 MD (ft) INCL deg AZIM deg TVD (ft) N+/S- (ft) E+/VI/- (ft) DLS deg/100FT Vertical Section (ft) Survey type 100.00 0.30 273.10 .100.00 0.01 -0.26 0.30 0.3 Sin le shot 150.00 0.40 320.10 150.00 0.16 -0.50 0.59 0.5 Sin le shot 200.00 0.00 6.90 200.00 0.29 -0.62 0.80 0.7 Sin le shot 250.00 0.30 41.70 250.00 0.39 -0.53 0.60 0.7 Sin le shot 300.00 0.30 21.60 300.00 0.61 -0.39 0.21 0.7 Sin le shot 350.00 0.30 16.80 350.00 0.85 -0.31 0.05 0.9 Sin le shot 400.00 0.30 40.30 400.00 1.08 -0.19 0.24 1.1 Sin le shot 450.00 0.50 31.90 449.99 1.36 0.01 0.42 1.4 Sin le shot 500.00 0.10 249.40 499.99 1.53 0.09 1.17 1.5 Sin le shot 550.00 0.40 47.60 549.99 1.64 0.18 0.99 1.6 Sin le shot 600.00 0.50 15.80 599.99 1.96 0.37 0.53 2.0 Sin le shot 650.00 0.50 9.50 649.99 2.39 0.46 0.11 2.4 Sin le shot 700.00 0.40 359.50 699.99 2.78 0.50 0.25 2.8 Sin le shot 750.00 0.20 10.90 749.99 3.04 0.51 0.42 3.1 Sin le shot 800.00 0.50 114.90 799.99 3.03 0.72 1.16 3.1 Sin Ie shot 850.00 0.80 105.90 849.98 2.84 1.26 0.63 3.1 Sin le shot 900.00 0.80 108.30 899.98 2.64 1.93 0.07 3.3 Sin le shot 950.00 0.90 111.00 949.97 2.39 2.62 0.22 3.5 Sin le shot 1000.00 0.90 118.00 999.97 2.06 3.34 0.22 3.9 Sin le shot 1D50.00 1.10 121.00 1049.96 1.63 4.09 0.41 4.4 Sin le shot 1100.00 1.10 121.60 1099,95 1.13 4.92 0.02 5.0 Sin le shot 1150.00 1.50 124.00 1149.94 0.52 5.87 0.81 5.9 .Sin le shot 1200.00 1.40 129.10 1199.92 -0.23 6.88 0.33 6.9 Sin le shot 1250.00 1.40 134.60 1249.91 -1.05 7.79 0.27 7.9 Sin le shot 1300.00 1.50 137.40 1299.89 -1.96 8.67 0.25 8.9 Sin le shot 1350.00 1.50 140.10 1349.87 -2.94 9.53 0.14 10.0 Sin le shot 1400.00 1.40 139.50 1399.86 -3.91 10.35 0.20 11.1 Sin le shot 1450.00 1.50 140.60 1449.84 -4.88 11.16 0.21 12.2 Sin le shot 1500.00 1.50 131.60 1499.82 -5.82 12.07 0.47 13.4 Sin le shot 1550.00 1.60 131.50 1549.81 -6.72 13.08 0.20 14.7 Sin le shot 1600.00 1.60 135.40 1599.79 -7.68 14.09 0.22 16.0 Sin le shot 1650.00 1.50 137.00 1649.77 -8.65 15.03 0.22 17.3 Sin le shot 1700.00 1.50 135.40 1699.75 -9.60 15.93 0.08 18.6 Sin le shot 1750.00 1.40 140.60 1749.74 -10.53 16.78 0.33 1.9.8 Sin le shot 1800.00 1.40 142.90 1799.72 -11.49 17.54 0.11 21.0 Sin le shot 1850.00 1.50 137.50 1849.70 -12.46 18.35 0.34 22.2 Sin le shot 1900.00 1.40 144.30 1899.69 -13.44 19.15 0.40 .23.4 Sin le shot 1950.00 1.50 137.10 1949.67 -14.42 19.95 0.42 24.6 Sin le shot 2000.00 1.40 143.70 1999.66 -15.39 20.75 0.39 .25.8 Sin le shot 2050.00 1.50 141.40 2049.64 -16.39 21.52 0.23 27.1 Sin le shot Pioneer Natural Resources Cronus #1 Page 1 of 3 Deviation Survey • • 2100.00 1.60 139.90 2099.62 -17.44 22.38 0.22 28.4 Sin le shot 2150.00 1.50 144.20 2149.60 -18.50 23.21 0.31 29.7 Sin le shot 2200.00 1.50 142.70 2199.59 -19.55 23.99 0.08 31.0 Sin le shot 2250.00 1.40 143.30 2249.57 -20.56 24.76 0.20 32.2 Sin le shot 2300.00 1.40 143.20 2299.56 -21.54: 25.49 0.00 33.4 Sin le shot 2350.00 1.30 146.40 2349.54 -22.51 26.17 0.25 34.5 Sin le shot 2400.00 1.20 148.70 2399.53 -23.42 26.75 0.22 35.6 Sin le shot 2450.00 1.10 153.50 2449.52 -24.30 27.24 0.28 36.5 Sin le shot 2496.00 1.30 96.30 2495.51 -24.75 27.95 2.53 37.3 Sin le shot 2508.00 1.40 154.10 .2507.51 -24.90 28.15 10.90 37.6 Sin le shot 2558.00 1.40 150.60 2557.49 -25.98 28.72 0.17 38.7 Sin le shot 2608.00 1.40 149.50 2607.48 -27.04 29.33 0.05 39.9 Sin le shot 2658.00 1.20 153.20 2657.47 -28.03 29.88 0.43 .41.0 Sin le shot 2708.00 1.10 .157.60 2707.46 -28.95 30.30 0.27 41.9 Sin le shot 2758.00. 0.90 159.30 2757.45 -29.76 30.62 0.40 42.7 Sin le shot 2808.00 0.80 161.60 2807.44 -30.46 30.87 0.21 43.4 Sin le shof .2858.00 0.70 159.70 2857.44 -31.07 31.08 0.21 44.0 Sin le shot 2908.00 0.70 165.10 2907.43 -31.65 31.27 0.13 44.5 Sin le shot 2959.00 0.39 180.13 .2958.43 -32.13 31.35 0.66 44.9 G ro 3445.00 0.39 178.79 3444.42 -35.44 31.38 0.00 47.3 G ro 4000.00 0.94 245..69 3999.39 -39.20 27.27 0.16 47.8 G ro 4434.00. 1.49 271.81 4433.29 -40.49 18.38 0.18 44.5 G ro 4508.00 1.60 270.10 4507.27 -40.45 16.39 0.16 43.6 Sin le shot 4558.00 1.70 271.60- 4557.24 -40.43 14.95 0.22 43.1 Sin le shot 4608.00 1.70 275.30 4607.22 -40.34 13.47 0.22 42.5 Sin le shot 4658.00 1.80 276.20 4657.20 -40.19 11.95 0.21 41.9 Sin le shot 4708.00 1.80 279.70 4707.17 -39.97 10.40 0.22- 41.3 Sin le shot 4758.00 1.90 281.60 4757.15 -39.67 8.81 0.23 40.6 Sin le shot 4808.00 1.90 281.60 4807.12 -39.34 7.19 0.00 40.0 Sin le shot 4858.00 2.00 283.30 4857.09 -38.97 5.53 0.23 39.4 Sin le shot 4908.00 2.10 285.70 4907.06 -38.52 3.79 0.26 38.7 Sin le shot 4958.00 2.20 287.30 4957.02 -37.99 2.00 0.23 38.0 Sin le shot 5008.00 2.40 290.80 5006.98 -37.33 0.10 0.49. 37.3 Sin le shot 5058.00 2.70 293.80 5056.93 -36.49 -1.95 0.66 36.5 Sin le shot 5108.00 3.00 297.20 5106.87 -35.41 -4.20 0.69- 35.7 Sin le shot 5158.00 3.20 299.80 5156.80 -34.12 -6.57 0.49. 34.7 Sin le shot 5208.00 3.50 301.90 5206.71 -32.62 -9.08 0.65 33.9 Sin le shot 5258.00 3.80 303.20 5256.61 -30.91 -11.76 0.62 33.1 Sin le shot 5308.00 4.10 304.60 5306.49 -28.99 -14.62 0.63 32.5 Sin le shot 5358.00 4.30 305.20 5356.36 -26.89 -17.62 0.41 32.1. Sin le shot 5408.00 4.60 305.70 5406.21 -24.64 -20.78 0.60 32.2 Sin le shot 5458.00 4.90 306.70 5456.04 -22.19 -24.12 0.62 32.8 Sin le shot 5508.00 4.90 306.60 5505.85 -19.64 -27.55 0.02 33.8 Sin le shot 5558.00 4.90 306.50 5555.67 -17.10 -30.98 0.02 35.4 Sin le shot 5608.00 5.00 306.50 5605.49 -14.54 -34.45 0.20 37.4 Sin le shot 5658.00 5.00 306.00 5655.29 -11.96 -37.96 0.09 39.8. Sin le shot 5708.00 5.00 305.50 5705.10 -9.41 -41.50 0.09 42.6 Sin le shot 5758.00 5.00 305.60 5754.91 -6.88 -45.04 0.02 .45.6 Sin le shot Page 2 of 3 Pioneer Natural Resources Cronus #1 Deviation Survey • • 5808.00 5.00 306.10 5804.72 -4.33 -48.57 0.09 48.8 Sin le shot 5858.00 5.10 306.40 5854.53 -1.72 -52.12 0.21 52.2 Sin le shot 5908.00 5.30 307.20 5904.32 0.99 -55.75 0.43 55.8 Sin le shot 5958.00 5.50 307.90 5954.10 3.86 -59.48 0.42 59.6 Sin le shot 6008.00 5.70 308.60 6003.86 6.88 -63.31 0.42 63.7 Sin le shot 6058.00 5.90 309.50 6053.61 10.06 -67.24 0.44 68.0 Sin le shot 6108.00 6.10 310.50. 6103.33 13.42 -71.24 0.45 72.5 Sin le shot 6158.00 6.20 311.50 6153.05 16.94 -75.28 0.29 77.2 Sin le shot 6208.00 6.20 312.60 6202.75 20.55 -79.29 0.24 81.9 Sin le shot 6258.00 6.40 .313.20 6252.45 24.29 -83.31 0.42 -86.8 Sin le shot .6308.00 6.50 313.80 6302.14 28.16 -87.39 0.24 91.8 Sin to shot 6358.00 6.50 314.50 6351.81 32.10 -91.45 0.16 96.9 Sin le shot 6408.00 6.70 315.80 6401.48 36.17 -95.50 0.50 .102.1 Sin le shot 6458.00 6.80 317.10 6451.14 40.43 -99.55 0.37 107.4 Sin le shot 6508.00 7.00 318.20 6500.77 44.87 -103.59 0.48 112.9 Sin le shot 6558.00 7.10 320.20 6550.40. 49.52 -107.60 0.53 118.4 Sin le shot 6608.00 7.20 321.70 6600.01 54.35 -111.52 0.42 124.1 Sin le shot 6658.00 7.30 322.90 6649.61 59.34 -115.38 0.36 129.7 Sin le shot 6708.00 7.00 323.40 6699.22 64.32 -119.11 0.61 135.4 Sin le shot 6758.00 6.80 324.30 6748.86 69.17 -122.66 0.45 140.8 Sin le shot 6808.00 7.00 325.70 6798.49 74.09 -126.10 0.52 146.3. Sin le shot 6858.00 7.00 327.00 6848.12 79.17 -129.48. 0.32 151.8 Sin le shot 6908.00 7.20 328.60 6897.74 84.40 -132.77 0.56 .157.3. Sin le shot 6958.00. 7.30 329.30 6947.34 89.80 -136.02 0.27 163.0 Sin le shot 7008.00 7.40 331.10 6996.93 95.35 -139.20 0.50 168.7 Sin le shot 7058.00 7.70 332.20 7046.49 101.13 -142.32 0.67 174.6 Sin le shot 7108.00 7.70 333.10 7096.04 107.08 -145,40 0.24 180.6 Sin le shot 7158.00 7.80 334.20 7145.59 113.13 -148,39 0.36 186.6 Sin le shot 7208.00 8.00 335.30 7195.11 119.34 -151.32 0.50 192.7 Sin le shot 7258.00 8.10 336.50 7244.62 125.73 -154.18 0.39 198.9 Sin le shot 7308.00 8.10 337.60 7294.12 132.22 -156.92 0.31 205.2 Sin le shot 7358.00 8.20 338.40 7343.62 138.79 -159.58 0.30 211.5 Sin le shot 7400.00 8.40 341.10 7385.18 144.48 -161.68 1.04 216.8 Sin le shot 7450.00 8.60 342.20 7434.63 151.49 -164.00 0.52 223.3 Sin le shot 7500.00 8.80 343.20 7484.05 158.71 -166.25 0.50 229.8 Sin le shot 7550.00 8.80 343.90 7533.46 166.05 -168.42 0.21 236.5. Sin le shot 7600.00 8.60 345.40 7582.89 173.34 -170.42 0.60 243.1 Sin to shot 7650.00 8.50 346.50 7632.33 180.55 -172.22 0.38 249.5 Sin le shot 7700.00 8.60 347.50 7681,78 187.80 -173.90 0.36 255.9 Sin le shot 7750.00 8.60 349.10 7731,21 195.12 -175.41 0.48 262.4 Sin le shot 7800.00 8.40 350.50 7780,66 202.39 -176.72 0.58 -268.7 Sin le shot 7850.00 8.30 352.00 7830.13 209.57 -177.83 0.48 274.8 Sin le shot 7900.00 8.20 350.30 7879.62 216.65 -178.93 0.53 281.0 Sin le shot 7941.00 8.20 350.30 7920.20 222.42 -179.92 0.00 286.1 Sin le shot Pioneer Natural Resources Cronus #1 Page 3 of 3 Deviation Survey • Letter of Transmittal ~s RED ~~ a' 2 5 2006 ~ - .:~ ,y~tca011 &GasC~'CA~ Date: A ril 25, 2006 FROM TO Tavia Bicklein Pioneer Natural Resources 700 G Street, Suite 600 Anchora e, AK 99501 Steve Davies AOGCC 333 W. 7~' Avenue, Suite 100 Anchora e, AK 99501 INFORMATION TRANSMITTED ^ Letter ^ Ma s ^ Report ^ A reement x Other: Wireline Logs DETAIL QTY DESCRIPTION Cronus #1 1 -Print - DSL Wireline Logs 1 Print - HDIL/ZDL/CN/GR/CAL 1 Print -XMAC/GR 1 Print-MREX 1 Print -.Directional Survey 1 Print - RCOR 1 Print -Processed Aniso 1 Print -Processed XMAC 2 Data CDs - Di its and ra hics Runs 1 & 2 and rocessed to s Received by: Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Kim 700 G Street Suite 600, Anchorage AK 99508 907-343-2190 fax ~ ~ Letter of Transmittal REC. IVED 2 5 zoos Oil & Gas cons. commission anchorage ~~ ~-~~~ z.~ ~,~ .. _ ~; Date: A ril 25, 2006 FROM TO Tavia Bicklein Pioneer Natural Resources 700 G .Street, Suite 600 Anchora e, AK 99501 Steve Davies AOGCC 333 W. 7~' Avenue, Suite 100 Anchora e, AK 99501- INFORMATION TRANSMITTED ^Letter ^Mas ^ Report ^ A reement x Other: Wireline Logs, Mudlogs, Summary Sheet DETAIL .QTY DESCRIPTION Cronus #1 1 Print -Acoustic Waveform Log Processed Sonic Data 3 Prints -Combination Mudlogs 1 ", 2"and 5" prints 1 Print -Gas Ratio. Show Log 5" print 1 Copy -Endo of Well Report 1 Print -Engineering Log 1 Print- Port Pressure Log 1 Data CD Digital data and graphics 1 Co -Summa Geol ical and Evaluation Summa Received by: Date: Please sign and return one copy to Pioneer Natural .Resources, Inc., ATTN: Shannon Kim 700 G Street Suite 600, Anchorage AK 99508 907-343-2190 fax • • PIONEER NATRUAL RESOURCES ALASKA, INC. Cronus #1 Summary co~~,r,~ Geologic Marker MD TVD TVDSS Base Permafrost 1144 1144 -966 Top West Sak 730 730 -552 Collville 2144 2144 -1966 Top H RZ 7464 7448 -7270 Base HRZ 7597 7580 -7402 Kup C 7753 7734 -7556 LCU 7761 7742 -7564 Kup A 7761 7742 -7564 Milluveach 7852 7832 -7654 -- .. R CEIVEC~ ~'' ~ 2 ~ 2006 Kaska Oil Or; iviuaivgging summa Cronus #1 1" 2" and 5" Mudlogs 98'MD/TVD to 7942'MD/7921'TVDI Samples collected Surface to 7942'MD/7921'TVD ....r... ~vvu summary Cronus #1 No LWD ~, vv~i~iir~~ ~urnm Cronus #1 DIR DSL (spectral GR) XMAC (dipole sonic) HDIL (resistivity) ZDL/CN (density/neutron) MREX (magnetic resonance) RCOR (rotary sidewall coring) Surface to 7942'MD/7921'TVD Surface to 7942'MD/7921'TVD 2500'MD/TVD to 7942'MD/7921'TVD 98'MD/TVD to 7942'MD/7921'TVD 98'MD/TVD to 7942'MD/7921'TVD 6200'MD/6195'TVD to 7942'MD/7921'TVD 6268' MD/6262'TVD to 7850'MD/7830'TVD ~a~ orY 4 ~o~ - any • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ~ ~~ ~~, +L TO: Jim Regg, yes;{~ P. L Supervisor FROM: Jeff Jones P. I. Supervisor DATE: March 28, 2006 SUBJECT: Surface Abandonment Cronus #1 Pioneer Resources PTD 206-014 March 27, 2006: I traveled to Pioneer Resources Cronus #1 well location near CPAI's 2P pad to inspect the casing cut off and surface abandonment of this well. Jack Newell was the Pioneer Resources representative at the site today. The well casing had been cut off approximately 3+ feet below original grade prior to my arrival and I determined that there was hard cement at surface in the 16"x 9 5/8" outer annuli and drilling mud at surface in the inner 9 5/8" casing. Mr. Newell indicated that he would have more cement delivered to the location and remove the drilling mud down to the top of cement (TOC). March 28, 2006: I returned to the Cronus #1 location and determined that TOC was approximately 8 ft. below the top of the cut off 9 5/8" casing. This void was filled to the top with Arctic Set ready mix concrete and a 3/8" thick steel marker plate was then seal welded to the outermost conductor pipe with the required information bead welded to it. Summary: I inspected the surface cement plugs, casing cut off depth, and the P&A marker plate on Pioneer's Cronus #1 well. 1 found all operations to be in compliance with AOGCC regulations 20 AAC 25.112 and 20 AAC 25.120. Attachments: PA Cronus #1 cutoff, marker plate photos (3) X Unclassified Classified Unclassified with Document Removed i • Cronus #1 (Pioneer) Surface Abandonment Inspection Photos from Jeff Jones March 27-28, 2006 Casing Cut-off Marker Plate ,,~, Marker Plate Installed • • MEMORANDUM State of Alaska TO: Jim Regg ~~, ` ~~/~ P. I. Supervisor ~1 Alaska Oil and Gas Conservation Commission DATE: March 22, 2006 FROM: John Crisp, Petroleum Inspector SUBJECT: Cement Plug Tag Cronus #1 Exploratory Pioneer Natural Res. PTD 206-014 March 22, 2005: I traveled to Pioneer Natural Resources exploratory well Cronus #1 to witness the Open hole cased hole segregation plug tag for permanent abandonment. Hard cement was witnessed tagged @ 2381' MD w/ 10K indicator weight while circulating 3 BPM. Plug was verified by tagging 2 times w/ 10K. Surface casing shoe was set @ 2501' MD/TVD. Hard cement @ 2381' complied with 20AAC 25.112 (b) (1 ). Summary: I witnessed an open hole cased hole segregation permanent abandonment cement plug on Cronus #1tagged @ 2381' MD. Attachments: None Confidential Cement Plug Tag Cronus .doc • ;, ~ ", 9 ~ ~ ~ ~ ' ~ ~ ~. ~ ~`~ ~ 'a, i ~~ ~ FRANK H. MURKOWSKI, GOVERNOR 9 a ~ ~ ~ ~ ~ _~, Lu/A-7~ OII/ A~D ~ ~~ 333 W. 7TM AVENUE, SUITE 100 COI~TSERQA7'IO1~T CO1~IIrIISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Vance Hazzard FAx (so7> 27s-7542 Drilling Superintendent Pioneer Natural Resources Alaska, Inc. 700 G ST., Suite 600 Anchorage, AK 99501 Re: Cronus # 1 Sundry Number: 306-097 Dear Mr. Hazzard: 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, 2006 Encl. R~CIEIVED 3 ~~ ~,o~ STATE OF ALASKA ~~j' .~ ALA IL AND GAS CONSERVATION COMM~N ~~ \ MAR 2 1 2006 APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. Cotrrlrrrlission 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend Operational shutdown Perforate Waiver ther 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: Pioneer Natural Resources Alaska, Inc. Development ^ Exploratory Q 206-014 3. Address: Stratigraphic ^ Service ^ 6. API Number: 700 G St., Suite 600 Anchorage, AK 99501 50-103-20523 7. KB Elevation (ft): 9. Well Name and Number: 177.4' Cronus #1 8. Property Designation: 10. Field/Pools(s): ADL 389161 ' Cronus Unit 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,941' 7,921' 7,941' 7,921' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 98' 98' 1640 psi 670 psi Surface 2484' 9.625" 2501' ~ 2501' 5750 psi 3090 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade:. Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory 0 Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/21/2006 Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Vance Hazzard Title Drilling Superintendent Signature Phone 907-343-2116 Date 3/21/06 COMMISSION USE ONLY di i C f o /~ ~ V~ ~C N on t ons f approval: Noti y Commission so that a representative . may witness Sundry umber: Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: '~('?~~~~~;J~P ~\~°' WC:i~t1C ` ~v`CJ~:~J V~©_ ~~c~-S ~I D`C.1~~E~'~r-~-'' ~ ~ ~Q ~ Subsequent Form Required: APPROVED BY Z / ~~"" ~` ~ / •~ Approved by: OM ISSIONER THE COMMISSION Date: / ~ Form 10-403 Revised 07/2005 ~{~. MAft ~ ~+ ZOO 'L~-~ Su in Duplic to `~OR`1Gl~AL ~~~.~,-~ ~~~~~6 • CRONUS #1 PLUG AND ABANDONMENT -APPLICATION FOR SUNDRY APPROVAL DESCRIPTION SUMMARY OF PROPOSAL Total depth of well in the 8-1/2" open hole section is 7,941' MD (7,921' TVD) Rig Procedure ~ .~ 1. RIH with open-ended drill pipe to TD. Spot a 400 sx 15.8 ppg Class G cement plug (yield 1.15 ~/~ q ft3/sx) from TD to 7045' MD. TOH to 6925' and circulate hole clean. TIH to 7045' MD or top of any tagged cement and spot a 400 sx 15.8 Class G cement plug (yield 1.15 ft3/sx) from 7045' MD to 6150' MD (100' above top of uppermost hydrocarbon bearing zone at 6250').' TOH above plug and circulate hole clean. ~ ~ "~j C Sg'1S~ S~ ~~ spa ~ 2, TOH laying down drillpipe. ~S T~ ~~ i~rcCSESSC~r~ QnO~`i x""~t ~S "20'x. ~ ~w S ~? t ~~-r7 ~c~-c~c ~''f C~ ~'t-ob~~S 3. Spot a 125 sx 15.8 ppg Class G cement plug (yieldd 1.1 t3/s~through drill pipe from 2651' to ~~~ 2351' (surface shoe at 2501'). TOH above plug and circulate hole clean. TIH and tag cement to '-'~ ~~^~~--~~~ ~~ verify cement top. '~~~,~Z~-~;n.,v~„~~,. ~OO~ bg\ow 1 1~0` c~.bo~~ ~2~~4-1-n~~ \ r~,~ 15 c~' . ~ 1 ~ so' ' ` '1w13 /a I 4. TOH laying down drillpipe. Spot final surface cement plug from 155' to 5' below surface through drillpipe using 75 sx 15.6 ppg Class C Permafrost cement (yield 0.95 ft3/sx). 5. ND BOPE. NU dry hole tree on well head while cleaning pits. 6. RDMO rig. Non-rig operations ,~ 1. Cut wellhead off 5' below ground level. Weld final plate as per AOGCC regulation. 2. Recover cellar and backfill cellar with previously stored material from cellar installation. Clean location of all debris. • • Cronus #1 Wellbore Schematic.. (pre P&A) RKB-GL 17T Pre-Set Conductor Pipe 16" @ 80' B.G.L. / 98' KB 12-1 /4" Top of Perfmafrost C~3 1 Surface Casing 9-5/8", 40#, J55 BTC @ 2501' MD / 2501' TVD Cemented w/ 370 sx Permafrost L Class G mixed @ 10.5 ppg (Lead) and 220 sx Class G w/additives mixed C~ 15.8 ppg (Tail) Cement circulated to surface 8-1/2" hole 9 ppg mud and 950 psi surface pressure. EMW 16.2 pP9 8-1/2" hole TD'd C~ 7941' MD / 7921' TVDI • • Cronus #1 Wellbore Schematic (post P&A) RKB-GL 17T Pre-Set Conductor Pipe 16" C~ 80' B.G.L. / 98' KB 12-1/4" hole Top of Perfmafrost ~ 1140' Surface Casing 9-5/8", 40#, J55 BTC @ 2501' MD / 2501' TVD " j Cemented w/ 370 sx Permafrost L ~ Class G mixed C~ 10.5 ppg (Lead) ~ and 220 sx Class G w/additives ~ mixed @ 15.8 ppg (Tail) ~ Cement circulated to surface 8-1/2" hole +Y 1 I I I I 8-1/2" hole TD'd @ 7941' MD / 7921' TVD~ 15.6 ppg Class C Permafrost cmt plug from 5' below surf to 155' 9.8 ppg mud 15.8 ppg Class G cmt plug from 2351' to - 2651' LOT w/8.9 ppg mud and 950 psi j surface pressure. EMW 16.2 ~ pP9 9.8 ppg mud ~ Top of hydrocarbon bearing zones ~ 6250' ~- 15.8 ppg Class G cmt plug from 7941' MD to ~ - 6150' MD (100' above top hydrocarbon ~ bearing zone) r ''` 'zF ;. C~iUN~~CZ Weekly Activities March 27 -April 2, 2006 Weekly Operations Report Cronus #1 Permit No.# 206-014 3/27/2006 7941' CONTINUE TO RD & MOVE OFF LOCATION. DEMOB RIG & EQUIP. HAUL RIG TO CPAI LOCATION. NOTIFIED JEFF JONES (AOGCC) OF NON-RIG P&A ACTIVITIES. THAW CELLAR AREA, REMOVE CELLAR. CLEAN OUT MUDS & DEBRIS AROUND TREE. CUTOFF WELLHEAD. CONDUCTOR & INTERIOR TUBULAR CUT OFF 42" BELOW TUNDRA MAT LEVEL. SCRAPE ICE PAD, REMOVE DEBRIS & FROZEN FLUIDS FROM ICE PAD & CELLAR AREAS. 3/28/2006 7941' FINISH CLEANING OBM FROM TANKS & CELLAR AREA. AOGCC REQUIRED CEMENT TO SURFACE, USED .01 CYD ARCTICSET. AOGCC APPROVED INSTALL OF 16" SEAL WELDED CAP PLATE. REUSE CELLAR MAT'L & BACK FILL HOLE. MOUND 5' ABOVE TUNDRA LEVEL. Vance Hazzard Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. 4/3/2006 Date • • ~.F_----M.~ ,~ ~~ ~~ ~ ~ ~ Weekly Operations Report ~` ~~'~ `~~ Cronus #1 ~`"~' Permit No.# 206-014 ['iC7NEE[~ Weekly Activities March 20 -March 23, 2006 3/20/2006 7941' LD QUAD COMBO TOOLS. MU ROT CORE TOOL &RIH. ATTEMPT CORES -UNSUCCESSFUL. POH & MU 2ND CORE TOOL. RIH & GET CORES AS REQUIRED. POH & MU MREX TOOL. RIH. 3/21 /2006 7941' FINISH MREX LOGS & POH SAME. LD TOOLS & RU WIRELINE UNIT. RIH W/ 1300' 2-7/8" DP & CONT IN HOLE W/ 4" DP. RIH TO 7941' &CBU. RU CEMENTERS & PUMP BOTTOM PLUG. PUMPED 826BLS 15.9PPG CEMENT. POH 20 STD'S SLOWLY TO 6649'. 3/22/2006 7941' CBU F/ 1ST CMT PLUG. PUMPED 82BBLS 15.9PPG CEMENT. 2ND PLUG/POH 18 STD'S. CBU & LD 90 JTS 4" DP. PUMP 3RD PLUG @ SHOE COVERAGE. POH 6 STD'S 4" DP. CBU & WOC 6 HRS. FEEL PLUG @ 2381' (STATE WITNESSED). LD 4" DP F/ DERRICK & OUT OF HOLE. POH TO 155' CMT. 4TH PLUG IN PLACE WITHIN 5' OF SURFACE. 3/23/2006 7941' FLUSHED ALL MUD PUMPS & HIGH PRESSURE LINES. CLEAN FLOOR OF OBM & ND KATCH KAN. ND BOP STACK & NU TREE. LD KELLY & RATHOLE. LD MOUSE HOLE. CONT TO CLEAN OBM F/ PITS. 3/24/2006 7941' RIG RELEASED @ 1200HRS. RD, MOVE OFF LOCATION REMAINDER OF WEEK. Vance Hazzard Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. 3/27/2006 Date • • ~~~ :. # ,, ~ Weekly Operations Report ~~, _ ~y' Cronus #1 ~'~"`~~ Permit No.# 206-014 C'I~NEER ., .. ~~; Weekly Activities March 13 -March 19, 2006 3/13/2006 7113' RECOVER FISH. TOOH - LD ANY DAMAGED DRILLSTRING COMPONENTS. TEST BOP'S. TIH W/ DRILLING BHA. 3/14/2006 7528' PU HWDP TO REPLACE DAMAGED PIPE. RIH TO 6824'. REAM TO 7113'. DRILL F/ 7113' TO 7528'. STUCK PIPE WHILE MAKING CONNECTION (PIPE MOVING WHEN HUNG UP). BIT @ 7500'. 3/15/2006 7528' CONT. TO TORQUE & SLUMP DOWNWARD FIRE JARS. RU & RUN FREE POINT TOOL. PREP TO RUN BACK OFF CHARGE. 3!16/2006 7528' RIH W/ BACK OFF CHARGE SHOOT. BACK OFF @ 7422'. POH W/ DP. MU &RIH W/TRIPLE COMBO LOGGING TOOLS (REST/DENSITY/NEUTRON). LD LOGGING TOOLS. MU FISHING TOOLS 3/17/2006 7528' RIH W/SCREW ONTO FISH. BUMP DOWN FOR APPROX. 8HR - NO SUCCESS. NO JAR ACTION AFTER 2 HRS. CUT MW F/ 9.9 PPG TO 9.6 PPG. NO SUCCESS FISHING. ATTEMPT TO BACK OUT. JAR UP ONCE & POP FISH FREE. CBU & POH W/ FISH TO 4,826'. 3/18/2006 7630' POH W/ FISH. FULL RECOVERY. RIH W/DRILLING BHA. PRECAUTON REAM F/ 6913' TO 7528' DRILL AHEAD F/ 7528' TO 7630'. 3/19/2006 7941' DRILL TO FINAL TD @ 7,941'. CBU. WIPER TRIP TO 6881'. CBU. POH FOR WIRELINE LOGS. LOG WELL BORE W/ QUAD COMBO TOOLS (REST/DENSITY/NEUTRON/SONIC). Vance Hazzard Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. 3/20/2006 Date <, Weekly Operations Report ~~ 1` ~'~' ~~~•~~ Cronus #1 ~~~ Permit No.# 206-014 PIONEER Weekly Activities March 6 -March 12, 2006 3/6/2006 2515' CEMENT 9 5/8" CSG W/ 180 BBLS OF CMT TO SURFACE. LD LANDING JOINT & DIVERTER INSTALL WELL HEAD & TEST TO 5000 PSI. NU BOP'S. 3/7/2006 2515' NU BOPS. PULL TST PLUG & INSTALL WEAR BUSHING. PU 8-1/2" BIT & BHA. TIH TO 2408'. 3/8/2006 3241' CSG TST TO 2900 PSI. DRILL FE & 20' NEW HOLE. 16.2 PPG EMW LOT. DRILL F/ 2515' TO 3241'. TAKE GYRO SINGLESHOT SURVEYS AS NEEDED. 3/9/2006 4515' DRILL & SURVEY FROM 3241' TO 4515'. WIPER TRIP TO SHOE. 3/10/2006 5528' FINISH WIPER TRIP TO BTM. DRILL & SURVEY F/ 4515' TO 5528'. 3/11 /2006 6700' DRILL & SURVEY F/ 5528' TO 6673'. 3/12/2006 7500' DRILL & SURVEY F/ 6673' TO 7113'. DRILLSTRING FAILURE WHILE REAMING 20' OFF BTM. TOP OF FISH @ 144' BELOW ROTARY TABLE. MU FISHING TOOLS & RIH. MILL OVER & ENGAGE FISH @ 165' RKB. PIPE FREE. PREP TO CIRC. Vance Hazzard Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. 3/13/2006 Date • • F..~ ._ ~^ .,\ r. ''„ ~ ~~ ~r~M3j Weekly Operations Report ~ ~~ Cronus #1 ~"~~~"~ Permit No.# 206-014 t'1QNEECt Weekly Activities February 27 -March 5, 2006 2/27/2006 0' CONTINUE MOVING TO CRONUS #1 LOCATION. BEGIN RIGGING UP. 16" CONDUCTOR PRESET @ 80' BELOW GROUND LEVEL. 2/28/2006 0' CONTINUING RIGGING UP. BEGIN WELL OPERATIONS AT NOON -MIXING MUD. BEGIN NU DIVERTER AND DIVERTER LINES. 3/1 /2006 0' COMPLETE RIGUP. FUNCTION TEST DIVERTER. PRE-SPUD MEETING. BEGIN PU BHA. 3/2/2006 1358' PIU BHA & CLEAN RIG. TIH. TAG AT 96' RKB. DRILL 12-1/4" HOLE 96' TO 1358'. 3/3/2006 2348' DRL & SURVEY 1358' TO 1644'. CIRC BOTTOMS UP. WIPER TRIP TO 361'. DRL & SURVEY FROM 1644 TO 2348'. 3/4/2006 2515' DRILL TO TD OF 2515'. CIRC B/U. WIPER TRIP TO 1644'. CIRC B/U. TOOH FOR LOGS. RU LOGGERS, COULD NOT PASS 350'. POOH WL. TIH BHA. TAG AT 441'. WASH TO 474, TIH 3/5/2006 2515' TIH TO BTM. CBU. TOOH. RUN LOGS - OK. RUN 9-5/8" CASING. PREP TO CEMENT. Vance Hazzard Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. 3/6/2006 Date RE: Cronus #1 H2S monitoring • • Subject: RE: Cronus #l FI2S moni~orin I~,rom: "Nichols, Josh" ~'Josh.~ichols(apxd.com> Datc: Thu, ~)' 1~~1ar'?U06 l ;:17:Oj -O(i~")O To: Thomas Maunder <tom_nlaunder(u?admin.state.ak.us% ~0ft ~~ ~~ Thanks, Tom. You understood both of my questions correctly. I will pass this information onto the rig. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, March 02, 2006 10:15 AM To: Nichols, Josh Subject: Re: Cronus #1 H2S monitoring Josh, I am not sure I understand your question here. It appears that Pioneer/Doyon as part of normal prespud operations noted that the rig floor H2S monitor had failed. It appears that it would not be possible to effect a repair prior to spud. You notified Inspector John Crisp of the inoperative rig floor sensor. The other 2 hard wired monitors are functioning and you will be employing hand-held monitors on the floor until the installed monitor can be repaired. 1. Contacting the Inspector does fulfill the requirement of notifying the Commission. The Inspector will likely communicate with his supervisor regarding the matter, but it is not unusual for other operators to follow up with a contact from their engineer to one of the Commission's engineers as you have done here. 2. With regard to the need to report even though you had not spudded, I think notification was proper since it appears that you intended to begin drilling operations with the rig floor sensor inoperable. If it was possible to make the repair prior to spudding then notification would probably not be needed. The important things here are that you had back up detection means available and had a contingency plan to employ them. Also, since you were drilling surface hole the likelihood of encountering H2S was very small. But, it is important to note that there is no qualification in the regulation regarding what hole section might be being drilled. That is where the Commission's "discretion" comes in. Hope this answers your questions. Call or message to discuss further. Tom Maunder, PE AOGCC Nichols, Josh wrote, On 3/2/2006 9:33 AM: Tom, Last night we discovered that the H2S monitor on the rig floor was malfunctioning. Our rig supervisors, Hubert Stallings and Jack McDade, spoke with John Crisp and they received a variance for the time being to begin drilling without the H2S monitor on the floor since the other 2 were still functioning properly. We will be using hand held monitors on the floor until we get the unit repaired later today, at which time we will notify the AOGCC that is has been repaired and is operable. 1 of 2 3/2/2006 10:27 AM RE: Cronus #1 H2S monitoring My question is this -according to 20 AAC 25.066 (c) "A failure in a gas detection system must be reported to the commission within 24 hours after the failure. The commission will, in its discretion, require well operations to be discontinued if a gas detection system fails." Two questions were posed by the company men after this -1) Does our situation fall under this regulation, even though we had not started drilling operations yet? and 2) Does our call to the AOGCC Qohn Crisp) to request a variance act as notification to the AOGCC that a failure has occurred? Thanks for your input, Josh Nichols Pioneer Natural Resources v. 972.969.3947 (Las Colinas) f. 972.969.3562 (Las Colinas) v. 907.343.2184 (Anchorage) £ 907.343.2192 (Anchorage) m. 214.549.5335 josh.nichols `ci! ~xd. roan C) .'F.,: lIr fn~asl .€clcir>:s, h€s rc a :~tl ~• c.I.~: dngecl This email has been scanned by the MessageLabs Email Security System. For more information please visit http://www.messagelabs.com/email 2 of 2 3/2/2006 10:27 AM Re: Cronus #1 (206-014) exception • • Subject: Re; C'r~nus#1 (2(lfi-014) exception From: Thomas viaunder ~-Morn «ulundern.admin.state.~k.us== Date: ~~"cd, U 1 '~~1ar ?006 1 ~: 10:07 -0900 To: "Nichols, Josh" ~~Josh.~icholsiu;px~l.c,on~ Josh, Seeking approval to remove the paddle while drilling the gravel sections is not unusual. In addition to using the PVT system, I suspect that the floor personnel will be directly observing the bell nipple. Based on your stated plans for monitoring the hole and fluid returns while drilling the gravel sections, it is acceptable to remove the paddle per 20 AAC 25.035 (j). This approval is specific to the surface hole on Cronus #l. A copy of this message should be available on the rig. I will place a copy of this message in the well file. Call or message with any questions. Tom Maunder, PE AOGCC Nichols, Josh wrote, On 3/1/2006 1:39 PM: Tom, As discussed during our phone conversation, while drilling the gravel section of the 12-1 /4" surface hole on the Cronus #1, Pioneer Natural Resources would like to remove from the 12" flow line the flow line paddle that measures flow. The paddle acts as a restriction to the amounts of gravel that will pass through the flow line. During the time that the paddle is out of the flow line, flow volume will be measured using PVT equipment. After the gravel section has been drilled, PNRA will put the paddle back in. This was previously done on our last well, the Hailstorm #1. Please let me know if you require any more data, and thank you for responding so quickly. Josh Nichols Pioneer Natural Resources v. 972.969.3947 (Las Colinas) £ 972.969.3562 (Las Colinas) v. 907.343.2184 (Anchorage) £ 907.343.2192 (Anchorage) m. 214.549.5335 j c, sh. r~ichc>lsa`,• X~ xd. ct>in \C~"IL : \1~: cfnail address has recen~it clrar.~~;eti. 1 of 1 3/1/2006 2:11 PM ~~ ~ ` ~~ ,. ~ ~ ~~ ~ : ~ ~ ~ a 1~ ~j ~ ~, ~ ~? ~' FRANK H. MURKOWSKI, GOVERNOR ~ ~~~ ~~~ di/L>•7~ Oa14 t>•isal ~17y7 J3 333 W. 7TM AVENUE, SUfTE 100 COI~TSER~ATIOlY C011i11'II5SIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vance Hazzard Drilling Superintendent Pioneer Natural Resources Alaska, Inc. 700 G St., Suite 600 Anchorage, AK 99501 Re: Cronus # 1 Pioneer Natural Resources Alaska, Inc. Permit No: 206-014 Surface Location: 4079' FSL, 3022' FEL, SEC. 8, T8N, R6E, UM Bottomhole Location: 4079' FSL, 3022' FEL, SEC. 8, T8N, R6E, UM Dear Mr. Hazzard: 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. Please note the following: 1. 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. 2. The requested waiver for a porosity log in the surface hole is denied. Such information is critical to determining the presence or absence of underground sources of drinking water. 3. Annular disposal of drilling wastes cannot be approved for this well until sufficient data is submitted via Form 10-403RD to ensure that the requirements of 20 AAC 25.080 are met. Permit No: 206-014 • February 1, 2006 Page 2 of 2 4. Prior to this well being tested, those plans should be submitted to the Commission via Form 10-403. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Co actor at (907) 659- 3607 (pager). DATED this. i' day of February,- 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA"'r~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL t~~ 20 AAC 25.005 1a. Type of Work: Drill ~ Redrill ~ Re-entry ~ 1b. Current Well Class: Exploratory ~ Development Oil Multiple Zone Stratigraphic Test ~ Service ~ Development Gas ~ Single Zone 2. Operator Name: Pioneer Natural Resources Alaska, Inc. 5. Bond: Blanket ~ Single Well Bond No. 103655283 11. Well Name and Number: Cronus #1 3. Address: 700 G St., Suite 600 Anchorage, AK 99501 6. Proposed Depth: MD: 9,200' TVD: 9,200' 12. Field/Pool(s): 4a. Location of Well (Governmental Section): Surface: 4079' FSL, 3022' FEL, SEC 8, T8N, R6E, UM f 7. Property Designation: ADL 389161 ` Exploratory Top of Productive Horizon: same ~ 8. Land Use Permit: 24013 13. Approximate Spud Date: 2/7/2006 Total Depth: same 9. Acres in Property: 5583 14. Distance to Nearest Property: 6,481' 4b. Location of Well (State Base Plane Coordinates): Surface:x- 413055 ~ y- 5874246 Zone- 4-NAD27 10. KB Elevation (Height above GL): 18 feet 15. Distance to Nearest Well Within Pool: 20,086' ~ 16. Deviated wells: Kickoff depth: feet Maximum Hole Angle: degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 5119 psi Surface: 4107 psi 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 65# H-40 Weld 80' GL GL 98' 98' 7.1 yards concrete 12-1/4" 9-5/8" 40# L-80 BTC 2,482' Surface Surface 2,500' 2,500' ~ 472 sx Prmfrst L + 206 sx Prem 8-1/2" 7" 26# L-80 BTC-Mod 9,182' Surface Surface 9,200' 9,200' • 427 sx Premium + additives 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachment: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat Q Diverter Sketch Q Seabed Report ~ Drilling Fluid Program Q 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 Vance Hazzard 343-2116 Printed Name Vance Hazzard Title Drilling Superintendent Signature ~~ Phone 907-343-2116 Date 1/24!2006 Commission Use Only Permit to Drill Number: ~ "°° ~ / ~ API Number: 50- /C}~°,~~~~~~ ~ 'G~ Permit Approval //--~~~I1 Date: ~~~vlX See cover letter for other requirements. ~~ Conditions of approval: ,au ;v t~. ~~rC exCCC~'F-c+bl~; at~~~La- g.C) ~ ~ ~~ (, , 5~t1~'3 PSG ~C7 Samples r wr Yes "~~~//' No Mud to re uired Yes [.~ No ~.5~ csc, drog sul measures Yes [~ No ~ Di ectional survey required Yes ~ No ~ Other: ~ i~2..`r~cd i ,3~'~'4 APPROVED BY ~ ^D Approved b THE COMMISSION Date: ~' Form'r0-401 Rev 6/2004 ~ Submit inDuplicate ORIGINAL REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION NOTES: ;. ~° ° ~ 1. COORDINATES SHOWN ARE ALASKA STATE PLANE ~ a Np ZONE 4, NAD 27. J rl^ 4 2 ~ a g ~ -^~ ~ , ~ ,,Q ,~' 2. GEOGRAPHIC COORDINATES ARE NAD 27 r " 3. ELEVATIONS SHOWN ARE GPS ORTHOMETRIC. ~% ' '~~~' ~° ~~ , ~ ,z 4. ELEVATIONS ARE DERIVED FROM SURVEY QUAUTY S" ~ ~ ' ~ GPS UNITS & ARE DEPENDENT ON GRAVIMETRIC GEOID e op sed I e , MODELING. ACCURACY AT THIS LOCATION IS BELIEVED ~ ~~ ~ ,5, ~ ;~~,< q~ '',8D - , TO BE IN THE 3' RANGE. ag >, ° ~ ''°- , o 5. ALL DISTANCES ARE TRUE. ' " y ~ ' ~ ~ 6. ICE PAD IS ROTATED 15' 08 WEST FROM NORTH. 39 ~ ?. ~° ~~ e ~` ~ ~ - ~° . VICINITY MAP NOT TO SCALE CRONUS-1 LOCATED WITHIN PROTRACTED SEC. 8, T8N, R6E, UMIAT MERIDIAN. 1201' F.N.L. 2258' F.W.L. 6 5 , LAT = 70' 03' 58.646" 7 8 LONG = 150' 41' 46.492" 400' Y = 5874246.3 RP-2~ X = 413055.2 GROUND ELEVATION = 156.1 200' o NE COR RP-1 N • ~ 0 N W COR ~N ~ s s 2258' °o 141 .a3 CRONUS-1 s SE COR S \M~~ 3 ° ' E P PD ~ 1 = 200 \c 5~~ LOUNSBURY & ASSOCUTE3, INC. SW COR ,~ ~ ~~~ Pioneer Natural Resources AREA: MODULE: UNIT: CRONUS-1 Alaska ~nC EXPLORATORY WELL CONDUCTOR . , AS-STAKED LOCATION CALK601D633 12 26 05 DRAWING N0: NSK 6.01-d633 PART: 1 OF 1 REV: 0 ~ • PIONEER CRONUS #1 SUMMARY DRILLING OPERATIONS Pre-Riq Work 1. When weather conditions allow, begin construction of snow road and ice pad. 2. Set 16" conductor and install landing ring for a multibowl wellhead on the conductor. 3. Install 6' x 6' cellar and drill rat and mouse hole. 4. Construct temporary cuttings storage area on ice pad. Ensure it is bermed with ice on three sides and built as per ADEC Drilling Waste Temporary Storage Plan. 5. Install plastic liner under rig substructure on ice pad prior to installing rig mats. Riq Activity 1. MIRU Doyon Akita Arctic Fox Rig #1 onto ice pad. Move over pre-installed 16" conductor casing. Post Alaska Oil and Gas Conservation Commission (AOGCC) approved Permit to Drill on the rig floor. 2. Nipple up and function test 21-1/4" diverter system. Ensure that diverter has been function- tested prior to spud and is witnessed by an AOGCC representative. 3. MU 12-1/4" drilling assembly with straight motor. Drill surface hole to the casing point at +/- 2500' TVD (100` into the Lower Cretaceous hot shales). Obtain inclination surveys via Teledrift recording surveys every 500' as required by the AOGCC. Short trip to heavy weight drill pipe. Circulate and condition hole to run logs and run casing. TOOH. 3. RU Baker Atlas wireline unit. Run GR-Resistivity-Orientation-Caliper logs from TD to surface. 4. If hole problems exist, TIH w/BHA & DP to TD and circulate and condition hole for casing. TOOH. Clear rig floor. 5. Ensure stab-in swage made up to full opening TIW valve is on rig floor before running casing. Run 9-5/8", 40# surface casing as follows: Float shoe, two joints 9-5/8" casing, float collar and 9-5/8" casing to surface. Place 1 bowspring centralizer per joint for the bottom 15 joints .and 2 per joint inside the conductor casing. Land casing and circulate 1.25 times bottoms up. Cement the casing to surface i single stage. Drop latch down plug. 6. ND diverter /riser system and NU casing / multi-bowl wellhead. NU BOPE and test to 250/5000 psi. Change pump liners from 6" to 5". 7. MU 8-1/2" drilling assembly. RIH to float collar. Test the 9-5/8" casing to 2900 psi for 30 min using spud mud. 8. Displace mud system with mineral oil based mud system while drilling out remaining cement. Drill 20' of new formation below 9-5/8" shoe. Circulate hole until mud weights are balanced and perform LOT.. Estimated results of 15.0 ppg. 9. Drill 8-1/2" production hole to casing point (approximately 9,200' MD/TVD) 300' into the top of the Kingak formation.~Make wiper trips as necessary. Minimum mud weight of 10.0 ppg at ' the top of the HRZ section and increase mud weight as needed to control Miluveach/Kingak shales. Obtain inclination surveys via Teledrift recording surveys every 500' as required by ° the AOGCC. Expected mud weight is in the 11.2 ppg range.~Onsite geologist will advise if TD can be shortened due to mud log shows. Note: after running logs, ensure that enough rathole has been drilled into the Kingak to accommodate 85' shoe track and perforation guns and attempt to keep rathole within 15-20' for running casing. Circulate and condition hole to run logs. TOOH. 10. RU Baker Atlas wireline unit. Run GR-Resistivity-Orientation-Caliper-Density Neutron-Dipole Sonic logs from TD to 9-5/8" casing shoe. Dipole sonic will be logged up as high as possible. Pioneer Natural Resources Alaska, Inc. Last Revised: January 24, 2006 Cronus #1 Permit Application • • If warranted, rotary sidewall cores (wireline conveyed), a wireline conveyed MREX (magnetic resonance tool) and a wireline or drillpipe conveyed RCI (formation pressure sampling tool) will be run in zones of interest. A VSP/Checkshot may also be run, but there will be some lead time for this decision. P&A operations of the open hole section will follow this step if warranted. ~-.-.~ ~'P P~` ~~-:bv~ ~yc,. ~1~~ `/di~~V~l ~ I~ ~ i 1. TIH w/BHA & DP to TD and circulate and condition hole for casing. Circulate until satisfied with the condition of the mud coming over the shakers. TOOH. Clear rig floor. 12. Change BOP rams to 7" and test bonnets to 2500 psi. Ensure stab-in swage made up to full opening TIW valve is on rig floor before running casing.. Run 7", 26# intermediate casing as follows: Float shoe, two joints 7" casing, float collar and 7" casing to surface. Place 1 rigid centralizer per joint throughout the planned cemented interval. Cement the casing to 500' above the top of the Albian section in a single stage. Drop 1st plug between spacer and lead cement. Displace plug with clean sea water. Note: Verify uppermost hydrocarbon zones needing cement coverage and adjust cement volumes accordingly. Top of cement must be 500 feet above all significant hydrocarbon zones - AOGCC reg. 20 AAC 25.030 (d)(5). Set & test the 7" pack off. Note: Submit final paperwork to AOGCC requesting permission for annular injection of cuttings. ~`--~t ~'-`'-~1.~'~ ~ `~I ~~-~"~ `l ~ l 13. Freeze protect 7" x 9-5/8" annulus with diesel to 2000'. 14. TIH w/4" DP to PBTD (+/-9180'). 15. Circulate and condition sea water while adding KCL and bactericide to 8.6 ppg brine. (reservoir. inhibition). 16. TOOH & LDDP. Clear rig floor. 17. RU completion running equipment. 18. Run the 2-7/8" 6.5# L80 EUE completion assembly. 19. Pump corrosion inhibitor and heated diesel down the 2-7/8" x 7" annulus equivalent to the annulus capacity plus tubing capacity for 2000' of freeze protection volume. 20. RU at surface to allow the freeze protection fluid to u-tube through the bottom gas lift mandrel. 21. Bleed off annulus to 0 psi. Ensure both the tubing and annulus pressures are O psi. 22. Install BPV. Ensure all valves are closed. RD and move off well. Post-Rig Work 1. Rig up well testing spread. 2. Perforate well. 3. Test well as per Cronus #1 Well Test Procedure. Estimated Spud Date: February 7, 2006 Josh Nichols Pioneer Drilling Engineer 907.343.2184 (o) 214.549-5335 (m) ~o ~JF c~v`~a`~..c~' v t c,. ~~~ ~~`l-;, Pioneer Natural Resources Alaska,lnc. Last Revised: January 24, 2006 Cronus #1 Permit Application • • CRONUS #1 WELL PLAN SUMMARY Type. of Well: Exploratory Surface Location: 4079' FSL, 3022' FEL, Sec 8, T8N, R6E, UM ' ASP 4 (NAD27) projection X = 413,055 ' Y = 5;874,246 ' Target: (top of Albian turbidite section) 4079' FSL, 3022' FEL, Sec 8, T8N, R6E, UM X = 413,055 Y = 5,874,246 6,885' TVDRKB Bottom Hole Location: 4079' FSL, 3022' FEL, Sec 8, T8N, R6E, UM X = 413,055 Y = 5,874,246 9,200' TVDRKB Rig: Doyon-Akita Arctic Fox Rig #1 Est. Start Date: February 7, 2006 Operating days to complete: 15 days to drill 5 days to complete TD: 9,200' MD/TVD 9,200' MD/TVD Well Design (slimhole, etc): Ultra slim hole -vertical Objective: Exploratory Albian turbidite/Kuparuk C/Jurassic Alpine Test MECHANICAL CONDITION Cellar box: Elevation above MSL: 156.1' y RKB to Cellar box: 18' (estimated) ` Rig Elevation: RKB +MSL = 175' ~ Conductor: 80' of 16" w/RH & MH drilled into place MUD PROGRAM Surface Hole Mud Properties Spud mud 12-1/4" hole From surface to 2500' MD/TVD ' Interval Density (ppg) Viscosity (seconds) YP PV 10 sec gel API FL Initial 8.5 300+ 45-55 10-30 10-15 Unrestricted Final 9.2-9.5 ~ 70-150 25-35 12-25 10-15 <12 Production Hole Mud Properties Mineral oil based mud (Enviromul System) 8-1/2"hole Interval Density Viscosity YP PV ES HTHP FL WPS O/W To top HRZ 8.6-9.3 ~ 55-80 12-20 14-25 400- 800 <6 250 to 300K 60/40 HRZ to TD 10.0-11.2 55-80 12-20 16-30 400- 800 <5 250 to 300K 60/40 .Pioneer Natural Resources Alaska, Inc. Last Revised: January 24, 2006 Cronus #1 Permit Application J • • v LOGGING PROGRAM 12-1/4" Section: Drillin Mud to in - Teledrift O en Hole: Gr-Resistivit -Orientation-Cali er - Cased Hole: None 8-1/2" Section: Drillin .Mud to in Teledrift Open Hole: GR-Resistivity-Orientation-Caliper-Density Neutron-Dipole Sonic logs Rotar SWC's, RCI, and MREX ossible in zones of interest Cased Hole: None INTEGRITY TESTING Test Point Depth Test Type EMW 9-5/8" Surface Shoe 20' min from 9-5/8" shoe LOT 15.0 ppg target FORMATION MARKERS Formation To s MD TVD (SS) West Sak 712 -537 Base Permafrost 1410 -1235 Colville Shales 2076 -1901 L. Cret. Hot Shales 2500 -2325 Surface Casin Point 2500 -2325 Cenomanian Silts 4351 -4176 Torok Shales 4904 -4729 Albian Section 6659 -6484 Turbidite sands 6885 -6710 HRZ To 7368 -7193 HRZ Base 7553 -7378 Ku aruk 7700 -7525 LCU 7769 -7594 Miluveach Shale 7769 -7594 UJU/AI ine A 8579 -8404 J4 Siltstone 8723 -8548 Kin ak To 8900 -8725 Pro osed TD 9200 -9026 Pioneer Natural Resources Alaska, lnc. Cronus #1 Permit Application Last Revised: January 24, 2006 • • CASING PROGRAM Hole Size Casing / Tubing Weight Grade -Conn. Casing Length Casing Top. MD/TVD Hole Btm MDlTVD 24" 16" 65# H40 Welded 80' Surface 98'!98' 12'/a" 9-5/8" 40# L60 BTC 2482' Surface 2500'/2500' 8'/z" 7" 26# L80 BTCM 9182' Surface 9200'/9200' Tubin 2-7/8" 6.4# L80 EUE 9000' Surface 9000'/9000' RE(~UIRED MATERIALS L-80 Surface: L-80 Intermediate: L-80 Completion; 2482' 9-5/8", 40# L-80 BTC 1 - 9-5/8" HES Super Seal II Float Shoe 1 - 9-5/8" HES Super Seal II Float Collar 1 - 9-5/8" Cement plug set 18 - 9-5/8" x 12-'/a" Bowspring Centralizers 1 - 14-5/8" x 9-5/8" ABB-VGI Fluted hanger -BTC down, 11 %" external ACME landing thread 1 - 11" ABB-VGI Casing Head/Tbg head 9182' 7" 26# L-80 BTC-MOD 1 - 7" HES Super Seal II Float Shoe 1 - 7" HES Super. Seal II Float Collar 1 - 7" Cement Plug Set 77 - 7" x 8-1/4" Rigid Centralizers 9000' 2-7/8", 6.4# L-80 TC11 1 2-7/8" ABB-VGI tubing hanger 1 11" x 2-9/16" ABB-VGI adapter flange 1 2-9/16" ABB-VGI 2-9/16" 5K Swab Valve w/tree Pioneer Natural Resources Alaska, Ina Last Revised: January 24, 2006 Cronus #1 Permit Application • CEMENT CALCULATION: • The followina cement calculations are based unoh a sinale stage cement iob Casin 12-1/4" hole - 9-5/8" Surface Casin Basis: Stage 1: Lead: Based on 1312' of 12-1/4" open hole in permafrost plus 300% excess and 590' of 12-1/4"open hole below permafrost plus 30% excess Lead TOC: surface Tail: Based on 500' of 12-1/4" open hole plus 30% excess plus 85' shoe joint Tail TOC: At -2000' MD/TVD 500' above casin shoe Sta a 1: Total Cement / S acer Preflush 10 bbl water Spacer 30 bbl 10.0 NSCI S acer 348.8 bbls / 472 sx of 10.7 ppg Type "L" Permafrost Lead. Cement. 4.15 cf/sk, 20.3 gps water req., BHST 75°, .BHCT 70°, TT = 6.0 hrs 42.7 bbls / 206 sx of 15.9 ppg Premium "G" + 2% Tail CaCI. 1.16 cf/sk, 5.0 gps water req., BHST 75°, BHCT 70°, TT = 3.0 hrs Dis I. 183.1 bbls mud conventional 1 bowspring centralizer per joint for the bottom 15 Centralizer placement joints & 2 per joint (3 total) inside the conductor casin 18 total centralizers The followina cement calculations are based upon a sinale stage cement iob Casin 8-1/2" hole - 7" Production Casin Basis: Stage 1: Lead: Based on 400' of 8-1/2" open hole plus 30% excess Lead TOC: -6159' MD/TVD (500' above hi hest h drocarbon bearin zone Tail: Based on 2641' of 8-1/2" open hole plus 30% excess plus 85' shoe joint Tail TOC: At 6559' MD/TVD (100' above top h drocarbon bearin zone) Sta a 1: Total Cement / S acer Preflush 10 bbl water 20 bbl 11.0 ppg Dual Spacer + 0.2 gal/bbl 4346. S acer Stabilizer surfactant 11.7 bbls /32 sx of 12.5 ppg Premium + 2% Econolite (extender) + 0.5%CFR-3 (friction Lead reducer) + 0.35% Halad 344 (fluid loss add) + HR-5 (retarder), if required. 2.06 cf/sk, 11.8 gps water req., BHST 173°, BHCT 140°, TT = 5.0 hrs 80.8 bbls / 395 sx of 15.8 ppg Premium + 0.3% Halad-344 (fluid loss add) + 0.2%CFR-3 (friction Tail reducer) + 0.25 Ib/sk Super CBL (gas migration control) + 0.2% HR-5 (retarder) or as required. 1.16 cf/sk, 5.06 gps water req., BHST 173°, BHCT 140°, TT = 4.0 hrs Displ. 349.1 bbls mud Centralizer placement 1 rigid centralizer per joint to the top of the cemented interval (77 total centralizers Pioneer Natural Resources Alaska,lnc. Last Revised: January 24, 2006 Cronus #1 Permit Application i WELL CONTROL: Diverter (see attached schematic) • Hydril MSP 21-1/4" 2M annular BOP fitted w/nitrite element 1 12" full opening .knife gate valve, .hydraulically actuated 12" diverter line 5000 psi BOP stack (see attached schematic) Hydril GK 11" 5M annular BOP fitted w/nitrite element Hydril 11" 5M double ram BOP w/ (4) 3-1/8" 5M side outlets w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3-178" 5M side outlets w/flanged connections 2 ea. 3-1/8" 5M full opening, hydraulic controlled remote, valves 2 ea. 3-1/8" 5M full opening, manual gate valves Hydril 11" 5M single ram BOP w/studded connections Well control equipment will be capable of handling maximum potential surface pressures. Based on calculations below, BOP equipment will be tested to 5000 psi. Surface Section: • Maximum anticipated BHP: 1170 psi @ 2500' TVD • Maximum surface pressure: 895 psi C~ surface (Based on BHP and a full colum n of gas from TD C~ 0.11 psi/ft) Production Section: • Maximum anticipated BHP: 5119 psi C~ 9200' TVD' • Maximum surface pressure: 4107 psi @ surface ' (Based on BHP and a full column of gas from TD C~ 0.11 psi/ft) • Planned BOP test pressure: 5000 psi (annular to 3500 psi) • Planned completion fluid: 8.6 ppg Seawater /6.8 ppg Diesel Pioneer Natural Resources Alaska, Ina Last Revised: January 24, 2006 Cronus #1 Permit Application • • DRILLING HAZARDS/CONTINGENCIES • Cronus #1 is not expected to encounter hydrogen sulfide, however Standard Operating Procedures for H2S precautions should be followed at all times.' • Pioneer Natural Resources Alaska H2S contingency plan is on file with the AOGCC. ' DISPOSAL: Annular Injection: An annular injection permit will be filed for this well once the cementing of the production casing is completed. Cuttings Handling: Cuttings generated from drilling operations will be processed and disposed of at the Grind and Inject Facility at Prudhoe Bay Unit Drillsite 4. Fluid Handling: All Class I fluids will be processed and disposed of at the Prudhoe Bay Unit Pad 3 waste injection facility. All Class II fluids will be processed and disposed of at the Grind and Inject Facility at Prudhoe Bay Unit Drillsite 4. SURFACE HOLE SECTION: • Mudloggers will be rigged up throughout the entire section. ~ • Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on Cronus #1 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.0 ppg and treated with 2 ppb DRILTREAT (Lecithin). Additional measures include reducing flow rates to 450 to 500 gpm, control drilling through the zone at 40 to 60 feet per hour and keeping the mud temperature cool • Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. • Lost circulation has not been noted while drilling any of the offset wells and no losses were noted while running and cementing. surface casing. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. • Hole stabilization in the shallow unconsolidated intervals can be problematic if mud properties are relaxed. Hi viscosities as used elsewhere on the North Slope should be sufficient to control. any potential running gravels. PRODUCTION SECTION: • BOPE will be nippled up and tested prior to drilling the production section. • Mudloggers will be rigged up throughout the entire section. ' • Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior toany intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. • To prevent the initiation of lost circulation, the rheology of the system has been reduced while still providing ample hole cleaning. Maintaining a low ECD while circulating and eliminating high pressure Pioneer Natural Resources Alaska,lnc. Last Revised: January 24, 2006 Cronus #1 Permit Application • spikes while tripping should reduce the risk of lost returns. • Two forms of stuck pipe are possible. One is from hole pack-off as related to poor hole cleaning, i.e. a cuttings bed. Stuck pipe can occur if a cuttings bed forms, or if the wellbore exhibits severe instability. The best cure is to pro-actively prevent the occurrence of either scenario in the first place, and if they do occur, correct drilling practices must be employed. if pulling up into a tight spot, do not jar up further, but attempt to get below the problem. Backreaming a large cuttings bed. is an invitation to packing off and resulting stuck pipe, and backreaming must be done with care and only when necessary. If stuck pipe occurs across a sand and there are indications of differential sticking, there are drilling fluid solutions. If possible, reducing the fluid density by a minimum of 0.5 ppg may provide some relief. • The HRZ and Kingak can be problematic. Ensure the mud weight is 10.0 ppg prior to entering the HRZ and reduce the HTHP to less than 10cc. Should any signs of shale splintering be seen, immediately raise the mud weight a minimum of 0.4 ppg. Keep instantaneous surge/swab limited. Awareness by the rig crews as to the fragility of these shales to mechanical disturbance is of great importance. Expected final mud weight at TD is 11.2 ppg. Pioneer Natural Resources Alaska, Inc. Last Revised: January 24, 2006 Cronus #1 Permit Application Pioneer Natural Resources Alaska. Cronus#1 Pressure Info and Casing Design DESIGN C The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling of the Pioneer Natural Resources Alaska Cronus #1 well. Casing Casing Setting Depth Fracture pore pressure pore ASP Drilling size Gradient Gradient pressure 16" 98' TVD / 98' TMD (from KB) Conductor csg will be installed prior to ri up 9-5/8" 2500' TVD / 2500' TMD 15.0 ppg 9.0 1170 si 45 psi 7" 9200' TVD / 9200' TMD 16.0 10.7 5119 psi 1675 psi Expected Maximum Mud Weights: 12-1/4" Surface hole to 2500' TVD / 2500' TMD: 9.5 ppg 8-1/2" Production hole to 9200' TVD / 9200' TMD: 11.2 ppg ' Procedure for calculating Anticipated Surface Pressure (ASP): ASP 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) ASP = [(FG x 0.052) - 0.11] D Where: ASP =Anticipated Surface Pressure in psi FG =Fractured Gradient at the casing seat in lb/gal 0.052 =Conversion factor from lb/gal to psi/ft 0.11 =Gas gradient in psi/ft D =True vertical depth of casing seat in ft. RKB OR 2) ASP =FPP - (0.11 x D) Where: FPP =Formation pore pressure at the next casing point ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11] D _ [(1 l.o x o.os2) - o.l 1] x 98 = 45 psi OR ASP =FPP - (0.11 x D) = 1170 - (0.11 x 2500) = 895 psi ~J 2. Drilling below surface casing (9-5/8") ASP = [(FG x 0.052) - 0.11] D _ [(ls.o x o.os2) - o.l 1] x 2soo = 1675 psi OR ASP = FPP - (o. l 1 x D) = 5119 - (0.11 x 9200) = 4107 psi Casing Performance Properties Internal Tensile Strength Size Weight Grade Connection Yield Collapse Joint Body 16" 65 f H-40 Weld Conductor casin 9-5/8" 40 pf L-80 BTC 5750 psi 3090 si 916 M 916 M 7" 26 f L-80 BTC-Mod 7240 psi 5410 psi 604 M 604 M • • Pioneer Natural Resources Alaska Cronus # 1 Leak Off Test Procedure 1. After cementing casing and nippling up BOPE, TIH to top of cement and pressure test the casing (2900 psi on the 9-5/8" surface casing) for 30 minutes and record on chart (AOGCC required casing integrity test). Plot casing pressure test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat casing pressure test if needed. 2. Dri1120' of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system (required for a good LOT). PU into the shoe. 4. Close the blowout preventer. 5. Pump down the drill string at 1/4 to 1/2 barrel per minute. 6. Plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid. At this point the pressure will continue to rise, but at a slower rate. 7. Shut down when the leak-off point is clearly seen. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut-in pressures for a minimum of 10 minutes or until the shut-in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Anchorage office so that a report can be prepared and filed with the AOGCC. RKB-GL 175' Pre-Set Conductor Pipe 16" @ 80' B.G.L. / 98' KB 12-1/4" hole Surface Casing 9-5/8", 40#, L80 BTC @ 2500' 8-1 /2" hole Production Casing 7", 26#, L80, BTCM @ 9200' T • • Cronus #1 Proposed Wellbore Schematic • • 11 " 5000 psi BOPE Stack Doyon Akita Arctic Fox Rig #1 4" pipe ram; Blind rams 4" pipe rams • • 21-1 /4" Diverter Schematic Doyon Akita Arctic Fox Rig #1 "knife valve it shown) NOTE: 12" Diverter Line runs underneath substructure away from pipe shed (into the page on this diagram) • • Pioneer Natural Resources Alaska Cronus#1 Pressure Analysis and Prediction DISCUSSION: An analysis and prediction of over-pressured strata was performed for the Pioneer Natural Resources Alaska (PNRA) Cronus #1 well as required by AOGCC regulations. PNRA does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells Itkillik River Unit #l, Atlas #1, Cirque #3, Meltwater North #2, and Tarn #3. Attached are the following: • Mud weight versus depth graphs for these wells. ° • Drilling hazards and risk analysis of the proposed Cronus #1 using seismic velocities. ` Itkillik River Unit No. 1 Depth vs. Mud Weight (no days vs. depth data) 0 2000 4000 6000 .~. ... ... w 8000 a m D 10000 12000 14000 16000 • • 8 8.5 9 9.5 10 10.5 11 11.5 12 12.5 Density (PPG) • • d U s ca ~ Q ~ N ~ Q = t d a ~ as c L ~ ~_ I ~ s ~ a ~ lO y~ ~I I rY N O O O O ~ ~ ~ CV r r r ~ O O O) i N Q C m rn 0 I N i ~ ~ ~ O ~ l f) O~ N y ~ ~ li ~ ! ~ ~ ~ ~ N ~ ~ J ,` O O O O O O O ~ N ~ ~ ~ COO O O O O O N 0 ~, ~ ~ 0 N O O O O O (;aa~) y;daa Cirque #3 Depth vs. Mud Weight (no days vs. depth data) 0 1000 2000 r w 3000 a m 0 4000 5000 6000 9 9.2 9.4 9.6 9.8 10 10.2 10.4 10.6 10.8 11 Density (PPG) ARCO Meltwater North #2 Drilling Time and Mud Weight Curve 0 1000 2000 :~ 3000 m .'~~.. r a m 0 4000 5000 6000 7000 I Drill 12-1 /4" and set 9-5/8" I Drill8-1/2" ' I/ Log and P&A well 0 2 4 6 8 10 12 Days 10.4 10.2 10.0 9.8 ~ Depth f Mud Weight 9.6 9.4 9.2 9.0 14 • 0 1000 2000 :r 3000 m .'~~.. r a 0 4000 5000 6000 7000 ARCO Tarn #3 Drilling Time and Mud Weight Curve i Drill8-1/2" ~ 0 2 4 6 8 10 Days 11.5 11.0 10.5 -~ Depth -~-- Mud Weight 10.0 9.5 ~ 9.0 12 • • To: Vance Hazzard, Drilling Superintendent From: Terry Jensen/Craig Knutson/Tavia Bicklein, Project Geologists Date: November 1, 2005 Subject: Drilling Hazards and Risk Analysis of the Proposed Cronus #1 Well (To be located 4,079' FSL, 3,022' FEL, Section 8, T8N, R6E, UM) The purpose of this letter is to document PNRA's drilling hazard evaluation for the proposed Cronus No. 1 Well, estimated to spud February of 2006. In our shallow hazard and pore pressure risk analysis of this well we examined 2D seismic data, seismic velocity information and available relevant offset well data. Our evaluation of this data J shows no indications of apparent drilling hazards or risks. The analyses of this data are not definitive, however. Therefore, PNRA will work on the assumption that the possibility of encountering drilling hazards exists and work to establish drilling processes to mitigate those risks. Log and drilling data from nearby wells used in our analysis includes the Itkillik River Unit #1, Atlas #1, Cirque #3, Meltwater North #2, and Tarn #3. Particular focus was on the Itkillik River Unit #1 which was drilled deep enough to penetrate the targets in the Cronus #1 and is directly tied to seismic line ANF-7X which also ties the Cronus location. 2D seismic line ANF-7X was shot and processed in 1980 by GSI (see base map, Figure 1). Data quality is good for deeper targets but is rather poor in the shallow section. Permafrost, Gas Hydrates, Shallow Gas In the Cronus area the depth to base of permafrost varies from approximately -1265 ft. SS at the Itkillik River Unit #1 to -1137 ft. SS at the Meltwater Field (Figures 3 and 4), based on interpretation of induction, sonic and GR logs in the area . The logs also indicate that the base of permafrost is transitional and not as sharply or easily defined as in other areas on the North Slope. The base of permafrost is poorly imaged on line ANF-7X (Figure 5) because of permafrost's transitional nature, low fold at those depths, and short wavelength surface statics associated with the Itkillik River channel The USGS Open File Report #2004-1454 by Timothy S. Collett supports the interpreted permafrost depth for the Cronus #1 and indicates that the well is located just west of the Tarn gas hydrate trend. It is also 8 miles WSW of the Cirque #1 which experienced well control problems, possibly due to a gas hydrate zone. Gas hydrates have similar acoustic properties to permafrost, and as a result, surface seismic is not useful for direct detection. Seismic data can possibly be used to identify gas bearing sands that intersect the base of the permafrost and have the potential to form • • hydrates. Figure 5 is line ANF-7X from 0.0 seconds to 1.0 seconds from just west of the Itkillik River Unit #1 to just east of Meltwater. The two horizons, at .264 and .302 seconds, are highest and lowest estimates of base of permafrost based on the Itkillik River Unit #1 and Meltwater North #2. At the Cronus #1 location there are weak reflectors dipping to the west that intersect the base of permafrost. This is similar to the geometry seen at Meltwater and where Cirque projects into the line. However, data quality is quite poor so no definitive conclusions about gas bearing sands can be drawn. Faults The current interpretation of the seismic survey does not show any shallow faults that will be intersected by the drilling of the Cronus #1. Again, data quality is poor in the shallow section, so faulting cannot be ruled out. Pressure Analysis of nearby well data and seismic velocities suggest that the Cronus #1 well will penetrate a normally pressured section from spud to final TD.~Mud weight and sonic log data from the Itkillik River Unit #1 indicate that the well was normally pressured. The well data were compared to seismic velocities from line ANF-7X. The velocities are consistent with a normally pressured section at the Itkillik River Unit #1. The comparison is also made to the Cronus #1 location and shows that the well should penetrate a % normally pressured section. Figure 6 shows well and seismic velocity data from the Itkillik River Unit #1 well which is four miles west of the Cronus #1 location and provides a good tie to seismic. On the left graph mud weights from the drilling of the well are plotted versus depth (measured from seismic datum = 0'). On the right graph sonic interval transit times (ITT) are plotted versus depth. The nearest three velocity analyses from line ANF-7X, converted to ITT, are plotted with the sonic log. There is a fair correlation between sonic and seismic ITT. The sonic ITT shows a normally pressured, hydrostatic gradient from the base of the permafrost to the Ivishak where an intermediate string of casing was set. The exceptions to this gradient are the organic rich shales of the Brookian, HRZ, and. Kingak which are lower velocity due to their composition. The mud weights also suggest a normally pressured section with values between 9.5 lbs/gal and 10.5 lbs/gal down to the LCU and up to 11.0 lbs/gal through the targeted TD in the Jurassic (Figure 7). Figure 8 is the ITT plot for the Cronus #llocation. Three nearby velocity analyses are plotted along with the sonic log from the Itkillik River Unit #l. This data suggests that the section at the Cronus #1 should be normally pressured, similar to that found in the Itkillik River Unit #1. Cnu uu~- ~r •~ •CRU CD7-NQ1 ~ j OLVILLE RIVER-1 ~~ ~- ~ 3•~' '~ ~~ ~ •' l ~O ¢ Ku aruk River Unit SUNRISE-1 (00) CRU CD2-3738 ff ~ / p A-2 ' o ~ ~~. NANUQ-3 NAN¢U--K-1 Nanu 'f J S KOOKPUK-1 KRU 2M-13A-4019 t KRU 2M-21 q 1 2i ~ ~ KRLKRUKRU LM-~aLK SUNRISE-3 (01) NANUQK4 (00) OC J ! -- KRLKRUKRU KRU 2M- NANUQ ~ 23 2? ~76 KRU KRLKRU i~KRU 2M-2 r-{ I Y e ~ ~ ~ .-_ '. _.. - _--- KRU 2M-28 A-27:U 2M-26-2 ' CLOVER-B 9 J11 r ~ II - KRU 2M-31~~~~ ~ =IKRU 2MQ ° GANYM E D E ¢" "- 1 1 " - I I KRU 2M-29~~KRKRU 2M i I 14]4 • ° ro ) a CALLISTO.1 ^ rn (01} +--~o-- e~~. ,~_~` _ ~ ~T .~ - CLOVER•A ° m ~ Q-' rn - ~`~`~~-P^~ -~~~~„~~~, KRW SAK 25590-15.RU 2M-09;K ~. A:` ¢ r `~ ~ ~ m ( _ ».~-~-.-.. KRU 2M?n+ r i ~ Q, ~ ~ KRU 2M-35~L 27;pu -, p ~ OB~ON I KRU: L-03 '~-' J • • yy~~ KR O {~ b KRI I ?F. + i ~ eron + + KRU 2K- F^ ... : l i3 _ ~~'- 80 p ~ I3 ~ I KRU TARN-2L-329... KRU TARN-2L-329A ~ KRU 21 10-8l1 2A ~~ I` ~ _ . 2G ~i 22 _ ~ ,..,..... ,..N-2L-305 --~~.~~JJ °--~ -- KRU 'TARN-2=315L-313 a3 - --- - - ~ KRU TARN-2.325;23 R17A 2S 26 c 8$p ? _ n n-[ L-321397 KRU TARN-2N-318'N-3153081305 - - ANDROS-1 (01 - ~ 302 ' 2 f 3L`~ ?:~ 26 n- ° ~~:.::. _ ~.C: .. TARN-3A• ^93307- ." - _ _, ati~..c~. , vr TARN-1 9RUK RIV U '""" KRU -.. ,.... ~.1.328 TARN-3 N - - ~ ,,, T c:6 ?a ~ s$ 36 31 -.4 arn KRU TARN-2N-332 o_u_g25;19 f'¢ KUPARUK RIV U TARN ARN-2N-349Aj I Atlas - TARN-4 KUPAR RIV U TARN..ow33 i i 6 ~ :{ ! ~ ~ ~ ~0 ~ 6 ~ 9 KFKRLi ~I xnn-Ln-Sella ¢ W SAK 25618.20 ' If ~ I nrsU Irann-Ln-ss~ } ATLAS-1A "S 1 4. '- - ` i2 ? 3 _ g 7 ~ 8 _ ~ 4 . i l: i3 i3 P 85~ J 13 i ~/rgUe } ? 16 i_ -, _ i`v i? i6 it. ( CIRQUE-2; 24 18 d + ~ iS 2G 2i 22 23 2A ~ CIRQUE is 2G 2i 2." I J _ CIRQUE ~ 2S 3G 29 23 ~? ~6 1 ~ 2S ~d ?G - 20 23 2 ,- --- - -- - - - - ! - - i _ 1002 q 36 3i ~:? ?;:. r N N i C~ W f\ /'' ~J~ O l~e.~ - ~ N N hl j O o O N O •I ~ ° (J O o J N _° - ~~ c° ITKILLI K RIVER UNIT-1 ° ~~ TT TT Prosp ~_~ _ nus - ~~~ "-~'9-O"4$~3'j° _ 'O'- ~ Llne ANF _ 7X T ~/ \'1 ./'/ KRII ttllFl T•7P-417. MELTWATER NORTH 2A RUBY ST / / ~, ~ / KUrAtMELTWATER NORTH-2 •¢ '!// / !' O ^„ , r„ ~~=LTV U MELT KUPA KUPARUK RIV UNIT ELT- i? i6 Itkillik River Unit #1 ' KMELTWATER NORTH-1~ELT <^ i = ~ Cronus #1 K UPARUK RIV U MELT. LT ' Meltwater '~'~ 2i - ! ran W Location Map Figure 1 • • 1 ~ 1° {?(~' 154°UO' p 3 url ` ~'~ MILNE Pi3~liN t ! f~l' FIE _ ~a- ~a' Accum a#fon ~ ~ 1-' ,,. _ ;-. .;~ 144° aa' 14g' aa' FREE GAS +7' .. # ~-~ ~ ~ Y~J _ J. 1 _ ' - 4' - ~~ . ~~ ~` ~ . _ ~ -~ _,;~ ~. sf~ .~~ - .. , ~~ „ .I~ J ~~ ~ a~, oo, , .. - , AIL F f ~ ~ HI.C}HaH Q1-Y ~~ ~ - `' ,` f r~i'. ~~=L FaELD _ r. ~ 7 - ~ '~., 61 c- . • • - - -- - - - - -= ~- - '°' GAS HYDRATE,,; ~ ~ ~~ - - ~j~ TE ,- ~ ~~ r ~.rc~--us fr ~ USGS Open File Report #2004-1454, Collett Gas Hydrates Trend Map Figure2 Base permafrost __-~_.-_ __ _. ..__ ..._..._.__.. I Y...._...._v--__ ATIO PnB PT I 1 j ~IKAR'CNUG 1 TUY•1 x RCNNC 2 - _ I TN E7p UxR.~`l ~`~ i 9 GitE- ~ ~62 ---Jf Xµ~PULI ~' - o00 , HS?'j( O O r _ _ . i _ __ __ C YILLE , ~ LxBIK 1 E ARR n~ x Y $f 1/ K• c.- 1 ~ 1 ~ .~ . ~ / L E~EL~ TCNGII F~.I .f R116~ y N ~~"Y /E'I ~ O kU Ik3 -~ -1,393 kAV PT L K 2687 16 W 81tK 2%19 17 -1,B 722 .~. - ' TBIKER . ~ ~4ti I [(~ /~+ n {3 L •1,56 811K 2$/811 R 372 4 1, 1 KU PAnUk - 1 TO7 r .~ }. ~ V r rn3N I ~ ` A ^ ~ W ~K~ ~ Q1~ 1JIAl ) .1 1i-1 E •URYf 1 B " E88T 1 -1 ~ - . ~ y -1.426 w I -1 ~ 1 7 , r ' ~ ; Jdl -12T1I- ~ P • -qI 9~~: 1-~ 8~~ I-I= ~ S _ ~7: l® : 9 PRO- f./' ~,LdJti 22 -1~BBW811K RyN 3T RN3T 06 A -1,309 1~ 7.1 ~A, l •BS I /7 ~ _ wsluLic___ A da Wf~`'~ ` w ~ C~3 x _ 1 V RERR pa wl ~ ,j ' 1. 9 NB113P 1 -121 7 1 I .1 3 .1 7 3 - ~ , ~ 00 w ewK n at e- W.r~al _ ~r ~ O ~ . ~ ...~._ w . •1 1 -1,236 Q O : NBII NOSr1/ ~ O 'LT I _. znK2e -1,1 61 - 551 ~ ~ xarl n^ a : INT ER A ~ [t n 42 Wf~ j wLTgRU `ti ~ I -1, 04 j -1, 3 ~ ~Q I •~ fiKIL IF t.. _.... :._~-__ _. lOQ !ce ~... T00 A 7 A 2 /11 J Q 65 ~ ~ TER x -1• 32 KLU}e- -1,52 Q^ eo k I {~rI ,. __ _. ___ ....__. _. Cronus #1 _ - ~ i. O ~Q ~1 woueuTtox 2~O o 0 / \y I 2 • • Base Permafrost Structure Map Figure3 W SAK 04 W SAK 20 TRN 2N-349 CIRQUE 2 ATLAS 7A ITNILLIK RIVER U 7 MELTWATER N 2 TOOLIK FED 3 q 4 4 f f -{- {- {- ~- ~ A O~ 'SR 0 1 OP 81ff 0 I O`OAfr 0 1 ORS O 1 OR_91R O 1 0~9ff 0 1 O~~f! 0 1 OA~OIIY 0~81ff O~OIf~ 0~31R OAS OR ~ AK O`_3ff 011~9If Subsea 0 1 0 I D I 0 I 0 I 0 1 0 1 0 Subse TVD 3P~ ~ IL~£Yf0~iJ I I®190 17 ~r` iD ao`~rr 1 I® o 19 ~0lff 0 ~OYf i9 ao~ I Om er~a 190 rr O~OIfT D a~01RO~avr I®190 o~ D ue~ I 1 av~OYf a~tarro~OYf ® 81rt ~ ao` a~0Y1 aLe=Srre~a OID 0 ur TVD 400 I i 1 I iD 1 f 1 90 1 1 i0 1 I 19 400 c6 SRC P 200 200 0 0 ~,,, -200 U`rs E Eu~~R -400 -400 600 s 600 - - 800 800 - - -1000 _ _ ° -1000 ire; ~ e~" - - ! ~ ~ ~~~ ` Cr_u 41~d 1 -,200 -200 ~ / Base Pe rmafrost __ 1400 1400 - - 600 -1 -1600 • • Structural Cross-section A-A', Base Permafrost Figure4 West F': u.uu~ ~ _f t ~ ~ li it ~ ~. ~~ ~ ~, "J 1 A, 1 ~ f 2D Line ANF-7X Figure 5 ITKILLIK RIVER UNIT•1 Cronus #1 Meltwater, Cirque, ¢ 7.5 mi. south 3 mi. north ANF-iB,1067.09 I ttkillik River Unit #7 Mud Weigh Data MW (Ibslgal) 8 9 10 11 12 0 1000 2DDD 3000 4000 5000 6000 r as d 7000 ~ 8000 .~ ~ 9000 10000 11000 12000 13000 14000 15000 16000 ttkillik River Unit #1 Sonic Log ITT vs Seismic ITT ITT (microsec+lt) 13 1DD0 1D0 10 N • Base Permafrost @ ~'• • S•• ~<<•. ~OI:I G4 R:...Yd~ H 1,265' : _ • ^srn ~ SPN ~SPt 3osa 3034 13014 • € .; i I .. HR Z @ 7 56 7' ,, , ' M LC U @ 7, 83 8 .,•~ • .<' • Rive Sa r 9 9 75 ' g , ' Ivishak @ 1 0,2 96 ' Lisburne @ 1 1,4 51 a Kekiktuk @ 14, 620' I F kli i I I I I I 14 752' • - - - - 1 ran n a n I_L1_ , I~ L_ L_ 0 1000 2000 3000 4000 5000 6000 70D0 8000 .~ N 9000 ~ 10000 11000 12000 13000 14000 15000 160D0 • Itkillik River Unit #1, Mud Weight and Sonic ITT vs Seismic ITT Figure s Q 1°OO o 0 0 0 0 0 0 0 0 0 0 0 ~ o 0 0 o a o 0 0 0 0 0 0 0 ~~~ ~; ~ ~ c~ c+•~ v u ~ cn e~ eo m o Itkillik River Unit it Sonic Log ITT vs Seismic ITT Cronus Location IfT (~icrosecfft) 1000 100 V ~ • Sonic Log • SPN 2968 1000 _•~ •. • SPN2944 SPN 2924 2000 • 3000 t e 4000 5000 6000 • • • 7000 M 8000 .' t Y • N 9000 9200', Proposed TD loooo 11000 12000 • ~ 13000 • Y 14000 • ~ • • ~ 15000 __.. .. .._ .. lcnnn • • Cronus Location, Sonic ITT vs Seismic ITT Figure 7 • PIONEER NATURAL RESOURCES ALASKA, INC January 30, 2006 Mr. John Norman, Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Attn: Steve Davies Change of Ownership and Designation of Operator Forms Cronus Unit Area, North Slope Alaska Gentlemen: Attached please find duplicate originals of AOGCC forms for Change of Ownership and Designation of Operator covering an interest ConocoPhillips Alaska, Inc. had in leases in and near the Cronus Unit. Also enclosed is J. Patrick Foley's Power of Attorney to execute same on behalf of Pioneer Natural Resources Alaska, Inc. Please advise if you require anything further. Thank you for your assistance. Sincerely, r Dale Hoffman ~~~EIVED attachments SAN ~ ~ 2006 At~i~a Dif & Gas Cans. Ca-nmission Ancfiaraya 700 G STREET, STE. 600 ANCHORAGE, ALASKA 99501 • MAIN: (907) 277-2700 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOTICE OF CHANGE OF OWNERSHIP 20 AAC 25.022 i .Operator Name: Pioneer Natural Resources Alaska, Inc. 2. Address: 600 G St., Suite 600 Anchorage, AK 99501 Attn: Manager -Land, Commercial and Regulatory Affairs 3. Notice is hereby given that the owner ~ ,landowner , of record for the oil and gas property described below has assigned or transferred interest in the property indicated below: Property Designation: / , / C ~ D~ , ADL 389056 ~ ADL 389161, ADL 390037, ADL 390038 ~ ADL 389665, ADL 389168, ADL 389169 - (' 1.3 Legal description of property: Field or Unit: Sections 1 - 18, T8N, R6E, UM ~ (,- Cronus S ti 27 ~ r ec ons - 34, T9N, R6E, UM p j~ Sections 1, 2, 3, 1D - 15, T8N, R5E, UM s/~ ~ O` Sections 13, 14, 23 - 26, 35, 36, T9N, RSE, UM ' ('~ RE~EIVEQ .JAN 3 1 2006 Alaska Oil & Gas Cons. Corrar>MSSion Anchorage Property plat attached ^ 4. Effective date of assignment or transfer. 5. Percentage interest assigned or transferred: 1-Jan-06 ADL 389056, 389161, 390037, 390038 ~ 70% ADL 389665, 389168, 389169 ~ 78% 6. Assignee or Transferee: Pioneer Natural Resources Alaska, Inc. Address: 700 G St., Suite 600 Anchorage, AK 99501 Attn: Manager -Lands, Commercial and Regulatory Affrairs 7. Assignor or Transferor: ConocoPhillips Alaska, Inc. Address: 700 G. St. ATO 1470 Anchorage, AK 99501. Attn: Land Manager 8. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ Date: 1 /30/2006 Printed Name: J. Patrick Foley Title: Attorney-In-Fact Form 10-417 Rev.10/2003 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM~ ION NOTICE OF CHANGE OF OWNERSHIP 20 AAC 25.022 1. Operator Name: Pioneer Natural Resources Alaska, Ina 2. Address: 600 G St., Suite 600 Anchorage, AK 99501 Attn: Manager -Land, Commercial and Regulatory Affairs 3. Notice is hereby given that the owner ~ ,landowner , of record for the oil and. gas property described below has assigned or transferred interest in the property indicated below: Property Designation: ADL 389056, ADL 389161, ADL 390037, ADL 390038 ADL 389665, ADL 389168, ADL 389169 Legal description of property: Field or Unit: Sections 1 - 18, T8N, R6E, UM Cronus Sections 27 - 34, T9N, R6E, UM Sections 1, 2, 3, 10 - 15, T8N, R5E, UM Sections 13, 14, 23 - 26, 35, 36, T9N, R5E, UM RECEIVED ,IAN 3 1 206 Alaska Oil & Gas Cons. Corrxnissi0ti Anchorage Property plat attached ^ 4. Effective date of assignment or transfer: 5. Percentage interest assigned or transferred: 1-Jan-06 ADL 389056, 389161, 390037, 390038 70% ADL 389665, 389168, 389169 78% 6. Assignee or Transferee: Pioneer Natural Resources Alaska, Ina Address: 700 G St., Suite 600 Anchorage, AK 99501 Attn: Manager -Lands, Commercial and Regulatory Affrairs 7. Assignor or Transferor: ConocoPhillips Alaska, Inc. Address: 700 G. St. ATO 1470 Anchorage, AK 99501 Attn: Land Manager 8. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: cy~~~// Date: 1 /30/2006 Printed Name: J. Patrick Foley Title: Attorney-In-Fact Form 10-417 Rev. f 0/2003 STATE OF ALASKA ALAS A OIL AND GAS CONSERVATION COM~SION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name and Address of Owner: Pioneer Natural Resources Alaska, Inc. 700 G St., Suite 600 Anchorage, AK 99501 Attn: Manager -Lands, Commerical and Regulatory Affairs 2. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: ADL 389056 Sections 1, 2, 3, 10, 11, 12, 13, 14, 15 T8N, R6E, UM ~ ~, p(o ADL 389161 Sections 4, 5, 6, 7, 8, 9, 16, 17, 18 TSN, R6E, UM ~?~~~ ~ ~ / , RECEIVEQ .}~~~ ~ ~ ~a~ri Alaska Oil & Gas Cons. Commissiolt Anchorage ~ Property Plat Attached: ^ 3. Name and Address of Designated Operator: Same as above 4. Effective Date of Designation: 1/25/2006 See attached DNR letter 5. Acceptance of operatorship for the above described property within all attendant responsibilities and obligations is hereby acknowledged: Signature .~Z~ Date 30-Jan-06 Printed Name J. Patrick Foley Title Attorney-In -Fact 6. The Owner hereby certifies thatthe foregoing is tru and correct: e l ~ / Signature i/ Date 1./30/2006 Printed N e . Patr' Title Attorney-In-Fact 7. ~.•~...0 Appro d: !! Comm sinner Date Approved. ~~~ Commissioner Date ~ r ~ i D Approved: Commissioner Date (Requires approval by two ommissioners) Form 10-411 Rev.10/2003 Submit in duplicate • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name and Address of Owner. Pioneer Natural Resources Alaska, Inc. 700 G St., Suite 600 Anchorage, AK 99501 Attn: Manager -Lands, Commerical and Regulatory Affairs 2. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: ADL 389056 Sections 1, 2, 3, 10, 11, 12, 13, 14, 15 T8N, R6E, UM ADL 389161 Sections 4, 5, 6, 7, 8, 9, 16, 17, 18 T8N, R6E, UM RECEIVEQ ,IOR! 3 1 7~1Ua Alaska Oil & Gas Cons. Corranissioa Anchorage , Property Plat Attached: ^ 3. Name and Address of Designated Operator. Same as above 4. Effective Date of Designation: 1/25/2006 See attached DNR fetter 5. Acceptance of operatorship for the above described property within all attendant responsibilities and obligations is hereby acknowledged: Signature ~%~2~./~ Date 30-Jan-06 Printed Name J. Patrick Foley Title Attorney-In -Fact 6. The Owner hereby certifies that the foregoing is true and correct: ~ Date Signature % 1/30/2006 Printed Na J a ri k Title Attorney-In-Fact 7. .r' _~~ A rove PP issioner Date Approve ommissione ate Approved: ~. `~ ~' (,/ 6 Commissioner Date (Requires approval by two ommissioners) Form 10-411 Rev.10/2003 Submit in duplicate F~K H. MURKOWSKI, GOVERNOR O ® 400 WILLOUGHBY AVENUE JUNEAU, ALASKA 99801-1796 PHONE: {907) 465-2400 FAX.' (907) 465-3886 DEPARTMENT OF NATURAL RESOURCES ^ 55o WEST 7T" AvENUE, SUITE 1400 ANCHORAGE, ALASKA 99501-3650 .DIVISION OF OIL AND GAS PHONE: (907) 269-8431 January 25, 2006 J. Parick Foley Pioneer Natural Resources Alaska, Inc. 700 G Street, STE. 600 Anchorage, Alaska 99501 FAX.• j907) 269-8918 Subject: Cronus Unit, Designation of Unit Operator Dear Mr. Foley: By -letter dated January 24, 2006, ConocoPhillips Alaska, Inc. (CPAI) submitted its resignation as the Cronus Unit Operator and by letter dated January 25, 2006, Pioneer Natural Resources Alaska, Inc. {Pioneer) as the 70% working interest owner in the Cronus Unit, designated Pioneer as the successor Cronus Unit Operator. ~ Effective January 25, 2006, I accept CPAI's resignation and approve Pioneer as the successor Cronus Unit Operator. A person affected by this decision may appeal it, in accordance with 11 AAC 02. Any appeal. must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040. (c) and (d), and may be mailed or delivered to Michael Menge, Commissioner, DNR, 550 W. 7th Avenue, Suite. 1400,..:Anchorage, Alaska 99501; faxed to 1-907-269-8918; or sent by a-mail to dnr_appeals@dnr.state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 3l st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. If you have any questions regarding this decision, contact Christopher Ruff at 907-269-8451. Sincerely, William Van Dyke Acting Director cc: Paul Wharton, ConocoPhillips Alaska, Inc. P.O. Box 100360 -Suite ATO 1482 Anchorage, Alaska 99510-0360 Bo Darrah AVCG LLC 8100 E. 22"d N, Bldg 1100 Wichita, Kansas 67226 RECEIVED JAN ~ 1 ~OQ6 Alaska Oil 8t Gas Cons. Comrrlissian Anchorage "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " POWER OF ATTORNEY for Pioneer Natural Resources Alaska, Inc. KNOW ALL MEN BY THESE PRESENTS: That Pioneer Natural Resources Alaska, Inc., a corporation duly organized and existing under the laws of the State of Delaware (the "Company"), has made, constituted and appointed and by these presents does make, constitute and appoint J. PATRICK FOLEY its true and lawful attorney-in-fact for the Company and in its name, place and stead, giving and granting unto its said attorney full power and authority toexecute -~ and deliver for and on its behalf (i) any and all types of notices, leases, operatorship forms, filings or other instruments by or between the Company and the Bureau of Land Management or Minerals Management Service of the U.S. Department of Interior (the "BLM" or "MMS," respectively) or any agency or regulatory body of the State of Alaska (the "State") only, but not otherwise, as may be necessary or appropriate to carry on the business of the Company as it pertains to the BLM or MMS or State, including acts relating to, but not to be limited to, making lease bids to the BLM or MMS or State, execution of BLM or MMS or State oil and gas leases, permits, rights-of--way, or assignments with the BLM or MMS or State, (ii) any and all instruments or filings required under the statutes or regulations for the State of Alaska or other regulatory or governmental agencies of the State of Alaska having jurisdiction, and (iii) unitization or pooling declarations permitted by and that comport with the terms and provisions of the applicable oil and gas leases for properties located in the State of Alaska. The authority of the attorney-in-fact herein granted by this Power of Attorney is for the sole and exclusive benefit of the Company and not on behalf of any other person in whole or in part. The Company agrees to be bound by representation of the attorney-in-fact as to matters related to or arising from the limited powers herein granted and waives any and all defenses which may be available to the Company to contest, negate or disaffirm the action of the attorney-in-fact under this Power of Attorney. The authority of the attorney-in-fact herein granted by this Power of Attorney shall remain in full force and effect until 11:59 p.m., December 31, 2006, at which time and date it shall terminate. This Power of Attorney is granted as of the ~ ~ day of December, 2005. ATTEST: Mark H. Kleinman, Secretary PIONEER NATURAL RESOURCES ALASKA, NC. By Timoth L. Dove Executive Vice President STATE OF TEXAS § COUNTY OF DALLAS § This instrument was acknowledged before me on December~~ , 2005, by Timothy L. Dove, Executive Vice President of Pioneer Natural Resources Alaska, Inc., a Delaware corporation, on behalf of said Company. .~®---~° • ,~~"'r'r"'~. LINDA K. WATSON ?=°:Pp• ue`~ : Notary Public, State of Texas L~"ol7` ~~:,~ My Commission Expires '.;+.•••~e+;~` Mqy o5, 2oos Not Public State of Te as ~'bi4ns~``` ' T:\GroupsU.egaIU,KNMOAs\PNRAlaska\Foley 2006.doc • • * ~® ..?rt • ;~ ~• 2006 PIONEER NATURAL RESOURCES ALASKA, INC. January 24, 2006 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite #100 Anchorage, AK 99501 Alaska f,~;i ~:~ ~- Anr:hor ~ Cs+oR RE: Application for Permit to Drill Cronus #1 (Exploratory Test) Surface Location: 4079 ft. FSL, 3022 ft. FEL, Sec 8, T8N, R6E, UM ' X=413,055, Y=5,874,246 ASP4 NAD27 ~ Main Target Location Albian turbidite: Same Secondary Target Location Kuparuk C: Same Secondary Target Location Jurassic Alpine: Same Bottom Hole Location: Same Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location. The well is designed to penetrate, evaluate and test the production potential of the main target Albian turbidite formation and the secondary targets, the Kuparuk C and Jurassic Alpine formations: As indicated in the attachments, the drilling program will entail drilling a 12'/4' surface hole to approximately 2,500 ft. MD/TVD, where surface casing will be seta An 8%2' vertical wellbore will be drilled through the main Albian turbidite target and secondary Kuparuk C and Jurassic Alpine targets into the Kavik shale at approximately 9,200 ft. MD/TVD. E-line logs will be run at the end of the 12'/" and 8%2' hole sections. If any of the targets are determined to be productive, a 7" string of production casing will be run for possible future testing. It is anticipated that there will time to conduct a well test on the Cronus #1 this season, if deemed necessary. The proposed casing program will utilize 95/8° surface casing and 7" production casing (if completed). 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) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 2) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 3) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2)• 700 G STREET, STE. 600 ANCHORAGE, ALASKA 99501 MAIN: (907) 277-2700 Alaska Oil & Gas Conservation Commission January 24, 2006 Page2of3 4) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13). 5) A summary of drilling hazards per 20 AAC 25.005 (c) (4). 6) Diagrams and descriptions of the BOP and diverter equipment to be used on Doyon Akita Arctic Fox Rig #1 as required by 20 AAC 25.035 (b) and (c). 7) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 8) 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. 9) The drilling fluid program as required by 20 AAC 25.033 is attached in this Application for Permit to Drill package. 10) Complete logging and mud logging operations are planned and descriptions are attached. `~"~~ ~"~~'°~' 11) PNRA 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 rig as standard operating procedure for all wells drilled by that rig.' PNRA's contingency plan for H2S for all wells drilled on the North Slope while using the Doyon Akita Arctic Fox Rig #1 is on file with the AOGCC. PNRA proposes the following additions to this drilling permit: 1) PNRA requests authorization for the disposal of drilling waste via the annulus and will do so by filing with the AOGCC a 10-403 supplement with additional information as required under 20 AAC 25.080 when the intermediate interval has been drilled and cased. 2) Regarding diverter use, PNRA requests an exception to 20 AAC 25.035 (c) (1) (A) & (B). PNRA plans to use a 12" diverter vent line while drilling the 12'/d' surface hole. ~4P~c~c~~ ~~co~,~-,~~c~~~'~`~`t~~ 3) PNRA would like to request a waiver for porosity logs in the surface hole in accordance with 20 AAC 25.071 (c). The geologic staff has determined that resistivity and gamma ray logs will be run and will provide data in the 12'/<" surface hole, but no data will be obtained from the porosity logs due to lithology and hole conditions. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vance Hazzard, Drilling Superintendent (20 AAC 25.070) 907/343-2116 hazzardv@pioneernrc.com Alaska Oil & Gas Conservation Commission January 24, 2006 Page 3 of 3 2) Geologic Data and Logs (20 AAC 25.071) • Tavia Bicklein, Senior Operations Geologist 907/343-2133 bickleit@pioneernrc.com The anticipated spud date for this well is February 7, 2005 If you have any questions or require further information, please contact Vance Hazzard at 907/343-2116. Sincerely, ance H tilling Superintendent Attachments: $100 check payable to State of Alaska, AOGCC Form 10-401 Supporting permit information cc: Cronus #1 Well File ~ ~nP~ wHe9NiNdi ERR MUST ItAYE A GRAY Br~'Kr(;OUt,~0 W6flCfi FADES TEMPORfiRfLY 4!°HEPE WARR+iED SY:TOUCN O~ FRICTI(ti,. ~I PIONEER NATURRL RESOURCES USA, INC. WELLS FARGO BA1VK, lOT.A. ALASKA CHECKING 11.24 700 G. STREET, SUITE 600 1210(8) ANCHORAGE, AK 99501 DATE Poa oR of State of Alaska, Alaska Oil & Gas Conservation Comm;sc;nn • One Hundred and 00/100--------------. f'E LI~TFF? ON THE BACK. 001073 January 24, 2006 100.00 DOLLARS TWO I~ATRUE EQUIRE~ 2 .00 II'00 LO 7 3n° ~: ~ 2 1000 2480'4 588 54 3 30 ° f~ 6n DETACH AND RETAIN THIS STATEMENT PIONEER NATURAL RESOURCES USA, INC. THE ATTACHED CHECK IS IN PAYMENT OF ITEMS DESCRIBED BELOW. IF NOT CORRECT PLEASE NOTIFY US PROMPTLY. NO RECEIPT DESIRED. ALASKA CHECKINGa DATE DESCRIPTION AMOK 1 /24/06 Well permit fee for Cronus # 1 well. North Slope Exploration Program $100.00 Property # 1840, AFE 9558, Cronus Prospect EMPLOYEE EARNINGS DEDUCTIONS PERIOD TOTAL ENDING HOURS AMOUNT OVERTIME EARNINGS RATE EARNED AT FICA WITHHOLDING STATE REGULAR RATE ANb OTHER US INC.7AX S'D'I' INC. TAX 001073 DISTRIBUTIONS ACCT. NO. AMOUNT TOTAL DEDUCTIONS NET PAY • TRANSMITAL LETTER CHECK LIST WELL NAME l~ ~ ~ u'~ PTD# ~U~ ~ ~~ Development Service Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE 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, C~~~ .~ ~~~~~~ -~~ ~G~ yam/ ~S~•' Rev: 1105/06 ~~~ C:\jody\transmittal_checklist ~ UST ~JQ./ U~ ~-- /-~Ui'JI'J/ ~`/~ ~/ ~8/~'~~ ~j / ~ ~ d G~CT~ v v ~~ ~2.2-~~vee..ti ~ C~ o~ ~~ v ~ tn~ ~ ~~ Cct.S ~-r ~~ o e / s ~-e `/ 12c~. czvL~/•~r~C r ~ ~ r ~-e.Sehce ems- cZ~~nCe o~' ~d~c`t~-r~~ ~~ ~,-~o u~.S~ urr- Ce S a~ ~~" ~~~is-,~ li147~ /- /n ~ ° 3 ~ ° ~ ° N.~ j n N I^~ .. v~ A ~ v~ p ~ v N M O p O D ~ ~'~ ~ ~ ~ v `° N M O p W D Q ~ ~ ~ y ~ M v o N K 3 O p O ~ ~ r N r o o ~ rn a ~ O ~ ~ v ! ! 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. ~t ~~.~~ CONFIDEN11Al ~-a ~ - ©`~ GRAIN SIZE SUMMARY -Pioneer Cronus #1 .Depth (ft) 6288 6301 6307 7112 7117 7127 7144 7153 7158 7172 7196 7250 7262 Mean (phi) 5.107 3.901 4.668 4.564 3.288 3.275 4.327 3.228 3.173 3.511 3.087 3.203 3.468 - Mean (mm) 0.029 0.067 0.039 0.042 0.102 0.103 0.050 0.107 0.111 0.088 .0.118 0.109 0.090 Mean (Sieve Equivalent) (phi) 5.147 4.020 4.736 4.639 3.447 3.436 4.418 3.391 3.340 3.656 3.260 3.368 3.616 Mean (Sieve Equivalent) (mm) 0.028 0.062 0.038 0.040 .0.092 0.092 0.047 0.095 0.099 0.079 0.104 0.097. 0.082 Std. Dev. (phi) 3.106 2.105 2.874 2.726 1.804 1.425 2.601 1.993 .1.502 1.954 1.227 1.514 2.311 Std. Dev. (mm) 0.123 .0.136 0.142 .0.137 0.164 0.119 0.147 0.199 0.137 0.159 0.113 0.136 0.215 Std.Dev. (Sieve Equivalent) (phi) 2.857 1..976 2.653 2.522 1.710 1.377 2.412 .1.877 1.444 1.843 1..203 1.455 2.157 Std.Dev. (Sieve Equivalent) (mm) 0.100 0.113 0.115 0.112 0.136 0.102 0.120 0.162 0.116 0.131 0.097 0.115 0.173 Mean of Framework Fract. (>30Nm) (phi) 3.512 3.343 3.409 3.460 2.899. 3.043 3.423. 2.745 2.922 3.038 2.908 2.935 2.839 Mean of Framework Fract. (>30Nm) (mm) 0.088 0.099 0.094 0.091 0.134 0.121 0.093 0.149 0.132 0.122 0.133 0.131 0.140 Std. Dev. of Framework Fract. (>30Nm) (phi) 0.346 0.324 0.338 0.423 0.496 0.476 0.460 0.480 0.418 0.462 0.435 0.490 0.498 Std. Dev. of Framework Fract. (>30um) (mm) 0.021 0.022 0.022 0.027. 0.047 0.041 0.030 0.051 0.039 0.040 0.041 0.045. 0.049 Minimum Size Value (phi) 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 Minimum Size Value (mm) 0.0002 0.0002. 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 Maxiumum Size Value (phi) 2.693 2.181 2.348 2.135 1..727 1.354 1.519 .0.846 1.787 1.776 1.570 1.453 0.939 Maxiumum Size Value (mm) 0.155 0.221 0.196 0.228 0.302 0.391 0.349 0.556 0:290 0.292 0.337 0.365 0.521 Depth (ft) 7269 7282 7289 7296 7345 T384 7755 7756 7757 7758 7772 7793 7812 Mean (phi) 3.103 3.934 3.284 3.626 4.734 3.868 6.180 4:620 4.662 2.664 8.943 6.229 7.415 Mean (mm) 0.116 0.065 0.103 0.081 0.038 0.068 0.014 0.041 0.039 0.158 0.002 0.013 0.006 Mean (Sieve Equivalent) (phi) 3.274 4.051 3.444 3.763 4.798 3.989 6,149 4.692 4.731 2.865 8.730 6:195 7.303 Mean (Sieve Equivalent) (mm) 0.103 0.060 0.092 0.074 0.036 0.063 0.014 .0.039 0.038 0.137 0.002 0.014 0.006 Std. Dev. (phi) 1.630 2.648 1.480 .2.098 2.980 2.420 3.887 3.741 3.871 1.914 2.967 3.403 3.668 Std. Dev. (mm) 0.161 0.200 0.125 0.164 0.146 0.177 0.102 0.270 0.287 0.276 0.008 0.070 0:037 Std.Dev. (Sieve Equivalent) (phi) 1.557 2.454 1.425 1.970 2.746 2.253. 3.544 3.416 3.530 1.808 2.735 3.118 3.352 Std.Dev. (Sieve Equivalent) (mm) 0.135 0.160 0.106 0.135 0.118 0.143 0.082 0.205 0.216 0.221 .0.008 0.058 0.032 Mean of Framework Fract. (>30um) (phi) 2.793 3.052 3.038 3.082 3.292 3.072 1.710 2.056 1.859 2.209 3.885 3.892 3.908 Mean of Framework Fract. (>30um) (mm) 0.144 0.121 0.122 0.118 0.102 0.119 0.306 0.240 0.276 0.216 0.068 0.067 0.067 Std. Dev. of Framework Fract. (>30Nm) (phi) 0.517 0.487 .0.416 0.475 0.432 0.455 0.644 0.600 0.572 0.495 0.371 0.324 0.371 Std. Dev. of Framework Fract. (>30Nm) (mm) 0.053 0.041 0.036 0.040 0.031 0.038 0.141 0.103 0.112 0.076 0.018 0.015 0.017 Minimum Size Value (phi) 12.397 12.397 12.397 12.397 12.397 12.397 11.396 11.396 11.396 11.396 12.397 12.397 12.397 Minimum Size Value(mm) 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0004 0.0004 0.0004 0.0004. 0.0002 0.0002 0.0002 Maxiumum Size Value (phi) 1.237 1.485 1.975 1.959 1.705 1.314 -0.508 -0.072 -0.043 0.204 2.852 2.975 2.969 .Maxiumum Size Value (mm) 0.424 0.357 0.254 0.257 0.307 0.402 1.422 1.051 1.030 0.868 0.138. 0.127 0.128 POINT COUNT ANALYSTS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 1 Depth/Sample I.D.: 6288 Mean size = 0.088mm (3.51 Phi) Sorting = .346 Phi Porosity = 9.9 Permeability (md) _ .O1 Total Counts = 300 Lithology: Laminated mudstone and argillaceous coarse siltstone and argillaceous very fine-grained very we 11 sorted lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 6288 .PCT Date: 06-18.2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cuts) (X fraction) (X total cats) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 91 30.3 43.3 _30.3 43.1 Polycryst. Quartz (2-5 subunits) 13 4.3 6.2 4.3 6.2 Polycryst. Quartz (>5 subunits) 1 0.3 0.5 0.3 0.5 Polyxln. Quartz w/ Tr. Aligned Mica 2 0.7 1.0 0.7 0.9 Dense Nondescript Chert 10 3.3 4.8 3.3 4.7 Micaceous Quartzite(<8Xmicas/chlorite) 1 0.3 0.5 0.3 0.5 Quartzose Mica.Microschist/Metachrt 2 0.7 1.0 0.7 0.9 Stable Heavy Minerals (Zircon etc.) 1 0.3 0.5 0.3 0.5 Plagioclase 31 10.3 14.8 10.3 14.7 Potassium Feldspar 1 0.3 0.5 0.3 0:5 Granitic Fragment 1 0.3 0.5 0.3 0.5 Basic Volcanic Fragment 1 0.3 0.5 0.3 0.5 Unstable Heavy Minerals (Epidote etc.) 1 0.3 0.5 0.3 0.5 Dolomite Rock Fragments 19 6.3 9.0 6.3 9.0 Organic Fragment 6 2.0 2.9 2.0 2.8 Shale/Mudstone Fragments 3 1.0 1.4 1.0 1.4 Indeterminate Argil.Frag./Ductile 2 0.7 1.0 0.7 0.9 Clay Peloid 3 1.0 1.4 1.0 1.4 Phyllite Fragment 9 3.0 4.3 3.0 4.3 Muscovite 1 0.3 0.5 0.7 0.9 Chlorite 1 0.3 0.5 0.3 0.5 Unknown Rigid Framework Grain 10 3.3 4.8 3.3 4.7 REPLACEMENT COMPONENTS Muscovite Replaced by Kaolinite 1 0.3 .100.0 0.0 0.0 PORES Intergranular Pore (2-20um) 6 2.0 100.0 2.0 100.0 PORE-FILLING COMPONENTS Siderite 8 2.7 15.1 2.7 15.1 Ankerite 11 3.7 20.8 3.7 20.8 Quartz Overgrowths 2 0.7 3.8 0.7 3.8 Clay and Mud Matrix 31 10.3 58.5 10.3 58.5 Sideritic Matrix 1 0.3 1.9 0.3 1.9 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 30 10.0 100.0 10.0 100-.0 SUMMARY CALCULATIONS. COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (X Framwrk)(Non-Folk) 121.00 60.50 60.20 F FeldspathicComponents (XFrmwrk)(Non-Folk) 33.00- 16.50 16.42 L Lithic Components {X Framework)(Non•Folk) 46.00 23.00 23.38 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 118.30 70.84 70.84 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFL) 32.70 19.58 19.58 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 15.00 8.98 8.98 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 42.30 55.27 55.27 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 32.70 19.58 19.58 Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 41.00 24.55 24.55 Total Quartz (XFramework Fraction) 107.00 50.95 50.71 Total Chert (X Framework Fraction) 10.00 4.76 4.74 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 0.00 0.00 0.00 7ot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 3.00 1.43 1.42 Total Plagioclase (XFramework Fraction) 31.00 14.76 14.69 Tot. Potassium Feld. (X Framework Fraction) 1.00 0.48 -0.47 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 1.00 0.48 0.47 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 1.00 0.48 0.47 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 0.00 0.00. 0.00 Tot. Ductile Metamorph.Frags.(% Frmwrk Frac.) 9.00 4.29 4.27 Tot. Carbonate Fragments (X framework Frac.). 19.00 9.05 9.00 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 1.00 0.48 0.47. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, TBN, R6E Age/Strat. Unit Designation: Torok Sand 1 Depth/Sample I.D.: 6288 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION. COMPOSITION Tot. Lithic Sandst.& Sltst (%Frmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 8.00 3.81 3.79 Total Micas b Chlorite (X Framework Fraction) 2.00 0.95 1.42 Total Organic Fragments (XFramework Fraction) 6.00 2.86 2.84 Total Rigid Framework Grains (X Frmwrk Frac.) 185.00 88.10 87.68 Tot.Ductile framework Grains (X Frmwrk Frac.) 25.00 11.90 12.32 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 270.00 270.00 270.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 19.00 7.04 7.04 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 22.00 8.15 7.78 Total Detrital Matrix (X Adj.Tot.Cts.) 62.00 22.96 22,96 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 6.00 2.22 2.22 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 6.00 2.22 2.22 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.00 O.DO 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 60.00 22.22 21.85 Compaction Loss(X Adj. Tot. Cts) 16.57 Bulk Volume Corrected Compaction Loss 21.30 Calculated Initial Porosity 38.79 Tot. Framework-Unknowns-Folk (Total Counts) 187.00 187.00 187.00 Q Quartzose Components-Folk (X Framework) 108.00 57.75 57.75 F Feldspathic Components-Folk.(X Framework) 33.00 17.65 17.65 L Lithic Components-Folk (XFramework) 46.00 24.60 24.60 **~x******:at*~x~r~-x:~**,~***,~~**~***~r*,r*~*,r~* COMMENTS *~~x-*:Fx***:r:r*~*~x~***~*~*,tt*******~x***~~ The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The unstable heavy mineral is an altered opaque. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. The stable heavy mineral is a possible rutile. Some ankerite occurs as overgrowths on detrital dolomite. The very fine grain size promotes extensive component overlap and this makes identification of many components very difficult. The clay pellets are a greenish color and may be poorly crystalline glauconite. It is :also possible that thes e grains are altered chlorite flakes. Three fining-up or coarsening-up cycles are present in this sample. Elongate grains are relatively well aligned. POINT .COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat, Unit Designation: Torok Sand 1 Depth/Sample I.D:: 6301 Mean size = 0.099mm (3.34 Phi) Sorting = .324 Phi Porosity ~ 13.3 Permeability (md) _ .371 Total Counts = 300- Lithology: Very fine-grained very well sorted slightly argillaceous Lithic sandstone cemented by plastic d eformation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 6301 .PCT Date: 06-18.2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cuts) (% fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 89 29.7 36.5 29.7 36.5 Polycryst. Quartz (2-5 subunits) 15 5.0 6.1 5.0 6.1 Polyxln. Quartz w/ Tr. Aligned Mica 11 3.7 4.5 3.7 4.5 Dense Nondescript Chert 28 9.3 11.5 9.3 11.5 Argil7aceous Chert 1 0.3 0.4 0.3 0.4 Micaceous Quartzite(<8Xmicas/chlorite) 7 2.3 2.9 2.3 2.9 Quartzose Mica.Microschist/Metachrt 1 0.3 0.4 0.3 0.4 Plagioclase 25 8.3 10.2 8.3 10.2 Potassium Feldspar 1 0.3 0.4 0.3 0.4 Granitic Fragment 2 0.7 0.8 0.7 0.8 Devitrified Tuff Fragments 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 16 5.3 6.6 5.3 6.6 Organic Fragment 11 3.7 4.5 3.7 4.5 Clay/Mud Clasts 7 2.3 2.9 2.3 2.9 Oversize Clay/Mud Clasts 3 1.0 1.2 1.0 1.2 Indeterminate Argil.Frag./Ductile 1 0.3 0.4 0.3 0.4 Phyllite Fragment 9 3.0 3.7 3.0 3.7 Muscovite 2 0.7 0.8 0.7 0.8 Chlorite 1 0.3 0.4 0.3 0.4 Metasiltstone/Metamudstone 3 1.0 1.2 1.0 1.2 Unknown Rigid Framework Grain 10 3.3 4.1 3.3 4.1 REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) 13 4.3 72.2 4.3 72.2 Intergranular Pore (>20um) 5 1.7 27.8 1.7 27.8 PORE•FILLING COMPONENTS Kaolinite 2 0.7 6.5 0.7 6.5 Siderite 8 2.7 25.8 2.7 25.8 Quartz Overgrowths 5 1.7 16.1 1.7 16.1 Inherited Clay Rims 1 0.3 3.2 0.3 3.2 Pyrite/Marcasite 1 0.3 3.2 0.3 3.2 Clay and Mud Matrix 14 4.7 45.2 4.7 45.2 LAMINA/BURROW FILLS & FRACTURE FILLS - Clay/Mud Laminae and Burrow Fi71s 6 2.0 85.7 2.0 85.7 Siderit. Clay/Mud Lam.& Burrow Fill 1 0.3 14.3 0.3 14.3 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Q Quartzose Components (X Framwrk)(Non-Folk) 152.00 64.96 64.96 F FeldspathicComponents (XFrmwrk)(Non-Folk) 28.00 11.97 11.97 L Lithic Components (X Framework)(Non-Folk) 54.00 23.08 23.08 Qt-Quartzose Comp.(pseudo-Dickin.)(~Tot.QtFL) 151.60 78.55 78.55 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFL) 27.40 14.20 14.20 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 14.00 7.25 7.25 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 96.60 50.05 50.05 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 27.40 14.20 14.20 Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 69.00 35.75 35.75 Total Quartz (XFramework Fraction) 115.00 47.13 47.13 Total Chert (X Framework Fraction)- 29.00 11.89 11.89 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 0.00 0.00 0.00 Tot:Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 8.00 3.28 3.28 Total Plagioclase (XFramework Fraction) 25.00 10.25 10.25 Tot. Potassium Feld.. (X Framework Fraction) 1.00 0.41 0.41 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 2.00 0.82 0.82 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 0.00 0.00 0:00 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 1.00 0.41 0.41 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 12.00 4.92 4.92 Tot. Carbonate Fragments (X Framework Frac.) 16.00 6.56 6.56 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 1 Depth/Sample I.D.: 6301 SUMMARY CALCULATIONS. COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac ) 0.00 0.00 D.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 11.00 4.51 4.51 Total Micas & Chlorite (k Framework Fraction) 3.00 1.23 1.23 Total Organic Fragments (XFramework Fraction) 11.00 4.51 4.51 Total Rigid Framework Grains (X Frmwrk Frac ) 207.00 84.84 84.84 Tot.Ductile Framework Grains (X Frmwrk Frac ) 37.00 15.16 15.16 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 293.00 293.00 293.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 8.00 2.73 2.73 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 2.00 .0.68 0.68 7ota1 Intergranular Cements (XAdj.Tot.Cts) 17.00 5.80 5.80 Total Detrital Matrix (X Adj.Tot.Cts.) 21.00 7.17 7.17 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00. Total Intergranular Porosity (XAdj.Tot.Cts.) 18.00 6.14 6.14 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 18.00 6.14 6.14 Ca1c.5econdary Porosity (X Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 49.00 16.72 16.72 Compaction Loss(X Adj. Tot. Cts) 22.21 Bulk Volume Corrected Compaction Loss 26.67 Calculated Initial Porosity 38.93 Tot. Framework-Unknowns-Folk (Total Counts) 210.00 210.00 210.00 Q Quartzose Components-Folk (X Framework) 122..00 58.10 58.10 F Feldspathic Components-Folk. (X Framework) 28.00 13.33 13.33 L Lithic Components-Folk (XFramework) 60.00 28.57 28.57 ***~x,~**~x***,r********,r~~*,t~x**~*****~rx***x~ COMMENTS *~x*~x***~~,ttr*~-,t*******~,r~~x*,t**,~****,t**~x*~x* The thin section was prepared .from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The tuff fragment is questionable. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. One kaolinite count is questionable. Due to the relatively fine grain size overlap of components is common and locally this makes component identif ication very difficult. POINT .COUNT ANALYSIS Region I.D.: North S1ope.Alaska Well/Outcrop I.D.: Pioneer .Cronus #1, Sec 8, T8N. R6E Age/Strat. Unit Designation: Torok Sand 1 Depth/Sample I.D.: 6307 Mean size = 0.094mm (3.41 Phi) Sorting = .338 Phi Porosity = 11.4 Permeability (md) _ .087 Total Coun ts = 300 Lithology: Very fine-grained very well sorted argillaceous lithic sandstone. cemented by plastic deformatio n and suturing Special Comment: Size and sorting data are measured values and appl y to framework fra ction only. Poroperm Filename: 6307 .PCT Date: 06-18.2006 Formula F ilename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total. cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 77 25.7 33.3 25.7 33.3 Polycryst. Quartz (2-5 subunits) 16 5.3 6.9 5.3 6.9 Polycryst. Quartz (>5 subunits) 2 0.7 0.9 0.7 0.9 Polyxln. Quartz w/ Tr. Aligned Mica 3 1.0 1.3 1.0 1.3 Dense Nondescript Chert 23 7.7 10.0 7.7 10.0 Porous Chert(>33X visible porosity) 1 0.3 0.4 0.3 0.4 Argillaceous Chert 1 0.3 0.4 0.3 0.4 Micaceous Quartzite(<8%micas/chlorite) 4 1.3 1.7 1.3 1.7 Quartzose Mica.Microschist/Metachrt 4 1.3 1.7 1.3 1.7 Quartzose Sandstone/Siltstone Frag. 1 0.3 0.4 0.3 0.4 Stable Heavy Minerals (Zircon etc.) 1 0.3 0.4 0.3 0.4 Plagioclase 16 5.3 6.9 5.3 6.9 Potassium Feldspar 1 0.3 0.4 0.3 0.4 Basic Volcanic Fragment 1 0.3 0.4 0.3 0.4 Unstable Heavy Minerals (Epidote etc.) 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 27 9.0 11.7 9.0 11.7 Organic Fragment 7 2.3 3.0 2.3 3.0 Clay/Mud Clasts 3 1.0 1.3 1.0 1.3 Shale/Mudstone Fragments 7 2.3 3.0 2.3 3.0 Indeterminate Argil.Frag./Ductile 5 1.7 2.2 1.7 2.2 Clay Peloid 1 0.3 0.4 0.3 0.4 Argillite Fragment 1 0.3 0.4 0.3 0.4 Phyllite Fragment 8 2.7 3.5 2.7 3.5 Muscovite 4 1.3 1.7 1.3 1.7 Chlorite 4 1.3 1.7 1.3 1.7 Indeterminate/Altered Mica 1 0.3 0.4 0.3 0.4 Unknown Rigid Framework Grain 11 3.7 4.8 3.7 4.8 REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) 3 1.0 100.0 1.0 100.0 PORE-FILLING COMPONENTS Siderite 9 3.0 18.8 3.0 18.8 Ankerite _ 1 0.3 2.1 _0.3 2.1 Quartz Overgrowths 2 0.7 4.2 0.7 4.2 Clay and Mud Matrix 34 11.3 70.8 11.3 70.8 Sideritic Matrix 2 0.7 4.2 0.7 4.2 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 18 6.0 100.0 6.0 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Q Quartzose Components (X Framwrk)(Non-Folk) 133.00 60.45 60.45 F FeidspathicComponents (XFrmwrk)(Non-Folk) 17.00 7.73 7.73 L Lithic Components (X Framework)(Non-Folk) 70.00 31.82 31.82 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFU 127.50 76.35 76.35 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFL) 17.00 10.18 10.18 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 21.50 12.87 12.87 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 81.50 48.80 48.80 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 17.00 10.18 10.18 Lt-Tot.Lithic Comp.{pseudo-Dick.)(XTot.QmFLt) 67.50 40.42 40.42 Total Quartz (XFramework Fraction) 98.00 42.42 42.42 Total Chert (X .Framework Fraction) 25.00 10.82 10.82 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 1.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 8.00 3.46 3.46 Total Plagioclase (XFramework Fraction) 16.00 6.93 6.93 Tot. Potassium Feld. (X Framework Fraction) 1.00 0.43 0.43 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 1.00 0.43 0.43 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 1 Depth/Sample I.D.: 6307 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Volc.-Glass & Tuff Frags(% Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags.(% Frmwrk Frac.) 9.00 3.90 3.90 Tot. Carbonate Fragments (% Framework Frac.) 27.00 11.69 11.69 Tot.Unstable Heavy Min. & Gabbro(%Frmwk Frac) 1.00 0.43 0.43 Tot. Lithic Sandst.& Sltst (%Frmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(%Frmwrk Frac.) 16.00 6.93 6.93 Total Micas & Chlorite (% framework Fraction) 9.00 3.90 3.90 Total Organic Fragments (%Framework Fraction) 7.00 3.03 3.03 Total Rigid Framework Grains (% Frmwrk Frac.) 190.00 82.25 82.25 Tot. Ductile Framework Grains (% Frmwrk Frac.) 41.00 17.75 17.75 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 282.00 282.00 282.00 Tot. Intergrn.Carbonate Cement(% Adj.Tot.Cts) 10.00 3.55 3.55 Tot. Intergran.Zeolite Cement (% Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (%Adj.Tot.Cts) 12.00 4.26 4.26 Total Detrital Matrix (% Adj.Tot.Cts.) 54.00 19.15 19.15 Tot. Calc.Dissolved Frmwrk(%Tot.Frame.Fract.) 0.40 0.17 0.17 Total Intergranular Porosity (%Adj.Tot.Cts.) 3.00 1.06. 1.06 Ca1c.Secondary Porosity (% Adj.Tot.Cts.) 0.40 0.14 0.14 Tot. Calc. Visible Porosity (%Adj. Tot. Cts.) 3.40 1.21 1.21 Ca1c.Secondary Porosity (% Tot.Vis. Porosity) 0.40 11.76 11.76 Total Intergranular Volume (X Adj.Tot. Cts.) 51.00 18.09 18.09 Compaction Loss(% Adj. Tot. Cts) 20.76 Bulk Volume Corrected Compaction Loss 25.34 Calculated Initial Porosity 38.84 Tot. Framework-Unknowns-Folk (Total Counts) 198.00 198.00 198.00 Q Quartzose Components-Folk (% Framework) 103.00 52.02 52.02 F Feldspathic Components-Folk.(% Framework) 17.00 8.59 8.59 L Lithic Components-Folk (%Framework) 78.00 39.39 39.39 *******:r***,E,t***,r*,tax***~x~r*****,~x*~x~x***~r**~x COMMENTS ,t*,t*****:rx******~:t~x*,ter*~x*******,tt~t****a-,t~,t*~t The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy mineral is a possible phosphatic fragment. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed.. It tends to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. Several fining-up or coarsening•up cycles appear to be present. Due to the relatively fine grain size overlap of components is common and locally this makes component identif ication very difficult. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7112 Mean size = 0.091mm (3.46 Phi) Sorting = .423 Phi Porosity = 6.6 Permeability (md) _ .078 Total Counts = 300 Lithology: Very fine-grained well sorted argillaceous carbonaceous lithic sandstone cemented by plastic de formation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7112 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Polycryst. Quartz (2-5 subunits) Polyxln. Quartz w/ Tr. Aligned Mica Dense Nondescript Chert Argillaceous Chert .Micaceous Quartzite(<8Xmicas/chlorite) Stable Heavy Minerals. (Zircon etc.) Plagioclase Granitic Fragment Basic Volcanic Fragment Devitrified Tuff Fragments Dolomite Rock .Fragments Organic Fragment Clay/Mud Clasts Shale/Mudstone Fragments Argillite Fragment Phyllite Fragment Muscovite Chlorite Indeterminate/Altered Mica Metasiltstone/Metamudstone Unknown Rigid Framework Grain REPLACEMENT COMPONENTS PORES PORE-FILLING COMPONENTS Siderite Clay and Mud Matrix LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total- cnts) (X fraction) 55 18.3 21.7 18.3 21.7 2 0.7 0.8 0.7 0.8 8 2.7 3.1 2.7 3.1 15 5.0 5.9 5.0 5.9 I 0.3 0:4 0.3 0.4 9 3.0 3.5 3.0 3.5 1 0.3 0.4 0.3 0.4 27 9.0 10.6 9.0 10.6 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 2 0.7 0.8 0.7 0.8 7 2.3 2.8 2.3 2.8 88 29.3 34.6 29.3 34.6 2 0.7 0.8 0.7 0.8 7 2.3 2.8 2.3 2.8 3 7.0 1.2 1.0 1.2 10 3.3 3.9 3.3 3.9 2 0.7 0.8 0.7 0.8 4 1.3 1.6 1.3 1.6 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 7 2.3 2.8 2.3 2.8 6 2.0 16.2 2.0 16.2 31 10.3 83.8 10.3 83.8. 9 3.0 100.0 3.0 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Q Quartzose Components (X Framwrk)(Non-Folk) 91.00 36.84 36.84 F FeldspathicComponents (XFrmwrk)(Non-Folk) 28.00 11.34 11.34 L Lithic Components (X Framework)(Non-Folk) 128.00 51.82 51..82 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 90.30 63.15. 63.15 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFL} 27.70 19.37 19.37 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 24.00 16.78 16.78 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 64.30 44.97 44.97 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 27.70 19.37 19.37 Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 50.00 34.97 34.97 Total Quartz (XFramework Fraction) 65.00 25.59 25.59 Total Chert (X Framework Fraction) 16.00 6.30 6.30 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 0.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 9.00 3.54 3.54 Total Plagioclase (XFramework Fraction) 27.00 10.63 10.63 Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 1.00 0.39 0.39 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac} 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 1.00 0.39 0.39 Total Volc. Glass & Tuff Frags(% Frmwrk Frac) 2.00 0.79 0.79 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 14.00 5.51 5.51 Tot. Carbonate Fragments (X Framework Frac.) 7.00 2.76 2.76 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil- Sedimentary Frags.(XFrmwrk Frac.) 9.00 3.54 3.54 Total Micas & Chlorite (X Framework Fraction) 7.00 2.76 2.76 Total Organic Fragments (XFramework Fraction) 88.00 34.65 34.65 Total Rigid Framework Grains (X Frmwrk Frac.) 136.00 53.54 53.54 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N. R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7112 SUMMARY CALCULATIONS. COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION. Tot.Ductile Framework Grains (X Frmwrk Frac.) 118.00 46.46 46.46 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 291.00 291.00 291.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 6.00 2.06 2.06 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 6.00 2.06 2.06 Total Detrital Matrix (X Adj.Tot.Cts.) 40.00 .13.75 13.75 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Gts.) 0.00 0.00 0.00 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 0.00 0.00 0.00 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 37.00 12.71 12.71 Compaction Loss(X Adj. Tot. Cts) 25.60 Bulk Volume Corrected Compaction Loss. 29.33 Calculated Initial Porosity 38.31 Tot. Framework-Unknowns•Folk (Total Counts) 149.00 149.00 149.00 Q Quartzose Components•Folk (X Framework) 74.00 49.66. 49.66 F Feldspathic Components-Folk.(X Framework) 28.00 18.79 18.79 L Lithic Components-Folk (XFramework) 47.00 31.54. 31.54 ******~***********~***~x*~x*~x**,~***********,t* COMMENTS *********~*******,~*~*~*****~~~*~**~***~x The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The tuff fragments are questionable. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. The stable heavy mineral is a rutile. POINT-COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.; 7117 Mean size = 0.134mm (2.90 Phi) Sorting = .496 Phi Porosity = 12.3 Permeability (md) _ .061 Total Counts = 300 Lithology: Fine-grained well sorted slightly argillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7117 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT MonocrystalTine Quartr 75 25.0 28.7 25.0 28.6 Polycryst. Quartz (2-5 subunits) 16 5.3 6.1 5.3 6.1 Polycryst. Quartz (>5 subunits) 3 1.0 1.1 1.0 1.1 Polyxln. Quartz w/ Tr. Aligned Mica 9 3.0 3.4 3.0 3.4 Dense Nondescript Chert 41 13.7 15:7 13.7 15.6 Argillaceous Chert 3 1.0 1.1 1.0 1.1 Micaceous Quartzite(<8Xmicas/chlorite) 11 3.7 4.2 3.7 4.2 Quartzose Mica.Microschist/Metachrt 4 1.3 1.5 1.3 1.5 Plagioclase 15 5.0 5.7 5.0 5.7 Granitic Fragment 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 19 6.3 7.3 6.3 7.3 Organic Fragment 8 2.7 3.1 2.7 3.1 Clay/Mud Clasts 5 1.7 1.9 1.7 1.9 Shale/Mudstone Fragments 9 3.0 3.4 3.0 3.4 Indeterminate Argil.Frag./Ductile 1 0.3 0.4 0.3 0.4 Argillite Fragment 5 7.7 1.9 1.7 1.9 Phyllite Fragment 16 5.3 6.1 5.3 6.1 Muscovite 2 0.7 0.8 1.0 1.1 Biotite 1 0.3 0.4 0.3 0.4 Chlorite 3 1.0 1.1 1.0 1.1 Metasiltstone/Metamudstone 9 3.0 3.4 3.0 3.4 Unknown Rigid Framework Grain 5 1.7 1.9 1.7 1.9 REPLACEMENT COMPONENTS Muscovite Replaced by Kaolinite 1 0.3 100.0 0.0 0.0 PORES Intergranular Pore (2.20um) 7 2.3 87.5 2.3 87.5 Intergranular Pore (>20um) 1 0.3 12.5 0.3 12.5 PORE-FILLING COMPONENTS Siderite 9 3.0 30.0 3.0 30.0 Ankerite 1 0.3 3.3 0.3 3.3 Calcite 1 0.3 3.3 A.3 3.3 Quartz Overgrowths 3 1.0 10.0 1.0 10.0 Plagioclase Ovegrowths 1 0.3 3.3 0.3 3.3 Clay and Mud Matrix 15 5.0 50.0 5.0 50.0 LAMINA/BURROW FILLS b FRACTURE (ILLS SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Q Quartzose Components (X Framwrk)(Non-Folk) 162.00 63.28 63.04 F FeldspathicComponents (XFrmwrk)(Non-Folk) 16.00 6.25 6.23 L Lithic Components (X Framework)(Non•Folk) 78.00 30.47 30.74 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 158.30 72.95 72.95 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFL) 15.70 7.24 7.24 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 43.00 19.82 19.82 Qm•Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 86.30 39.77 39.77 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 15.70 7.24 7.24 Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 115.00 53.00 53.00 Total. Quartz (XFramework Fraction) 103.00 39.46 39.31 Total Chert (X Framework Fraction) 44.00 16.86 16.79 Tot. QuartzoseSstone b Sltstone(XFmwrk Frac) 0.00 0.00 0.00 Tot.Mica.Qtziteb Qtzose Microsch.(XFmwk Frac) 15.00 5..75 5.73 Total Plagioclase (XFramework Fraction) 15.00 5.75. 5.73 Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic bGneissic Frags.(X Frmwrk Frac) 1.00 0.38 0.38 Tot. Feldspath.Sandst.b Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic b Intmed.Volcanics (X Frmwrk Frac.) 0.00 0.00 0.00 Total Volc. Glass b Tuff Frags(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 30.00 11.49 11.45 Tot. Carbonate Fragments (X Framework Frac.) 19.00 7.28 7.25 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec $, TSN, R6E Age/Stmt. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7117 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot.Unstable Heavy Min. & Gabbro(%Frmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 15.00 5.75 5.73 Total Micas & Chlorite (% Framework Fraction)- 6.00 2.30 2.67 Total Organic Fragments (XFramework Fraction) 8.00 3.07 3.05 Total Rigid Framework Grains (X Frmwrk Frac.) 202.00 77.39 77.10 Tot.Ductile Framework Grains (X Frmwrk Frac.) 59.00 22.61 22.90 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 300.00 300.00 300.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 11.00 3.67 3.67 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00. 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 16.00 5.33 5.00 Total Detrital Matrix (% Adj.Tot.Cts.) .15.00 5.00 5.00 Tot. Calc.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 8.00 2.67 2.67 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (%Adj. Tot. Cts.) 8.00 2.67 2.67 Ca1c.Secondary Porosity (% Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (% Adj.Tot: Cts.) 39.00 13.00 12.67 Compaction Loss(X Adj. Tot. Cts) 24.89 Bulk Volume Corrected Compaction Loss 28.61 Calculated Initial Porosity 37.89 Tot. Framework-Unknowns-Folk (Total Counts) 237.00 237.00 237.00 Q Quartzose Components-Folk (X Framework) 114.00 48.10 48.10 F Feldspathic Components-Folk.(X Framework) 16.00 6.75 6.75 L Lithic Components-Folk (XFramework) 107.00 45.15 45.15 . ~*******~x*~****~~~x***~~,tr*************,r*~ COMMENTS. **~x,~x*~x~x****~***,r***:~x****~~~***,tr:t*~**~x,~ The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The ankerite occurs as an overgrowth on a detrital dolomite. The matrix material may contain significant microporosity: The authigenic plagioclase occurs as an overgrowth on a plagioclase grain. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7127 Mean size = 0.121mm (3.05 Phi) Sorting = .476 Phi Porosity = 11.4 Permeability (md) _ .028 Total Coun ts = 300 Lithology: Very fine-grained well sorted lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7127 .PCT Date: 06-18-2006 Fo rmula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (% total cnts) (% fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 59 19.7 22.2 19.7 22:2 Polycryst. Quartz (2-5 subunits) 20 6.7 7.5 6.7 7.5 Polycryst. Quartz (>5 subunits) 4 1.3 1.5 1.3 1.5 Polyxln. Quartz w/ Tr. Aligned Mica 7 2.3 2.6 2.3 2.6 Dense Nondescript Chert 52 17.3 19.5 17.3 19:5 Porous Chert(>33% visible porosity) 2 0.7 0.8 0.7 0.8 Argillaceous Chert 2 0.7 0.8 0.7 0.8 Micaceous Quartzite(<BXmicas/chlorite) 21 7.0 7.9 7.0 7.9 Quartzose Mica.Microschist/Metachrt 2 0.7 0.8 0.7 0.8 Plagioclase 22 7.3 8.3 7.3 8,3 Silicic Volcanic Fragment 2 0.7 0.8 0.7 0.8 Devitrified Tuff fragments 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 13 4.3 4.9 4.3 4.9 Organic Fragment 15 5.0 5.6 5.0 5.6 Clay/Mud Clasts 6 2.0 2.3 2.0 2.3 Shale/Mudstone Fragments 8 2.7 3.0 2.7 3.0 Indeterminate Argil.Frag./Ductile 4 1.3 1.5 1.3 1.5 Argillite Fragment 1 0.3 0.4 0:3 0.4 Phyllite Fragment 12 4.0 4.5 4.0 4.5 Muscovite 3 1.0 1.1 1.0 1.1 Metasiltstone/Metamudstone 6 2.0 2.3 2.0 2.3 Unknown Rigid Framework Grain 4 1.3 1.5 1.3 1.5 REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) 9 3.0 100.0 3.0 100.0 PORE-FILLING COMPONENTS Siderite 14 4.7 58.3 4.7 58.3 Quartz Overgrowths 5 1.7 20.8 1.7 20.8 Clay and Mud Matrix 5 1.7 20.8 1.7 20.8 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 1 0.3 100.0 0.3 100.0 SUMMARY CALCULATIONS COUNTS PRESENT. RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (X Framwrk)(Non-Folk) 169.00 64.50 64.50 F FeldspathicComponents (XFrmwrk)(Non-Folk) 22.00 8.40 8.40 L Lithic Components (X Framework)(Non-Folk) 71.00 27:10 27.10 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFU 167.00 75.57 75.57 F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QtFU 22.00 9.95 9.95 L-Lithic Comp. (pseudo-Dickinson)(%Tot.QtFU 32.00 14.48 14.48 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 80.00 36.20. 36.20 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 22.00 9.95 9.95 Lt-Tot.Lithic Comp.(pseudo•Dick.)(XTot.QmFLt) 119.00 53.85 53.85 Total Quartz (XFramework Fraction) 90.00 33.83 33.83 Total Chert (X Framework Fraction) 56.00. 21.05 21.05 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 0.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 23.00 8.65 8.65 Total Plagioclase (XFramework Fraction) 22.00 8.27 8.27 Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) -0.00 0.00 0.00 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 2.00 0.75 0.75 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 0.00 0.00 0.00 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) . 1.00 0.38 0.38 Tot. Ductile Metamorph.Frags.(% Frmwrk Frac.) 19.00 7.14 7.14 Tot. Carbonate Fragments (X Framework Frac.) 13.00 4.89 4.89 Tot.Unstable Heavy Min. & Gabbro(%Frmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac..) 18.00 6.77 6.77 Total Micas & Chlorite (X Framework Fraction) 3.00 1.13 1.13 Total Organic Fragments (XFramework Fraction) 15.00 5.64 5.64 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8. T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7127 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total .Rigid Framework Grains (X Frmwrk Frac.) 211.00 79.32 79..32 Tot.Ductile Framework Grains (X Frmwrk Frac.) 55.00 20.68 20.68 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 299.00 299.00 299.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 14.00 4.68 4.68 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 19.00 6.35 6.35 Total Detrital Matrix (X Adj.Tot.Cts.) 6.00 2.01 2.01 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.80 0.30 0.30. Total Intergranular Porosity (XAdj.Tot.Cts.) 9.00 3.01 3.01 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.80 0.27 0.27 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 9.80 3.28 3.28 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.80 8.16 8.16 Total Intergranular Volume (X Adj.Tot. Cts.) 33.00 11.04 11.04 Compaction Loss(X Adj. Tot. Cts) 26.97 Bulk Volume Corrected Compaction Loss 30.31 Calculated Initial Porosity 38.00 Tot. Framework-Unknowns-Folk (Total Counts) 238.00 238.00 238.00 Q Quartzose Components-Folk (X Framework) 111.00 46.64 46.64 F Feldspathic Components-Folk.(X Framework) 22.00 9.24 9.24 L Lithic Components-Folk (XFramework) 105.00 44.12 44.12 ******~***~xt*****~~~x*********~****~x~x* COMMENTS **~*****,c*~x************~x*~~*~**~~:rk**~** The thin section was .prepared from a 1 inch diameter rotary sidewall plug and. is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The tuff fragment is questionable. The matrix material may contain significant microporosity. The siderite is very finely .crystalline and is irregularly developed. It tends to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult.. POINT COUNT ANALYSIS Region I.Q.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7144 Mean size = 0.093mm (3.43 Phi) Sorting = .46 Phi Porosity = 8.6 Permeability (md) _ .011 Total Counts = 300 Lithology: Laminated coarse carbonaceous silstone and argillaceous well sorted very fine•grained sandston e cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7144 .PCT Date: 06.18-2006 formula Filename.ext: KUTEII.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Polycryst. Quartz (2-5 subunits) Polyxln. Quartz w/ Tr. Aligned Mica Dense Nondescript Chert Micaceous Quartzite(<BXmicas/chlorite) Quartzose Mica.Microschist/Metachrt Quartzose Sandstone/Siltstone Frag. Stable Heavy Minerals (Zircon etc.) Plagioclase Devitrified Tuff Fragments Carbonate Bioclasts Dolomite Rock Fragments Organic Fragment Clay/Mud Clasts Shale/Mudstone Fragments. Indeterminate Argil.Frag./Ductile Clay Peloid Phyllite Fragment Muscovite Chlorite Indeterminate/Altered Mica Metasiltstone/Metamudstone Unknown Rigid Framework Grain REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) Intergranular Pore (>ZOum) PORE-FILLING COMPONENTS Siderite Ankerite Clay and Mud Matrix LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cuts) (X fraction) 67 22.3 27.0 22.3 27.0 6 2.0 2.4 2.0 2.4 6 2.0 2.4 2.0 2.4 15 5.0 6.0 5.0 6.0 8 2.7 3.2 2.7 3.2 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 25 8.3 10.1 8.3 10.1 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 13 4.3 5.2 4.3 5.2 61 20.3 24.6 20.3 24.6 2 0.7 0.8 0.7 0.8 4 1.3 1.6 1.3 1.6 3 1.0 1.2 1.0 1.2 1 0.3 0.4 0.3 0.4 11 3.7 4.4 3.7 4.4 3 1.0 1.2 1.0 1.2 2 0.7 0.8 0.7 0.8 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 14 4.7 5.6 4.7 5.6 5 1.7 71.4 1.7 71.4 2 0.7 28.6 0.7 28.6 7 2.3 21.9 2.3 21.9 2 0.7 6.3 0.7 6.3 23 7.7 71.9 7.7 71.9 13 4.3 100.0 4.3 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Q Quartzose Components (X Framwrk)(Non-Folk) 105.00 44.87 44.87 F FeldspathicComponents (XFrmwrk)(Non-Folk) 25.00 10.68 10.68 L Lithic Components (X Framework)(Non-Folk) 104.00 44.44 44.44 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFU 102.50 69.73 69.73 F-Feldspath.Comp.(pseudo•Dickin.)(XTot.QtFL) 25.00 17.01 17.01 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 18.50 12.59 12.59 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 75.50 51.36 51.36 F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QmFLt) 25.00 17.01 17.01 Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 45.50 30.95 30,95 Total Quartz (XFramework Fraction) 79.00 31.85 31.85 Total Chert (X Framework Fraction) 15.00 6.05 6.05 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 1.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 9.00 3.63 3.63 Total Plagioclase (XFramework Fraction) 25.00 10.08 10.08 Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac). 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.} 0.00 0.00 0.00 Total Volc. Glass & Tuff Frags{X Frmwrk Frac) 1.00 0.40 0.40 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 12.00 4.84 4.84 Tot. Carbonate Fragments (X Framework Frac ) 14.00 5.65 5.65 Tot.UnstabYe Meavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7144. SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 10.00 4.03 4.03 Total Micas & Chlorite (k framework Fraction) 6.00 2.42 2.42 Total Organic Fragments (XFramework Fraction) 61.00 24.60 24.60 Total Rigid Framework Grains (X Frmwrk Frac.) 159.00 64.11 64.11 Tot. Ductile Framework Grains (X Frmwrk Frac.) 89.00 35.89 35.89 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 287.00 287.00 287.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 9.00 3.14 3.14 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 9.00 3.14 3.14 Total Detrital Matrix (X Adj.Tot.Cts.) 36.00 12.54 12.54 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 7.00 2.44 2.44 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 7.00 2.44 2.44 Calc.Secondary Porosity (X Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 39.00 13.59 13.59 Compaction Loss(X Adj. Tot. Cts) 24.50 Bulk Volume Corrected Compaction Loss- 28.35 Calculated Initial Porosity 38.08 Tot. Framework-Unknowns-Folk (Total Counts) 162.00 162.00 162.00 Q Quartzose Components-Folk (k framework) 88.00 54.32 54.32 f Feldspathic. Components-Folk.(X Framework) 25.00 15.43 15.43 L Lithic Components-Folk (XFramework) 49.00 30.25 30.25 :t:rt-,r***~x***~****~.:t***,t**~***************** .COMMENTS *~x~t**~x*****:t~*~********~*~***~x~xt:tt~ The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The tuff fragment is questionable. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. The stable heavy mineral is a rutile. The very fine grain size promotes extensive component overlap and this makes identification of many components very difficult. The bioclast is probably a bivalve. It is partially dissolved. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: .Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: .Torok Sand 3 Depth/Sample I.D.: 7153 Mean size = 0.149mm (2.75 Phi) Sorting = .48 Phi Porosity = 13.4 Permeability (md) _ .086 Total Counts = 300 Lithology: Fine-grained well sorted slightly argillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values-and apply to framework fraction only. Poroperm Filename: 7153 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Polycryst. Quartz (2-5 subunits) Polycryst. Quartz (>5 subunits) Polyxln. Quartz w/ Tr. Aligned Mica Dense Nondescript Chert Micaceous Quartzite(<8Xmicas/chlorite) Quartzose Mica.Microschist/Metachrt Stable Heavy Minerals (Zircon etc.) Plagioclase Basic Volcanic Fragment Plastically Deformed Basic Volc. Devitrified Tuff Fragments Dolomite Rock Fragments Organic Fragment Clay/Mud Clasts Shale/Mudstone Fragments Indeterminate Argil.Frag./Ductile Argillite Fragment Phyllite Fragment Chlorite Metasiltstone/Metamudstone Unknown Rigid Framework Grain REPLACEMENT COMPONENTS Mesopore in Chert PORES Intergranular Pore (2-20um) Intergranular Pore (>20um) PORE-FILLING COMPONENTS Kaolinite Siderite Ankerite Quartz Overgrowths Clay and Mud Matrix LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cuts) (X fraction) 72 24.0 28.7 24.0 28.6 22 7.3 8.8 7.3 8.7 8 2.7 3.2 2.7 3.2 4 1.3 1.6 1.3 1.6 44 14.7 17.5 15.0 17.9 9 3.0 3.6 3.0 3.6 4 1.3 1.6 1.3 1.6 1 0.3 0.4 0.3 0.4 19 6.3 7.6 6.3 7.5 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 2 0.7 0.8 0.7 0.8 10 3.3 4.0 3.3 4.0 1 0.3 0.4 0.3 0.4 3 1.0 1.2 1.0 1.2 10 3.3 4.0 3.3 4.0 3 1.0 1.2 - 1.0 1.2 2 0.7 0.8 0.7 0.8 18 6.0 7.2 6.0 7.1 1 0.3 0.4 0.3 0.4 11 3.7 4.4 3.7 4.4 5 1.7 2.0 1.7 2.0 1 0.3 100.0 0.0 0.0 9 3.0 '81.8 3.0 81.8 2 0.7 18.2 0.7 18.2 1 0.3 2.9 0.3 2.9 10 3.3 29.4 3.3 29.4 1 0.3 2.9 0.3 2.9 7 2.3 20.6 2.3 2D.6 15 5.0 44.1 5.0 44.1 3 1.0 100.0 1.0 100.0 COUNTS PRESENT RECONSTRUCTED (#) COMPOSITION COMPOSITION ------- ------------- -------------- 164.00 66.67 66.80 19.00 7.72 7.69 63.00 25.61 25.51 159.00 69.74 69.87 19.00 8.33 8.30 49.00. 21.49 21.40 81.00 35.53 35.37 19.00 8.33 8:30.. 127.00 55.70 55.90 106.00 42.23 42.06 44.00 17.53 17.86 0.00 0.00 0.00 13.00 5.18 5.16 19.00 7:57 7.54 0..00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 0.80 0.79 2.00 0.80 0.79 31.00 12.35 12.30 10.00 3.98 3.97 SUMMARY CALCULATIONS DESCRIPTIONS Q Quartzose Components (X Framwrk)(Non-Folk) F FeldspathicComponents (XFrmwrk)(Non-Folk) L Lithic Components (X Framework)(Non-Folk) Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) F-Feldspath.Comp.(pseudo-Di ckin.)(XTot.QtFU L-Lithic Comp. (pseudo•Dickinson)(XTot.QtFL) Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) Total Quartz (XFramework Fraction) Total Chert (X Framework Fraction) Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) Total Plagioclase (XFramework Fraction) Tot. Potassium Feld. (% Framework Fraction). Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) Total Silic.Volcanics (X Framework Fraction) Tot-Basic & Intmed.Volcanics (X Frmwrk Frac ) Total Volc. Glass & Tuff Frags(X Frmwrk Frac) Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) Tot. Carbonate Fragments (X Framework Frac.1 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska. Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7153 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.b Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 16.00 6.37 6.35 Total Micas & Chlorite (X Framework Fraction) 1.00 0.40 0.40 Total Organic Fragments (XFramework Fraction) 1.00 0.40 0.40 Total Rigid Framework Grains (X Frmwrk Frac.) 201.00 80.08 80.16 Tot.Ductile Framework Grains (X Frmwrk Frac.) 50.00 19.92. 19.84 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 297.00 297.00 297.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 11.00 3.70 3.70 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00. 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 1.00 0.34 0.34 Total Intergranular Cements (XAdj.Tot.Cts) 19.00 6.40 6.40 Total Detrital Matrix (k Adj.Tot.Cts.) 18.00 6.06 6.06 Tot. Ca1c.Dissolved Frmwrk(%Tot.Frame.Fract.) 1.00 0.40 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 11.00 3.70 3.70 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 1.00 0.34 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 12.00 4.04 3.70 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 1.00 8.33 0.00 Total Intergranular Volume (X Adj.Tot: Cts.) 45.00 15.15 15.15 Compaction Loss(X Adj. Tot. Cts) 22.84 Bulk Volume Corrected Compaction Loss 26.92 Calculated Initial Porosity 38.00 Tot. Framework-Unknowns-folk (Total Counts) 240.00 240.00 241.00 Q Quartzose Components-Folk (X Framework) 115.00 47.92 47.72 F Feldspathic Components-Folk.(X Framework)' 19.00 7.92 7.88 L Lithic Components-Folk (XFramework) 106.00 44.17 44.40 **:t*~**********~t**,r*:tyr***************~.:r*:r~x***,t** COMMENTS ***~x*~-x***~x**,t****,t,t~t~~-x,rx*,~**~t,t**,ttt*~*~* The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The tuff fragments are somewhat questionable. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult, The stable heavy mineral is an apatite. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation:: Torok Sand 3 Depth/Sample I.D.: 7158 Mean size = 0.132mm (2.92 Phi) Sorting = .418 Phi Porosity = 12.3 Permeability (md) _ .023 Tot al Counts = 300 Lithology: Fine-grained well sorted slightly ar gillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measu red values and apply to framework fraction only. Poroperm Filename.: 7158 .PCT Date: 06-18-2006 Fo rmula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 65 21.7 26.3 21.7 26.2 Polycryst. Quartz (2-5 subunits) 11 3.7 4.5 3.7 4.4 Polycryst. Quartz (>5 subunits) 2 0.7 0.8 0.7 0:8 Polyxln. Quartz w/ Tr. Aligned Miea 6 2.0 2.4 2.0 2.4 Dense Nondescript Chert 40 13.3 16.2 13.7 16.5 Argillaceous Chert 1 0.3 0.4 0.3 0.4 Micaceous Quartzite(<8Xmicas/chlorite) 6 2.0 2.4 2.0 2.4 Quartzose Mica.Microschist/Metachrt 3 1.0 1.2 1.0 1.2 Quartzose Sandstone/Siltstone Frag. 1 0.3 0.4 0.3 0..4 Stable Heavy Minerals (Zircon etc.) 4 1.3 1.6 1.3 1.6 Plagioclase 26 8.7 10.5 8.7 10.5 Granitic fragment 4 1.3 1.6 1.3 1.6 Plastically Deformed Basic Volc. 2 0.7 0.8 0.7 0.8 Unstable Heavy Minerals (Epidote etc.) 1 0.3 0.4 0.3 0.4 Carbonate Allochems (not bioclasts) 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 9 3.0 3.6 3.0 3.6 Organic Fragment 1 0.3 0.4 0.3 0.4 Clay/Mud Clasts 11 3.7 4.5 3.7 4.4 Shale/Mudstone Fragments 7 2.3 2.8 2.3 2.8 Indeterminate Argil.Frag./Ductile 3 1.0 1.2 1.0 1.2 Argillite Fragment 2 0.7 -0.8 0.7 0.8 Phyllite Fragment 25 8.3 10.1 8.3 10.1 Muscovite 3 1.0 1.2 1.0 1.2 Chlorite 3 1.0 1.2 1.0 1.2 Metasiltstone/Metamudstone 5 1.7 2.0 1.7 2.0 Unknown Rigid Framework. Grain 5 1.7 2.0 1.7 2.0 REPLACEMENT COMPONENTS Mesopore in Chert 1 0.3 100.0 0.0 0.0 PORES Intergranular Pore (2-20um) 12 4.0 80.0 4.0 80.0 Intergranular Pore (>20um) 3 1.0 20.0 1.0 20.0 PORE-FILLING COMPONENTS Siderite 15 5.0 44.1 5.0 44.1 Ankerite 3 1.0 8.8 1.0 8.8 Quartz Overgrowths 9 3.0 26.5 3.0 26.5 Clay and Mud Matrix 7 2.3 20.6 2.3 20.6 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 3 1.0 100.0 1.0 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Q Quartzose Components (X Framwrk){Non-Folk) 139.00 57.44 57.61 F FeldspathicComponents (XFrmwrk)(Non-Folk) 30.00 12.40 12.35 L Lithic Components (% Framework)(Non•Folk) 73.00. 30.17 30.04 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 132.70 63.19 63.36 F-Feldspath.Comp.(pseudo•Dickin.)(XTot.QtFL) 28.80 13.71 13.65 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 44.50 21.19 21.09 Qm-Monoxln.Quartz(pseudo-Dickin.)(%Tot.QmFLt) 72.70 34.62 34.45 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 28.80 13.71 13.65 Lt•Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 104.50 49.76 50.00 Total Quartz (XFramework Fraction) 84.00 -34.01 33.87 Total Chert (X Framework Fraction) 41.00 16.60 16.94 Tot. QuartzoseSstone 8 Sltstone(XFmwrk Frac) 1.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 9.00 3.64 3.63 Total Plagioclase (XFramework Fraction) 26.00 10.53 10.48 .Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(% Frmwrk Frac) 4.00 1.62 1.61 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 2.00 0.81 0.81 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8, TBN, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7158 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Volc.-Glass & Tuff Frags(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags_(X Frmwrk Frac.J 32.00 12.96 12.90 Tot. Carbonate Fragments (X Framework Frac.) 10.00- 4.05 4.03 Tot.Unstable Heavy Min, & Gabbro(XFrmwk Frac) 1.00 0.40 0.40 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac ) 21.00 8.50 8.47 Total Micas & Chlorite (X Framework Fraction) 6.00 2.43 2.42 Total Organic Fragments (XFramework fraction) 1.00 0.40 0.40 Total Rigid Framework Grains (X Frmwrk Frac.) 185.00 74.90 75.00 Tot.Ductile Framework Grains (X Frmwrk Frac ) 62.00 25.10 25.00 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 297.00 297.00 297.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 18.00 6.06 6.06 Tot. Intergran.Zeolite Cement (% Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (%Adj.Tot.Cts) 27.00 9.09 9.09 Total Detrital Matrix (X Adj.Tot.Cts.) 10.00 3.37 3.37 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.fract.) 1.00 0.40 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 15.00 5.05 5.05 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 1.00 0.34 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 16.00 5.39. 5.05 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 1.00- 6.25 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 49.00 16.50 16.50 Compaction Loss(X Adj, Tot. Cts) 21.87 Bulk Volume Corrected Compaction Loss 26.19 Calculated Initial Porosity 38.37 Tot. Framework-Unknowns•Folk (Total Counts) .218.00 218.00 219.00 Q Quartzose Components•Folk (X Framework) 91.00 41.74 41.55 F Feldspathic Components-Folk.(X Framework) 30.00 13.76 13.70 L Lithic Components•Folk (XFramework) 97.00 44.50 44.75 ******~x**~**********,t***~x****~**~xr****** COMMENTS ~x*~x*****~,t******~x~t**~**~~x~x**,tr~~r~:t*irr The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material.. The unstable heavy mineral is an altered opaque. The matrix material may contain significant microporosity. The siderite is very finely, crystalline and is irregularly developed.. It tends to occur in small scattered c] usters. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. The stable heavy minerals are a rutile a zircon an apatite and a phosphatic fragment. The quartzose sandstone fragment is a slightly argillaceous quartz-rich sandstone cemented by suturing. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7172 Mean size = 0.122mm (3.04 Phi) Sorting = .462 Phi Porosity = 10.8 Permeability (md) _ .066 Total Counts = 300 Lithology: Very fine-grained well sorted slightly argillaceous Lithic sandstone cemented by plastic deform ation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename:- 7172 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 85 28.3 31.7 28.3 31.6 Polycryst. Quartz (2-5 subunits) 21 7.0 7.8 7.0 7.8 Polycryst. Quartz (>5 subunits) 3 1.0 1.1 1.0 1.1 Polyxln. Quartz w/ Tr. Aligned Mica 10 3.3 3.7 3.3 3.7 Dense Nondescript Chert 37 12.3 13.8 12.3 13.8 Porous Chert(>33X visible porosity) 1 0.3 0.4 0.3 0.4 Argillaceous Chert 1 0.3 0.4 0.3 0.4 Micaceous Quartzite(<8Xmicas/chlorite) 10 3.3 3.7 3.3 3.7 Quartzose Mica.Microschist/Metachrt 4 1.3 1.5 1.3 1.5 Quartzose Sandstone/Siltstone Frag. 2 0.7 0.7 0.7 0.7 Stable Heavy Minerals (Zircon etc.) 1 0.3 0.4 0.3 0.4 Plagioclase 22 7.3 8.2 7.3 8.2 Granitic fragment 2 0.7 0.7 0.7 0.7 Feldspathic Sandstone. Fragment 1 0.3 0.4 0.3 0.4 Silicic Volcanic Fragment 3 1.0 1.1 1.0 1.1 Dolomite Rock Fragments 20 6.7 7.5 6.7 7.4 Organic Fragment 7 2.3 2.6 2.3 2.6 Clay/Mud Clasts 5 1.7 1.9 1.7 1.9 Shale/Mudstone Fragments 5 1.7 1.9 1.7 1.9 Indeterminate Argil.Frag./Ductile 2 0.7 0.7 0.7 0.7 Argillite Fragment 1 0.3 0.4 0.3 0.4 Phyllite Fragment 13 4.3 4.9 4.3 4.8 Chlorite 1 0.3 0.4 0.3 0.4 Metasiltstone/Metamudstone 5 1.7 1.9 1.7 1.9 Unknown Rigid Framework Grain 6 2.0 2.2 2.3 2.6 REPLACEMENT COMPONENTS Unknown Frmwork Grain Repl.by Kaol. 1 0.3 100.0 0.0 0.0 PORES Intergranular Pore (2-20um) 1 0.3 100.0 0.3 100.0 PORE-FILLING COMPONENTS Siderite 8 2.7 28.6 2.7 28.6 Quartz Overgrowths 4 1.3 14.3 1.3 14.3 Plagioclase Ovegrowths 1 0.3 3.6 0.3 3.6 Clay and Mud Matrix 15 5.0 53.6 5.0 53.6 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 2 0.7 100.0 0.7 100.0 SUMMARY CALCULATIONS DESCRIPTIONS Q Quartzose Components (X Framwrk)(Non-Folk) F FeldspathicComponents (XFrmwrk)(Non-.Folk) L Lithic Components (X Framework)(Non-Folk) Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFU L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) Lt-Tot. Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) Total Quartz (XFramework Fraction) Total Chert (X Framework Fraction) Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) Total Plagioclase (XFramework Fraction) Tot. Potassium Feld. (X Framework Fraction) Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) Total Silic.Volcanics (X Framework Fraction) Tot.Basic & Intmed.Volcanics (X Frmwrk Frac ) Total Volc. Glass & Tuff Frags(X Frmwrk Frac) Tot. Ductile Metamorph.Frags.(X Frmwrk Frac ) COUNTS PRESENT RECONSTRUCTED (#) COMPOSITION COMPOSITION 175.00 25.00 62.00 170.10. 23.90 32.00 97.10 23.90 105.00 119.00 39.00 2.00 14.00 22.00 0.00 2.00 1.00 3.00 o.oo 0.00 19.00 ----66.79 9.54 23.66 74.93 10.53 14.10 42.78 10.53 46.26 44.40 14.55 0.01 5.22 8.21 0.00 0.75 0.37 1.12 o. o0 0.00 7.09 --- 66.79 9.54 23.66 74.93 10.53 14.10 42.78 10.53 46.26 44.24 14.50 0.01 5.20 8.18 0.00 0.74 0.37 1.12 o. o0 o.oo 7.06 POINT COUNT. ANALYSIS Region I.D.: .North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N. R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7172 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Carbonate Fragments (X Framework Frac.) 20.00 7.46 7.43 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac ) 12.00 4.48 4.46 Total Micas & Chlorite (% Framework Fraction) 1.00 0.37 0.37 Total Organic Fragments (XFramework Fraction) 7.00 2.61 2.60 Total Rigid Framework Grains (X Frmwrk Frac ) .229.00 .85.45 85.50 Tot.Ductile Framework Grains (X Frmwrk Frac.) .39.00 14.55 14.50 Tot. Cts (adjusted to excl.Artific.Por.6 Lam) 298.00 298.00 298.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 8.00 2.68 2.68 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 13.00 4.36 4.36 Total Detrital Matrix (X Adj.Tot.Cts.) 17.00 5.70 5.70 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.} 0.40 0.15 0.15 Total Intergranular Porosity (XAdj.Tot.Cts.) 1.00 0.34 0.34 Ca1c.Secondary Porosity (X Adj.Tot.Cts:) 0.40 0.13 0.13 Tot. Ca1c. Visible Porosity (XAdj. Tot. Cts.) 1.40 0.47 0.47 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.40 28.57 28.57 Total Intergranular Volume (X Adj.Tot. Cts.) 29.00 9.73 9.73 Compaction Loss(X Adj. Tot. Cts) 28.36 Bulk Volume Corrected Compaction Loss 31.42 Calculated Initial Porosity 38.09 Tot. Framework-Unknowns-Folk (Total Counts) 248.-00 248.00 248.00 Q Quartzose Components-Folk (X Framework} 131.00 52.82 52.82 F Feldspathic Components-Folk.(X Framework) 24.00 9.68 9.68 L Lithic Components-Folk (XFramework) 93.00 37.50 37.50 ~~x~x*************,rt************,t***xk**~x**~*:rk COMMENTS ****,r********~***********~*****,r*~x**i~,t~,t****~ The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy mineral is a rutile. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends. to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are. not present and this makes delineation of ove rgrowths very difficult. POINT .COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8. TBN, R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D:: 7196 Mean size = 0.133mm (2.91 Phi) Sorting = .435 Phi Porosity = 9.8 Permeability (md) _ .006 Total Counts = 300 Lithology: Fine-grained well sorted slightly argillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7196 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED. COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction). FRAMEWORK COMPONENT Monocrystalline Quartz 63 21.0 24.7 21.0 24.6 Polycryst. Quartz (2-5 subunits) 20 6.7 7.8 6.7 7.8 Polycryst. Quartz (>5 subunits) 2 0.7 0.8 0.7 0.8 Polyxln. Quartz w/ Tr. Aligned Mica 12 4.0 4.7 4.0 4.7 Dense Nondescript Chert 35 11.7 `13.7 11.7 13.7 Porous Chert(>33X visible porosity) 1 0.3 0.4 0.3 0.4 Argillaceous Chert 3 1.0 1.2 1.0 1.2 Micaceous Quartzite(<BXmicas/chlorite? 13 4.3 5.1 4.3 5.1 Quartzose Mica.Microschist/Metachrt 2 0.7 0.8 0.7 0.8 Stable Heavy Minerals (Zircon etc.) 1 0.3 0.4 0.3 0.4 Plagioclase 19 6.3 7.5 6.3 7.4 Granitic Fragment 3 1.0 1.2 1.0 1.2 Silicic Volcanic fragment 1 0.3 0.4 0.3 0.4 Plastically Deformed Basic Volc. 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 16 5.3 6.3 5.3 6.3 Organic Fragment. 4 1.3 1.6 1.3 1.6 Clay/Mud Clasts 7 2.3 2.7 2.3 2.7 Shale/Mudstone Fragments 8 2.7 3.1 2.7 3.1 Indeterminate Argil.Frag./Ductile 3 1.0 1.2 1.0 1.2 Argillite Fragment 2 0.7 0.8 0.7 0.8 Phyllite Fragment 22 7.3 8.6 7.3 8.6 Muscovite 1 0.3 0.4 0.3 0.4 Biotite 2 0.7 0.8 0.7 0.8 Chlorite 2 0.7 0.8 0.7 0.8 Indeterminate/Altered Mica 1 0.3 0.4 -0.3 0.4 Metasiltstone/Metamudstone 5 1.7 2.0 1.7 2.0 Unknown Rigid Framework Grain, 6 2.0 2.4 2.3 2.7 REPLACEMENT COMPONENTS Unknown Fretwork Grain Repl.by Kaol. 1 0.3 100.0 0.0 0.0 PORES Intergranular Pore (2-20um) 8 2.7 100.0 2.7 100.0 PORE-FILLING COMPONENTS Siderite 9 3.0 25.0 3.0 25.0 Ankerite 3 1.0 8.3 1.0 8.3 Ferroan Calcite 3 1.0 8.3 1.0 8.3 Quartz Overgrowths 3 1.0 8.3 1.0 8.3 Anatase 2 0.7 5.6 0.7 5.6 Plagioclase Ovegrowths 1 0.3 2.8 0.3 2.8 Clay and Mud Matrix 15 5.0 41.7 5.0 41.7 LAMINA/BURROW FILLS & FRACTURE FILLS .SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (X Framwrk)(Non-Folk) . 152.00 61.04 61.04 F FeldspathicComponents (XFrmwrk)(Non-Folk) 22.00 8.84 8.84. L Lithic Components (X Framework)(Non-Folk) 75.00 30.12 30.12 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 149.90 70.38 70.38 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFL) 21.10 9.91 9.91 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFL) 41.00 19.25 19.25 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 76.90 36.10 36.10 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 21.10 9.91 9.91 Lt-Tot. Lithic Comp:(pseudo-Dick.)(XTot.QmFLt) 114.00 53.52 53.52 Total Quartz (XFramework Fraction) 97.00 38.04 37.89 Total Chert (X Framework Fraction) 39.00 15.29 15.23 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 0.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 15.00 5.88 5.86 Total Plagioclase (XFramework Fraction) 19.00 7.45 7:42 Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 3.00 1.18 1.17 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: .North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. T8N. R6E Age/Strat. Unit Designation: Torok Sand 3 Depth/Sample I.D.: 7196 SUMMARY CALCULATIONS. COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Silic.Volcanics (X Framework Fraction) -1.00 0.39 0.39 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac..) 1.00 0.39 0.39 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 29.00 11.37 ll.33 Tot. Carbonate Fragments (X Framework Frac.) 16.00 6.27 6.25 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac ) .18.00 7.06 7.03 Total Micas & Chlorite (X Framework Fraction) 6.00 2.35 2.34 Total Organic Fragments (XFramework Fraction) 4.00 1.57 1.56 Total Rigid Framework Grains (X Frmwrk Frac.) 197.00 77.25 77.34 Tot.Ductile Framework Grains (X Frmwrk Frac.) 58.00 22.75 22.66 Tot. Cts (adjusted to excl.Artific.Por.B Lam) 300.00 300.00 300.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 15.00 5.00- 5:00 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 21.00 7.00 7.00 Total Detrital .Matrix (X Adj.Tot.Cts.) 15.00 5.00. 5.00 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.40 0.16 0.16 Total Intergranular Porosity (XAdj.Tot.Cts.) 8.00 2.67 2.67 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.40 0.13 0.13 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 8.40 2.80 2.80 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.40 4.76 4.76 Total Intergranular Volume (X Adj.Tot. Cts.) 44.00 14.67 14.67 Compaction Loss(X Adj. Tot. Cts) 23.60 Bulk Volume Corrected Compaction Loss 27.65 Calculated Initial Porosity 38.26 Tot. Framework-Unknowns-Folk (Total. Counts) 231.00 231.00 231.00 Q Quartzose Components-Folk (X Framework) 110.00 47.62 47.62 F Feldspathic Components-Folk.(X Framework) 22.00 9.52 9.52 L Lithic Components-Folk (%Framework) 99.00 42.86 42.86 ********~,t*~r*******~xr***~********~xtt COMMENTS ~******,~x*~~x**:r****~-x********~*****,t*~r~,t~~ The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy mineral is a possible apatite. The matrix material may contain significant microporosity. The siderite is finely crystalline and is irregularly developed. It tends to occur in small scattered cluster s. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. The anatase counts are somewhat questionable. The authigenic plagioclase occurs as overgrowths on a plagioclase grain. POINT .COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7250 Mean size = 0.131mm (2.93 Phi) Sorting = .49 Phi Porosity = 11.4 Permeability (md) _ .098 Total Counts = 300 Lithology: Fine-grained well sorted slightly argillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values. The poroperm data are measured at ambient pres Filename: 7250 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (% fraction) (% total. cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz Polycryst. Quartz (2.5 subunits) Polycryst. Quartz (>5 subunits) Polyxln. Quartz w/ Tr. Aligned Mica Dense Nondescript Chert Argillaceous Chert Micaceous Quartzite(<8Xmicas/chlorite) Quartzose Mica.Microschist/Metachrt Quartzose Sandstone/Siltstone Frag. Acgil. or Chlor. Quartzose Ss/Sltst Stable Heavy Minerals (Zircon etc.) Plagioclase Granitic Fragment Silicic Volcanic Fragment Carbonate Allochems (not bioclasts) Dolomite Rock Fragments Organic Fragment- Clay/Mud Clasts Shale/Mudstone Fragments Indeterminate Argil.Frag./Ductile Argillite Fragment Phyllite Fragment Muscovite Chlorite Metasiltstone/Metamudstone Unknown Rigid Framework Grain REPLACEMENT COMPONENTS. PORES Intergranular Pore (2-20um) Intergranular Pore (>20um) Transparticulate pore (2-20um) PORE-FILLING COMPONENTS Siderite Quartz Overgrowths Clay and Mud Matrix Sideritic Matrix LAMINA/BURROW FILLS 8 FRACTURE FILLS SUMMARY CALCULATIONS DESCRIPTIONS 66 22.0 25.5 22.0 25.5 19 6.3 7.3 6.3 7.3 1 0.3 0.4 0.3 0.4 10 3.3 3.9 3.3 3.9 34 11.3 `13:1 11.3 13.1 3 1.0 1.2 1.0 1.2 13 4.3 5.0 4.3 5.0 4 1.3 1.5 1.3 1.5 1 0.3 0.4 0.3 0.4 2 0.7 0.8 0.7 0.8 2 0.7 0.8 0.7 0.8 21 7.0 8.1 7.0 8.1 2 0.7 0.8 0.7 0.8 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 10 3.3 3.9 3.3 3.9 1 0.3 0.4 0.3 0.4 7 2.3 2.7 2.3 2.7 14 4.7 5.4 4.7 5.4 4 1.3 1.5 1.3 1.5 4 1.3 1.5 1.3 1.5 17 5.7 6.6 5.7 6.6 1 0.3 0.4 0.3 0.4 2 0.7 0.8 0.7 0.8 13 4.3 5.0 4.3 5.0 6 2.0 2.3 2,0 2.3 7 2.3 77.8 2.3 77.8 1 0.3 11.1 0.3 11.L 1 0.3 11.1 0.3 11.1 12 4.0 37.5 4.0 37.5 5 1.7 15.6 1.7 15.6 13 4.3 40.6 4.3 40.6 2 0.7 6.3 0.7 6.3 COUNTS PRESENT RECONSTRUCTED (#) COMPOSITION COMPOSITION 155.00 61.26 61.26 23.00 9.09 9.09 75.00 29.64 29.64 148.10 65.24 65.24 22.40 9.87 9.87. 54.50 24.01 24.01 81.10 35.73 35.73 22.40 9.87 9.87 121.50 53.52 53.52 96.00 37.07 37.07 37.00 14.29 14.29 3.00 0.01 0.01 17.00 6.56 6.56 21.00 8.11 8.11 0.00 0.00 0.00 2.00 0.77 0.77 0.00 0.00 0.00 1.00 0.39 0.39 0.00 0.00 0.00 0.00 0.00 0.00 Q Quartzose Components (% Framwrk)(Non-Folk) F FeldspathicComponents (%Frmwrk)(Non-Folk). L Lithic Components (% Framework)(Non-Folk) Qt-Quartzose Comp.(pseudo-Dickin.)(%Tot.QtFL) F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QtFL) L-Lithic Comp. (pseudo-Dickinson)(%Tot.QtFL) Qm-Monoxln.Quartz(pseudo-Dickin.)(%Tot.QmFLt) F-Feldspath-Comp.(pseudo-Dickin.)(%Tot.QmFLt) Lt-Tot. Lithic Comp.(pseudo•Dick.)(%Tot.QmFLt) Total Quartz (%Framework Fraction) Total Chert (X Framework Fraction) Tot. QuartzoseSstone & Sltstone(%Fmwrk Frac) Tot.Mica.Qtzite& Qtzose Microsch.(%Fmwk Frac) Total Plagioclase (%Framework Fraction) Tot. Potassium Feld. (% Framework Fraction) Tot. Granitic &Gneissic Frags.(% Frmwrk Frac) Tot. Feldspath.Sandst.& Sltst.(% Frmwrk Frac) Total Silic.Volcanics (% Framework fraction) Tot.Basic & Intmed.Volcanics (% Frmwrk Frac.) Total Vol c. Glass & Tuff Frags(X Frmwrk Frac) POINT COUNT. ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, TBN, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7250 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 34.00 13.13 13.13 Tot. Carbonate Fragments (X Framework Frac.) 11.00 4.25 4.25 Tot.Unstable Heavy Min. & Gabbro(%Frmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 25.00 9.65 9.65 Total Micas & Chlorite (X Framework Fraction) 3.00 1.16 1.16 Total Organic Fragments (XFramework Fraction) 1.00 0.39 0.39 Total Rigid Framework Grains (X Frmwrk Frac.) 196.00 75.68 75.68 Tot.Ductile Framework Grains (X Frmwrk Frac.) 63.00 24.32 24.32 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 300.00 300.00 300.00 .Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 12.00 4.00 4.00 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot: Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 17.00 5.67 5.67 Total Detrital Matrix (X Adj.Tot.Cts.) 15.00 5.00 5.00 Tot. Calc.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot:Cts.} 9.00 3.00 3.00 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts:) 9.00 3.00 3.00 Ca1c:Secondary Porosity (X Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 41.00. 13.67 13.67 Compaction Loss(X Adj. Tot. Cts) 24.26 Bulk Volume Corrected Compaction Loss 28.10 Calculated Initial Porosity 37.92 Tot. Framework-Unknowns-Folk (Total Counts) 239.00 239.00 239.00 Q Quartzose Components-Folk (X Framework) 110.00 4b.03 46.03 F Feldspathic Components-Folk.(X Framework) 23.00 9.62 9.62 L Lithic Components-Folk (XFramework) 106.00 44.35 44.35 ~*~-x*,tt*****~x*~xr~x:E*~x*x~~*~x***~x~~,r*~~x* COMMENTS *******,tx*****~x~x**,rt:t~t~t**:t,r*~*~**~~*~t,t~** The thin section was prepared from a l inch diameter rotary sidewall plug and is stained for potassium feldspa` r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy minerals are a rutile and a probable zirco n. The matrix material may contain significant microporosity. The siderite is finely crystalline and is irregularly developed. It tends to occur in small scattered cluster s. Dust rims on many quartz grains are very poorly developed o r are not present and this makes delineation of ove rgrowths very difficult. The quartzose sandstone fragments are cemented by suturing. One of the quartz grains with traces of micas a ctually is a quartz gr ain with moderate amounts of vermicular c hlorite and is probably a vein quartz. POINT COUNT ANALYSIS Region I.D.: North. Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: .Torok Sand 4 Depth/Sample I.D.: 7262 Mean size = 0.140mm (2.84 Phi) Sorting = .498 Phi Porosity = 10.9 Permeability (md) _ .039 Total .Counts = .300 Lithology: Fine-grained well sorted slightly argillaceous lithic sandstone cemented by .plastic deformation .and suturing Special Comment: Size and sorting data are measured values. and apply to framework fraction only. Poroperm Filename: 7262 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (% total cnts) (% fraction) (% total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 77 25.7 33.2 25.7 33.0 Polycryst. Quartz (2.5 subunits) 7 2.3 3.0 2.3 3.0 Polycryst. Quartz (>5 subunits) 4 1.3 1.7 1.3 1.7 Polyxln, Quartz w/ Tr. Aligned Mica 11 3.7 4.7 3.7 4:7 Dense Nondescript Chert 26 8:7 11.2 8.7 11.2 Porous Chert(>33X visible porosity) 1 0.3 0.4 0.3 0.4 Argillaceous Chert 2 0.7 0.9 0.7 0.9 Micaceous Quartzite(<8Xmicas/chlorite) 11 3.7 4.7 3.7 4.7 Quartzose Mica.Microschist/Metachrt 3 1.0 1.3 1.0 1.3 Stable Heavy Minerals (Zircon etc.) 1 0.3 0.4 0.3 0.4 Plagioclase 21 7.0 9.1 7.0 9.0 Extensively Fractured Plagioclase 1 0.3 0.4 0.3 0.4 Granitic Fragment 3 1.0 1.3 1.0 1.3 Feldspathic Siltstone/Mudstone 1 0.3 0.4 0.3 0.4 Unstable Heavy Minerals (Epidote etc.) 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 13 4.3 5.6 4.3 5.6 .Organic Fragment 2 0.7 0.9 0.7 0.9 Clay/Mud Clasts 2 0.7 0.9 0.7 0.9 Shale/Mudstone Fragments 8 2.7 3.4 2.7 3.4 Indeterminate Argil.Frag./Ductile 4 1.3 1.7 1.3 1.7 Argillite Fragment 4 1.3 1.7 1.3 1.7 Phyllite Fragment 16 5.3 6.9 5.3 6.9 Metasiltstone/Metamudstone 5 1.7 2.2 1.7 2.1 Unknown Rigid Framework Grain 8 2.7 3.4 3.0 3.9 REPLACEMENT COMPONENTS Unknown Replaced by Ferroarr Calcite 1 0.3 100.0 0.0 0.0 PORES Intergranular Pore (2-20um) 8 2.7 100.0 2.7 100.0 PORE-FILLING COMPONENTS Siderite 32 10.7 55.2 10.7 55.2 Ankerite 1 0.3 1.7 0.3 1.7 Quartz Overgrowths 5 1.7 8.6 1.7 8.6 Clay and Mud Matrix 11 3.7 19.0 3.7 19.0 Sideritic Matrix 9 3.0 15.5 3.0 15.5 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 1 0.3 100.0 0.3 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (X Framwrk)(Non-Folk) 143.00 63.84 63.84 F FeldspathicComponents (XFrmwrk)(Non-Folk) 26.00 11.61 11.61 L Lithic Components (% Framework)(Non-Folk) 55.00 24.55 24.55 Qt-Quartzose Comp..(pseudo-Dickin.)(%Tot.QtFL) 139.90 69.26 69.26 F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QtfU 24.10 11.93 11.93 L-Lithic Comp. (pseudo-Dickinson)(%Tot.QtFL) 37.00 18.32 18.32 Qm-Monoxln.Quartz(pseudo-Dickin.)(%Tot.QmFLt) 88.90 44.01 44.01 F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QmFLt) 24..10 11.93 11.93 Lt-Tot.Lithic Comp.(pseudo-Dick.)(%Tot.QmFLt) 88.00 43.56 43.56 Total Quartz (%Framework fraction) 99.00 42.67 42.49 Total Chert (% Framework Fraction) 29.00 12.50 12.45 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 0.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(%Fmwk Frac) 14.00 6:03 6.01 Total Plagioclase (XFramework Fraction) 22.00 9.48 9.44 Tot. Potassium Feld. (% Framework Fraction) O.OD 0.00 0.00 Tot. Granitic &Gneissic Frags.(% Frmwrk Frac) 3.00 1.29 1.29 Tot. Feldspath.Sandst.& Sltst.(% Frmwrk Frac) 1.00 0.43 0.43 Total Silic.Volcanics (% Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (% Frmwrk Frac.) 0.00 0.00 0.00 Total Vo1c. Glass & Tuff Frags(% Frmwrk Frac) 0.00 0.00 0,00 Tot. Ductile Metamorph.Frags.(% Frmwrk Frac.) 25.00 10.78 10.73 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #i. Sec 8. TSN, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7262. SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED- DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Carbonate Fragments (X Framework Frac.) 13.00 5.60 5.58 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 1.00 0.43 0.43 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frogs.{XFrmwrk Frac.) 14.00 6.03 6.01 Total Micas & Chlorite (X Framework Fraction) 0.00 0.00 0.00 Total Organic Fragments (XFramework Fraction) 2.00 0.86 0.86 Total Rigid Framework Grains (X Frmwrk Frac.) 191.00 82.33. 82.40 Tot.Ductile Framework Grains (X Frmwrk Frac.) 41.00 17.67 17.60 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 299.00 299.00 299.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 33.00 11.04 11.04 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) .38.00 12.71 12.71 Total Detrital Matrix (X Adj.Tot.Cts.) 21.00 7.02 7.02 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.40 0.17 0.17 Total Intergranular Porosity (XAdj.Tot.Cts.) 8.00 2.68 2.68 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.40 0.13 0.13 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 8.40 2.81 2.81 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.40 4.76 4.76 Total Intergranular Volume (X Adj.Tot. Cts.) 66.00 22.07 22.07 Compaction Loss(X Adj. Tot. Cts) 15.80 Bulk Volume Corrected Compaction Loss 20.28 Calculated Initial Porosity 37.88 Tot. Framework-Unknowns-Folk (Total Counts) 218.00 218.00 218.00 Q Quartzose Components-Folk (% Framework) 110.00 50.46 50.46 F Feldspathic Components-Folk.(X Framework) 25.00 11.47 11.47 L Lithic Components-Folk (XFramework) 83.00 38.07 38.07 *~x,+~*****,tt*~x~r***,~***~x*****~rx********,r,~-x,E**~x COMMENTS ',~**~x*,r,~******~x*****~*****~x*,~x***~~** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy mineral is a rutile. The matrix and sideritic matrix probably contain significant microporosity. The siderite tends to occurs as thin finely crystalline pore linings. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. The unstable heavy mineral is an opaque whose center has been dissolved. The stable heavy mineral is a possible chloritoid. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7269 Mean size = 0.144mm (2.80 Phi) Sorting = .517 Phi Porosity = 11.4 Permeability (md) _ .019 Total Counts = 300 Lithology: Fine-grained well sorted slightly argillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values-and apply to framework fraction only. Poroperm Filename: 7269 .PCT Date: 06-18-2006 Formula Filename.ext; KUTEII.WK1, COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Polycryst. Quartz (2-5 subunits) Polycryst. Quartz (>5 subunits) Polyxln. Quartz w/ Tr. Aligned Mica Dense Nondescript Chert Porous Chert(>33X visible porosity) Argillaceous Chert Micaceous Quartzite(<8Xmicas/chlorite) Quartzose Mica.Microschist/Metachrt Argil. or Chlor. Quartzose Ss/Sltst Stable Heavy Minerals (Zircon etc.) Plagioclase Extensively Fractured Plagioclase. Granitic Fragment Feldspathic Sandstone Fragment Basic Volcanic Fragment Plastically Deformed Basic Volc. Devitrified Tuff Fragments Dolomite Rock Fragments Organic Fragment Clay/Mud Clasts Shale/Mudstone Fragments Indeterminate Argil.Frag./Ductile Argillite Fragment Phyllite Fragment Muscovite Chlorite Metasiltstone/Metamudstone Unknown Rigid Framework Grain REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) Intergranular Pore (>20um) PORE-FILLING COMPONENTS Siderite Ankerite Quartz Overgrowths Plagioclase Ovegrowths Clay and Mud Matrix Sideritic Matrix LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) 62 20.7 24.5 20.7 24.5 12 4.0 4.7 4.0 4.7 2 0.7 0.8 0.7 0:8 9 3.0 3.6 3.0 3.6 38 12.7 15.0. 12.7 15.0 2 0.7 0.8 0.7 0.8 3 1.0 1.2 1.0 1.2 10 3.3 4.0 3.3 4.0 3 1.0 1.2 1.0 1.2 2 0.7 0.8 0.7 0.8 2 0.7 0.8 0.7 0.8 34 11.3 13.4 11.3 13.4 1 0.3 0.4 0.3 0.4 4 1.3 1.6 1.3 1.6 1 0.3 0.4 0.3 0.4 L 0.3 0.4 0.3 0.4 2 0.7 0.8 0.7 0.8 1 0.3 0.4 0.3 0.4 10 3.3 4.0 3.3 4.0 3 1.0 1.2 1.0 1.2 6 2.0 2.4 2.0 2.4 8 2.7 3.2 2.7 3.2 3 1.0 1.2 1.0 1.2 2 0.7 0.8 0.7 0.8 16 5.3 6.3 5.3 6.3 2 0.7 0.8 0.7 0.8 3 1.0 I.2 1.0 1.2 4 1.3 1.6 1.3 1.6 7 2.3 2.8 2.3 2.8 11 3.7 78:6 3.7 78.6 3 1.0 21.4 1.0 21.4 6 2.0 18.8 2.0 18.8 1 0.3 3.1 0.3 3.1 11 3.7 34.4 3.7 34.4 1 0.3 3.1 0.3 3:1 12 4.0 37.5 4.0 37.5 1 0.3 3.1 0.3 3.1 1 100.0 SUMMARY CALCULATIONS DESCRIPTIONS Q Quartzose Components (X Framwrk)(Non•Folk) F FeldspathicComponents (XFrmwrk)(Non-Folk) L Lithic Components (X Framework)(Non•Folk) Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFU F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QtFL) L•Lithic Comp. (pseudo•Dickinson)(XTot.QtFL) Qm-Monoxln.Quartz(pseudo•Dickin.)(XTot.QmFLt) F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) Lt-Tot.Lithic Comp.(pseudo•Dick.)(XTot.Qmflt) Total Quartz (XFramework Fraction) Total Chert (X Framework Fraction) Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) Total Plagioclase (XFramework Fraction) Tot. Potassium Feld. (X Framework Fraction) 0.3 COUNTS PRESENT .RECONSTRUCTED (#) COMPOSITION COMPOSITION 145.00 58.94 58.94. 40.00 16.26 16.26 61.00 24.80 24.80 140.70 64.25 64.25 38.30 17.49 17.49 38.00 .17.35 17.35 74.70 34.11 34.11 38.30 17.49 17.49 104.00 47.49 47.49 85.00 33.60 33.60 43.00 17.00 17.00 2:00 0.01 0.01 13.00 5.14 5.14 35.00 13.83 13.83 0.00 0.00 0.00 0.3 100.0 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7269, SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 4.00 1.58 1.58 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 1.00 0.40 0.40 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 3.00 1.19 1.19 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 1.00 0.40 0.40 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 22.00 8.70 8.70 Tot. Carbonate Fragments (X Framework Frac.) 10.00 3.95 3.95 Tot.Unstable Heavy Min. b Gabbro(XFrmwk Frac) 0.00. 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(kFrmwrk Frac.) 17.00 6.72 6.72 Total Micas & Chlorite (X Framework Fraction) 5.00 1.98 1.98 Total Organic Fragments (XFramework Fraction) 3.00 1.19 1.19 -Total Rigid Framework Grains (X Frmwrk Frac.) 204.00 80.63 80.63 Tot.Ductile Framework Grains (X Frmwrk Frac.) 49.00 19.37 19.37 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 299.00 299.00 299.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 7.00 2.34 2.34 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 19.00 6.35 6.35 Total Detrital Matrix (X Adj.Tot.Cts.) 14.00 4.68 4.68 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.80 0.32 0.32 Total Intergranular Porosity (XAdj.Tot.Cts.) 14.00 4.68 4.68 Ca1c.Secondary Porosity (% Adj.Tot.Cts.}. 0.80 0.27 0.27 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 14.80 4.95 4.95 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.80 5.41 5..41 Total Intergranular Volume (X Adj.Tot. Cts.) 46.00 15.38 15.38 Compaction Loss(X Adj. Tot. Cts) 22.38 Bulk Volume Corrected Compaction Loss. .26.45 Calculated Initial Porosity 37.76 Tot. Framework-Unknowns-Folk (Total Counts) 230.00 230.00 230.00 Q Quartzose Components-Folk (X Framework) 95.00 41.30 41.30 F Feldspathic Components-Folk. (X Framework) 39.00 16.96 16.96 L Lithic Components-Folk (XFramework) 96.00 41.74 41.74 **,t:t***~x**~x~*~***,t:tx*******:t,~**~xr******** COMMENTS *********,r,t~*********~x~x**********,~x***~r*,ttt**** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy minerals are an apatite and a chloritoid. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. The tuff fragment is questionable. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation:.. Torok Sand 4 Depth/Sample I.D.: 7282 Mean size = 0.121mm (3.05 Phi) Sorting = .487 Phi Porosity = 10.3 Permeability (md) _ .012 Total Counts = .300 Lithology: Very fine-grained well sorted argillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7282 .PCT Date: 06.18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT. RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X t otal cnts) (X fraction) (% total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 86 28.7 33.6 28.7 33.6 Polycryst. Quartz (2-5 subunits) 9 3.0 3.5 3.0 3.5 Polycryst. Quartz (>5 subunits) 1 0.3 0.4 0.3 0:4 Polyxln. Quartz w/ Tr, Aligned Mica 6 2.0 2.3 2.0 2.3 Dense Nondescript Chert 25 8.3 9.8 8.3 9.8 Argillaceous Chert 1 0.3 0.4 0.3 0.4 Micaceous Quartzite(<BXmicas/chlorite) 12 4.0 4.7 4.0 4.7 Quartzose Mica.Microschist/Metachrt 3 1.0 1.2 1.0 1.2 Argil. or Chlor. Quartzose Ss/Sltst 3 1.0 1.2 1.0 1.2 Stable Heavy Minerals (Zircon etc.) 1 0.3 0.4 0.3 0.4 Plagioclase 24 8.0 9.4 8.0 9.4 Granitic Fragment 2 0.7 0.8 0.7 0.8 Silicic Volcanic Fragment 1 0.3 0.4 0.3 0.4 Basic Volcanic Fragment 1 -0.3 0.4 0.3 0.4 Unstable Heavy Minerals (Epidote etc.) 1 0-3 0:4 0.3 0.4 Dolomite Rock Fragments 9 3.0 3.5 3.0 3.5 Organic Fragment 10 3.3 3.9 3.3 3.9 Clay/Mud Clasts 3 1.0 1.2 1.0 1.2 Shale/Mudstone Fragments 8 2.7 3.1 2.7 3.1 Indeterminate Argil.Frag./Ductile 4 1.3 1.6 1.3 1.6 Argillite Fragment 2 0.7 0.8 0.7 0.8 Phyllite Fragment 17 5.7 6.6 5.7 6.6 Muscovite 2 0.7 0.8 0.7 0.8 Chlorite 5 1.7 ~ 2.0 1.7 2.0 Indeterminate/Altered Mica 1 0.3 0.4 0.3 0.4 Metasiltstone/Metamudstone 7 2.3 2.7 2.3 2.7 Unknown Rigid Framework Grain 12 4.0 4.7 4.0 4.7 REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) 3 1.0 75.0 1.0 75.0 Intergranular Pore (>20um) 1 0.3 25.0 0.3 25.0 PORE-FILLING COMPONENTS Siderite 6 2.0 16.7 2.0 16.7 Ferroan Calcite 1 0.3 2.8 0.3 2.8 Quartz Overgrowths 2 0.7 5.6 0.7 5.6 Inherited Clay Rims 1 0.3 2.8 0.3 2.8 Clay and Mud Matrix 26 8.7 72.2 8.7 72.2 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 4 1.3 100.0 1.3 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (X Framwrk)(Non-Folk) 147.00 60.25 60.25 F FeldspathicComponents (XFrmwrk)(Non-Folk) 26.00 10.66 10.66 L Lithic Components (X Framework)(Non-Folk) 71.00 29.10 29.10. Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 142.10 67.99 67.99 F-Feldspath.Comp.(pseudo-Dickin.){XTot.QtFL) 25.40 12.15 12.15 L-Lithic Comp. (pseudo•Dickinson)(XTot.QtFL) 40.50 19.38 19.38 Qm-Monoxln.Quartz(pseudo•Dickin.)(XTot.QmFLt) 100.10 47.89 47.89 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 25.40 12.15 12.15 Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 82.50 .39.47 39.47 Total Quartz (XFramework Fraction) 102.00 39.84 39.84 Total Chert (X Framework Fraction) 26.00 10:16 10.16 . Tot. QuartzoseSstone & Sltstone(XFmwrk Frac} 3.00 0.01 0.01 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 15.00 5.86 5.86 Total Plagioclase (XFramework Fraction) 24.00 9.38 9.38 Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(% Frmwrk Frac) 2.00 0.78 0.78 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) .0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 1.00 0.39 0.39 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska. Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7282 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 1.00 0.39 0.39 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac ) 26.00 10.16 10.16 Tot. Carbonate Fragments (X Framework Frac.) 9.00 3.52 3.52 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 1.00 0.39 0.39 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 15.00 5.86 5.86 Total Micas & Chlorite (X Framework Fraction) 8.00 3.13 3.13 Total Organic fragments (XFramework Fraction) 10.00 3.91' 3.91 Total Rigid Framework Grains (X Frmwrk Frac.) 197.00 76.95. 76.95 Tot.Ductile Framework Grains (X Frmwrk Frac:) 59.00 23.05 23.05 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 296.00 296.00 296.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 7.00 2.36 2.36 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 10:00 3.38 3.38 Total Detrital Matrix (X Adj.Tot.Cts.) 30.00 10.14 10.14 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 4.00 1.35 1.35 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot: Ca1C. Visible Porosity (XAdj. Tot. Cts.) 4.00 1.35 1.35 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 40.00 13.51 13.51 Compaction Loss(X Adj. Tot. Cts) 24.42 Bulk Volume Corrected Compaction Loss 28.24 Calculated Initial Porosity 37.93 Tot. Framework-Unknowns-Folk (Total Counts) 221.00 221.00 221.00 Q Quartzose Components-Folk (X Framework) 114.00 51.58 51.58 F Feldspathic Components-Folk.(% Framework) 26.00 11.76 11.76 L Lithic Components-Folk (XFramework) 81.00 36.65 36.65 *****~x*~~*******~-xt:t*,t~r~****~x,~*~**~*~**,t~* COMMENTS ~~**************~***~t******~x******~~r~r*** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy mineral is a possible apatite. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. The unstable heavy mineral is an opaque. The argillaceous/micaceous quartzose sandstone fragments are cemented by suturing. POINT COUNT ANALYSIS Region T.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7289 Mean size = 0.122mm (3.04 Phi) Sorting = .416 Phi Porosity = 10.3 Permeability (md) _ .012 Total Counts = 300 Lithology: Very fine-grained well sorted slightly argillaceous lithic sandstone cemented by plastic deform ation and suturing Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7289 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 76 25.3 31.9 25.3 31,9 Polycryst. Quartz (2-5 subunits) 6 2.0 2.5 2.0 2.5 Polycryst. Quartz (>5 subunits) 1 0.3 0.4 0.3 0:4 Polyxin. Quartz w/ Tr. Aligned Mica 7 2.3 2.9 2.3 2.9 Dense Nondescript Chert 20 6.7 8.4 6.7 8.4 Argillaceous Chert 1 0.3 0.4 0.3 0.4 Micaceous Quartzite(<8%micas/chlorite) 13 4.3 5.5 4.3 5.5 Quartzose Mica.Microschist/Metachrt 1 0.3 0.4 0.3 0.4 Stable Heavy Minerals (Zircon etc.) 1 0.3 0.4 0.3 0.4 Plagioclase 32 10.7 13.4 10.7 13.4 Granitic Fragment 4 1.3 1.7 1.3 1.7 Feldspathic Sandstone Fragment 1 0.3 0.4 0.3 0.4 Silicic Volcanic Fragment 3 1.0 1.3 1.0 1.3 Carbonate Allochems (not bioclasts) 1 0.3 0:4 0.3 0.4 Dolomite Rock Fragments 14 4.7 5.9 4.7 5.9 Organic Fragment 2 0.7 0.8 0.7 0.8 Clay/Mud Clasts 4 1.3 1.7 1.3 1.7 Shale/Mudstone Fragments 9 3.0 3.8 3,0 3.8 Indeterminate Argil.Frag./Ductile 7 2.3 2.9 2.3 2.9 Argillite Fragment 1 0.3 0.4 0.3 0.4 Phyllite Fragment 11 3.7 4.6 3.7 4.6 Metasiltstone/Metamudstone 11 3.7 4.6 3.7 4.6 Unknown Rigid Framework Grain 12 4.0 5.0 4.0 5.0 REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um} 12 4.0 92.3 4:0 92.3 Intergranular Pore (>20um) 1 0.3 7.7 0.3 7.7 PORE-FILLING COMPONENTS Siderite 28 9.3 58.3 9.3 58.3 Quartz Overgrowths 6 2.0 12.5 2.0 12.5 Clay and Mud Matrix 5 1.7 10.4 1.7 10.4 Sideritic Matrix 9 3.0 18.8 3.0 18.8 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 1 0.3 100.0 0.3 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (% Framwrk)(Non-Folk) 126.00 55.75 55.75 F FeldspathicComponents (%Frmwrk)(Non-Folk) 37.00 16.37 16.37 L Lithic Components (X Framework)(Non-Folk) 63.00 27.88 27.88 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 125.70 63.48. 63.48 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFU 35.30 17.83 17.83 L-Lithic Comp. (pseudo-DickinsoN (XTot.QtFL) 36.00 18.18 18.18 Qm-Monoxln.Quartz(pseudo-Dickin.)(XTot.QmFLt) 90.70 45.81 45.81 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 35.30 17.83 17.83 Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 71.00 35.86 35.86 Total Quartz (XFramework Fraction) 90.00 37.82 37.82 Total Chert (X Framework Fraction) 21.00 8.82 8.82 Tot. QuartzoseSstone & Sltstone(%Fmwrk Frac) -0.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 14.00 5.88 5.88 Total Plagioclase (XFramework Fraction) 32.00 13.45 13.45 Tot. Potassium Feld. (% Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(% Frmwrk Frac) 4.00 1.68 1.68 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 1.00 0.42 0.42 Total Silic.Volcanics (X Framework Fraction) 3.00 1.26 1.26 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 0.00 0.00 0.00 Total Vol c. Glass & Tuff Frags(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags.(% Frmwrk Frac.) 23.00 9.66 9.66 Tot. Carbonate Fragments (X Framework Frac.) 15.00 6.30 6.30 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: .North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, TBN, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7289 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) -0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 20.00 8.40 8.40 Total Micas & Chlorite (X Framework Fraction) -0.00 0.00 0.00 Total Organic Fragments (XFramework Fraction) 2.00 0.84 0.84 Total Rigid Framework Grains (X Frmwrk Frac.) .193.00 81.09 81.09 Tot.Ductile Framework Grains (X Frmwrk Frac.) 45.00 18.91 18.91 Tot. Cts (adjusted to excl.Artific.Por.& Lam) .299.00 299.00 299.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) .28.00 9.36 9.36 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 34.00 11.37 11.37 Total Detrital Matrix (X Adj.Tot.Cts.) 15.00 5.02 5.02 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 13.00 4.35 4.35 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) .13.00 4.35 4.35 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 61.00 20.40. 20.40 Compaction Loss(X Adj. Tot. Cts) 17.97 Bulk Volume Corrected Compaction Loss 22.58 Calculated Initial Porosity 38.38 Tot. Framework-Unknowns-Folk (Total Counts) 218.00 218.00 218.00 Q Quartzose Components-Folk (X Framework) 103.00 47.25 47.25 F Feldspathic Components-Folk.(X Framework) 36.00 16.51 16.51 L Lithic Components-Folk (%Framework) 79.00 36.24 36.24 ~~*****~~*******~**********~** COMMENTS ~,~*,~**~~,~*****~*,r~**********~**~,~** The thin section was prepared from a f inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy mineral is an apatite. Both the siderite and matrix may contain significant hidden microporosity. The siderite occurs as thin very finely crystalline pore linings. Dust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. The feldspathic sandstone fragment is probably a low-grade metasandstone. POINT .COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. T8N. R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7296 Mean size = 0.118mm (3.08 Phi) Sorting = .475 Phi Porosity = 9.6 Permeability (md) _ .007 Total Counts = 300 Lithology: Very fine-grained well sorted slightly argillaceous lithic sandstone ation and suturing Special Comment: Size and sorting data are measured values and apply to framework Filename: 7296 .PCT Date: 06-18.2006 Formula Filename.ext: KUTEII.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz. Polycryst. Quartz (2.5 subunits) Polycryst. Quartz (>5 subunits) Polyxln. Quartr w/ Tr. Aligned Mica Dense Nondescript Chert Argillaceous Chert Micaceous Quartzite(<8%micas/chlorite) Quartzose Mica.Microschist/Metachrt Argil, or Chlor. Quartzose. Ss/Sltst Plagioclase Granitic Fragment Feldspathic Siltstone/Mudstone Feldspathic Sandstone Fragment Basic Volcanic Fragment Carbonate Allochems (not bioclasts) Dolomite Rock Fragments Organic Fragment Clay/Mud Clasts Shale/Mudstone Fragments Indeterminate Argil.Frag./Ductile Clay Peloid Argillite Fragment Phyllite Fragment Muscovite Chlorite Indeterminate/Altered Mica Metasiltstone/Metamudstone Unknown Rigid Framework Grain REPLACEMENT COMPONENTS Macropore in Plagioclase PORES Intergranular Pore (2-20um) Intergranular Pore (>20um) PORE-FILLING COMPONENTS Siderite Quartz Overgrowths Inherited Clay Rims Plagioclase Ovegrowths Clay and Mud Matrix Sideritic Matrix LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills SUMMARY CALCULATIONS DESCRIPTIONS cemented by plastic deform fraction only. Poroperm COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED. COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (% total cnts) (% fraction) (X total cnts) (% fraction) 57 19.0 22.3 19.0 22.2 16 5.3 6.3 5.3 6.2 3 1.0 1.2 1.0 1.2 10 3.3 3.9 3.3 3.9 25 8.3 9.$ 8.3 9.7 3 1.0 1.2 1.0 1.2 10 3.3 3.9 3.3 3.9 1 0.3 0.4 0.3 0.4 1 0.3 0.4 0.3 0.4 21 7.0 8.2 7.3 8.6 4 1.3 1.6 1.3 1.6 1 0.3 0.4 0.3 0.4 2 0.7 0.8 0.7 0.8 1 0.3 0.4 0.3 0.4 2 0.7 0.8 0.7 0.8 12 4.0 4.7 4.0 4.7 6 2.0 2.3 2.0 2.3 9 3.0 3.5 3.0 3.5 17 5.7 6.6 5.7 6.6 4 1.3 1.6 1.3 1.6 1 0.'3 0.4 0.3 0.4 4 1.3 1.6 1.3 1.6 17 5.7 6.6 5.7 6.6 2 0.7 0.8 0.7 0.8 1 0.3 0.4 0.3 0.4 2 0.7 0.8 0'.7 0.8 14 4.7 5.5 4.7 5.4 10 3.3 3.9 3.3 3.9 1 0.3 100.0 0.0 0.0 4 1.3 66.7 1.3 66.7 2 0.7 33.3 0.7 33.3 9 3.0 27.3 3.0 27.3 3 1.0 9.1 1.0 9.1 1 0.3 3.0 0.3 3.0 2 0.7 6.1 0.7 6.1 16 5.3 48.5 5.3 48.5 2 0.7 6.1 0.7 6.1 4 1.3 100.0 1.3 100.0 Q Quartzose Components (X Framwrk)(Non-Folk) F FeldspathicComponents (XFrmwrk)(Non-folk) L Lithic Components (% Framework)(Non-Folk) Qt-Quartzose Comp.(pseudo-Dickin.)(%Tot.QtFL) F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QtFL) L-Lithic Comp. (pseudo-Dickinson)(%Tot.QtFL) Qm-Monoxln.Quartz(pseudo-Dickin.)(%Tot.QmFLt) F-Feldspath.Comp.(pseudo-Dickin.)(%Tot.QmFLt) Lt-Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) Total Quartz (%Framework Fraction) Total Chert (% Framework Fraction) Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) Tot.Mica.Qtzite& Qtzose Microsch.(%Fmwk Frac) Total Plagioclase (%Framework Fraction) Tot. Potassium Feld. (% Framework Fraction) COUNTS PRESENT RECONSTRUCTED (#) COMPOSITION COMPOSITION 126.00 51.22 51.01 28.00 11.38 11.74 92.00 37.40 37.25 126.70 61.21 60.91 24.80 11.98 12.40 55.50 26.81 26.68 69.70 33.67 33.51 24.80 11.98 12.40 112.50 54.35 54.09 86.00 33.59 33.46 28.00 10.94 10.89 l.oo o.oo o:oo 11.00 4.30 4.28 21.00 8.20 8.56 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Nell/Outcrop I.D.: Pioneer Cronus #1, Sec 8. T8N, R6E Age/Strat. Unit Designation: Torok Sand 4 Depth/Sample I.D.: 7296 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 4.00 1.56 1.56 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 3.00 1.17 1.17 Total Silic.Volcanics (X Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 1.00 0:39 0.39 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 35.00 13.67 13.62 Tot. Carbonate Fragments (X Framework Frac ) 14.00 5.47 5.45 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 31.00 12.11 12.06 Total Micas & Chlorite (% Framework Fraction) 5.00 1.95 1.95 Total Organic Fragments (XFramework Fraction) 6.00 2.34 2.33 Total Rigid Framework Grains (X Frmwrk Frac.) 179.00 69.92 70.04 Tot.Ductile Framework Grains (X Frmwrk Frac ) 77.00 30.08 29.96 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 296.00 296.00 296.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 9.00 3.04 3.04 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) -0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 15.00 5.07 5.07 Total Detrital Matrix (X Adj.Tot.Cts.) 22.00 7.43 7.43 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame,Fract.) 1.00 0.39 0.00 Total Intergranular Porosity (%Adj.Tot.Cts.) 6.00 2.03 2.03 Ca1c.Secondary Porosity (X Adj.Tot.Cts.) 1.00 0.34 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 7.00 2.36 2.03 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 1.00 14.29 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 39.00 13.18 13.18 Compaction Loss(% Adj. Tot. Cts) 24.83 .Bulk Volume Corrected Compaction Loss 28.60 Calculated Initial Porosity 38.01 Tot. Framework-Unknowns-Folk (Total Counts) 223.00 223.00 224.00 Q Quartzose Components-Folk (X Framework) 96.00 43.05 42.86 F Feldspathic Components-Folk.(X Framework) 25.00. 11.21 11.61 L Lithic Components-Folk (XFramework) 102.00 45.74 45.54 ******~x**~t**~:tt****~x~***~-x***************** .COMMENTS it~t*:~****:t********,~x~:~****~x*******~*,ttt***~* The thin section was .prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The feldspathic siltstone and sandstone fragments are probably metasiltstone and metasandstone. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. - It tends to occur in small scattered cl usters. The authigenic plagioclase occurs as overgrowths on plagioclase grains. POINT COUNT ANALYSIS Region I.D.: North S1ope:Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6 E Age/Strat. Unit Designation: Torok Sand 5 Depth/Sample I.D.: 7345 Mean size = 0.102mm (3.29 Phi) Sorting = .432 Phi Porosity = 8.7 Permeability (md) _ .004 Total Counts = 300 Lithology: Very fine grained well sorted argill aceous lithic sandstone cemented by plastic deformation and suturing Special Comment: Size and sorting data are measured val ues and apply to framework fraction only.. Poroperm Filename: 7345 .PCT Date: 06-18-2006 Formula F ilename.ext: KUTEII.WK1 COMPONENT COUNTS P RESENT PRESENT RECONSTRUCTED RECONSTRUCTED COM POSITION COMPOSITION COMPOSITION COMPOSITION (#) (% total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 70 23.3 31.3 23.3 31.3 Polycryst. Quartz (2-5 subunits) 6 2.0 2 J 2.0 2.7 Polyxln. Quartz w/ Tr. Aligned Mica 5 1.7 2.2 1.7 2.2 Dense Nondescript Chert 17 5.7 7.6 5.7 7.6 Argillaceous Chert 2 0.7 0.9 0.7 0.9 Micaceous Quartzite(<8Xmicas/chlorite) 11 3:7 4.9 3.7 4.9 Quartzose Mica.Microschist/Metachrt 3 1.0 1.3 1.0 1.3 Stable Heavy Minerals (Zircon etc.) 2 0.7 0.9 0.7 0.9 Plagioclase 29 9.7 12.9 9.7 12.9 Granitic Fragment 3 1.0 1.3 1.0 1.3 Plastically Deformed Basic Volc. 1 0.3 0.4 0.3 0.4 Devitrified Tuff Fragments 1 0.3 0.4 0.3 0.4 Dolomite Rock Fragments 13 4.3 5.8 4.3 5.8 Organic Fragment 9 3.0 4.0 3.0 4.0 Clay/Mud Clasts 8 2.7 3.6 2.7 3.6 Shale/Mudstone Fragments 5 1.7 2.2 1.7 2.2 Oversize Clay/Mud Clasts 1 0.3 0.4 0.3 0.4 Indeterminate Argil.Frag./Ductile 4 1.3 1.8 1.3 1.8 Argillite Fragment 3 1.0 1.3 1.0 1.3 Phyllite Fragment 13 4.3 5.8 4.3 5.8 Muscovite 5 1.7 2.2 1.7 2.2 Biotite 1 0.3 0.4 0.3 0.4 Chlorite 1 0.3 0.4 0.3 0.4 Metasiltstone/Metamudstone 2 0.7 0.9 0.7 0.9 Unknown Rigid Framework Grain 9 3.0 4.0 3.0 4.0 REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) 1 0.3 100.0 0.3 100.0 PORE-FILLING COMPONENTS Siderite 8 2.7 12.3 2.7 12.3 Clay and Mud Matrix 51 17.0 78.5 17.0 78.5 Sideritic Matrix 6 2.0 9.2 2.0 9.2 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 9 3.0 90.0 3.0 90.0 Siderit. Clay/Mud Lam.& Burrow Fill 1 0.3 10.0 0.3 10.0 SUMMARY CALCULATIONS COUNTS. PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (X Framwrk)(Non-Folk) 116.00 53.95 53.95 F FeldspathicComponents (XFrmwrk)(Non-Folk) 32.00 14.88 14.88 L Lithic Components (% Framework)(Non-folk) 67.00 31.16 31.16 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFU 111.90 64.68 64.68 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QtFL) 31.10 17.98 17.98 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFU 28.00 16.18 16.18 Qm-Monoxln.Quartz(pseudo-Dickin.)(%Tot.QmFLt) 81.90 47.34 47.34 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 31..10 17.98 17.98 Lt-Tot.Lithic Comp.(pseudo-Dick.)(%Tot.QmFLt) 58.00 33.53 33.53 Total Quartz (XFramework Fraction). 81.00 36.16 36.16 Total Chert (X Framework Fraction) 19.00 8.48 8.48 Tot. QuartzoseSstone & Sltstone(%Fmwrk Frac) 0.00 0.00 0.00 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 14.00 6.25 6.25 Total Plagioclase (XFramework Fraction) 29.00 12.95 12.95 Tot. Potassium Feld. (X framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 3.00 1.34 1.34 Tot. Feldspath.Sandst.& Sltst.(% Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (% Framework Fraction) 0.00 0.00 0.00 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 1.00 0.45 0.45 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 1.00 0.45 0.45 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 18.00 8.04 8.04 Tot. Carbonate Fragments (X Framework Frac.). 13.00 5.80 5.80 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Torok Sand 5 Depth/Sample I.D.: 7345 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 -0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 Tot. Argil. Sedimentary Frags.(XFrmwrk Frac.) 18.00 8.04 8.04 Total Micas & Chlorite (X Framework Fraction) 7.00 3.13 3.13 Total Organic Fragments (XFramework Fraction) 9.00 4.02 4.02 Total Rigid Framework Grains (X Frmwrk Frac.) 17]..00 76.34 76.34 Tot.Ductile Framework Grains (X Frmwrk Frac.) 53.00 23.66 23.66 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 290.00 290.00 290.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 8.00 2.76 2.76 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(%Adj.Tot.Cts) 0.00 -0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 8.00 2.76 2.76 Total Detrital Matrix (X Adj.Tot.Cts.) 67.00 23.10 23.10 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 1.00 0.34 0.34 Ca1c.Secondary Porosity (X Adj.TOt.Cts.) 0.00 0.00 0.00 Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 1.00 0.34 0.34 Calc.Secondary Porosity (% Tot.Vis. Porosity) 0.00 0.00. 0.00 Total Intergranular Volume (% Adj.Tot. Cts.) 66.00 22.76 22.76 Compaction Loss(X Adj. Tot. Cts) 15.50 Bulk Volume Corrected Compaction Loss 20.07 Calculated Initial Porosity 38.26 Tot. Framework-Unknowns-Folk (Total Counts) 188.00 188.00 188.00 Q Quartzose Components-Folk (X Framework) 92.00 48.94 48.94 F Feldspathic Components-Folk.(X Framework) 32.00 17.02 17.02 L Lithic Components-Folk (XFramework) 64.00 34.04 34.04 ******~x~~x*,t~x*~,t*****~x~xt****~x*****~xtir*,t~,a COMMENTS *~***~x* **~x~~~x*****~xtt*******~-x~x~t~t*~*~** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. The stable heavy minerals are rutiles. The matrix material may contain significant mic roporosity. The siderite is very finely crystalline and is irregularly developed. In tends to occur in small scattered cl usters. bust rims on many quartz grains are very poorly developed or are not present and this makes delineation of ove rgrowths very difficult. The tuff fragment is questionable. The oversize mud clast is highly sideritic. POINT. COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. TBN. R6E Age/Strat. Unit Designation: Torok Sand 5 Depth/Sample I.D.: 7384 Mean size = 0.119mm (3.07 Phi) Sorting = .455 Phi Porosity = 10.3 .Permeability (md) _ .104 Total Counts = 300 Lithology: Very fine-grained well sorted argillaceous lithic sandstone cemented by plastic deformation and suturing Special Comment:. Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7384 .PCT Date: 06-18-2006 Formula Filename.ext: KUTEII.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 75 25.0 30.2 25.0 30.2 Polycryst. Quartz (2-5 subunits) 22 7.3 8.9 7.3 8.9 Polycryst. Quartz (>5 subunits) 1 0.3 0.4 0.3 0.4 Polyxln. Quartz w/ Tr. Aligned Mica 10 3.3 4.0 3.3 4.0 Dense Nondescript Chert 19 6.3 7,7 6.3 7.7 Micaceous Quartzite(<8Xmicas/chlorite) 5 1.7 2.0 1.7 2.0 Quartzose Mica.Microschist/Metachrt 2 0.7 0.8 0.7 0.8 Argil. or Chlor. Quartzose Ss/Sltst 3 1.0 1.2 1.0 1.2 Plagioclase 31 10.3. 12.5 10.3 12.5 Granitic Fragment 4 1.3 1.6 1.3 1.6 Silicic Volcanic Fragment 1 0.3 0.4 0.3 0.4 .Dolomite Rock Fragments 12 4.0 4.8 4.0 4.8 -0rganic Fragment 4 1.3 1.6 1.3 1.6 Clay/Mud Clasts 2 0.7 0.8 0.7 0.8 Shale/Mudstone Fragments 9 3.0 3.6 3.0 3.6 Indeterminate Argil.Frag./Ductile 2 0.7 0.8 0.7 0.8 Argillite Fragment 10 3.3 4.0 3.3 4.0 Phyllite Fragment 15 5.0 6.0 5.0 6.0 Muscovite 3 1.0 1.2 1.0 1.2 Chlorite 2 0.7 0.8 0.7 0:8 Metasiltstone/Metamudstone 7 2.3 2.8 2.3 2.8 Unknown Rigid Framework Grain 9 3.0 3.6 3.0 3.6 REPLACEMENT COMPONENTS PORES Intergranular Pore (2-20um) 1 0.3 100.0 0.3 100.0 PORE•FILLING COMPONENTS Siderite 4 1.3 8.3 1.3 8.3 Ankerite 7 2.3 14.6 2.3 14.6 Quartz Overgrowths 7 2.3 14.6 2.3 14.6 Plagioclase Ovegrowths 1 0.3 2.1 0.3 2.1 Clay and Mud Matrix 29 9.7 60.4 9.7 60.4 LAMINA/BURROW FILLS & FRACTURE FILLS Clay/Mud Laminae and Burrow Fills 3 1.0 100.0 1.0 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Q Quartzose Components (X Framwrk)(Non-Folk) 137.00 57.32 57.32 F FeldspathicComponents (XFrmwrk)(Non-Folk) 35.00 14.64 14.64 L Lithic Components (X Framework)(Non-Folk) 67.00 28.03 28.03 Qt-Quartzose Comp.(pseudo-Dickin.)(XTot.QtFL) 134.70 62.94 62.94 F-Feldspath.Comp.(pseudo-Dickin.)(XTot_QtFL) 33.80 15.79 15.79 L-Lithic Comp. (pseudo-Dickinson)(XTot.QtFU 45.50 21.26 21.26 Qm-Monoxin.Quartz(pseudo-Dickin.)(XTot.QmFLt) 82.70 38.64 38.64 F-Feldspath.Comp.(pseudo-Dickin.)(XTot.QmFLt) 33.80 15.79 15.79 Lt•Tot.Lithic Comp.(pseudo-Dick.)(XTot.QmFLt) 97.50 45.56 45.56. Total Quartz (XFramework Fraction) 108.00 43.55 43.55 Total Chert 1X Framework Fraction) 19.00 7.66 7.66 Tot. QuartzoseSstone & Sltstone(XFmwrk Frac) 3.00 0.01 0.01 Tot.Mica.Qtzite& Qtzose Microsch.(XFmwk Frac) 7.00 2.82 2:82 .Total Plagioclase (XFramework Fraction) 31.00 12.50 12.50 Tot. Potassium Feld. (X Framework Fraction) 0.00 0.00 0.00 Tot. Granitic &Gneissic Frags.(X Frmwrk Frac) 4.00 1.61 1.61 Tot. Feldspath.Sandst.& Sltst.(X Frmwrk Frac) 0.00 0.00 0.00 Total Silic.Volcanics (X Framework Fraction) 1.00- 0.40 0.40 Tot.Basic & Intmed.Volcanics (X Frmwrk Frac.) 0.00 0.00 0.00 Total Volc. Glass & Tuff Frags(X Frmwrk Frac) 0.00 0.00 0.00 Tot. Ductile Metamorph.Frags.(X Frmwrk Frac.) 32.00 12.90 12.90 Tot. Carbonate Fragments (X Framework Frac.) 12.00 4.84 4.84 Tot.Unstable Heavy Min. & Gabbro(XFrmwk Frac) 0.00 0.00 0.00 Tot. Lithic Sandst.& Sltst (XFrmwrk Frac.) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N. R6E Age/Strat. Unit Designation: Torok Sand 5 Depth/Sample I.D.: 7384 SUMMARY CALCULATIONS. COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot. Argil.-Sedimentary Frags.(XFrmwrk Frac.) 13.00 _5.24 5.24 Total Micas & Chlorite (X Framework Fraction) 5.00 2.02 2.02 Total Organic Fragments (XFramework Fraction) 4.00 1.61 1.61 Total Rigid Framework Grains (X Frmwrk Frac.) 194.00 78.23 78.23 Tot.Ductile Framework Grains (X Frmwrk Frac.) 54.00 21.77 21.77 Tot. Cts (adjusted to excl.Artific.Por.& Lam) 297.00 297.00 297.00 Tot. Intergrn.Carbonate Cement(X Adj.Tot.Cts) 11.00 3.70 3.70 Tot. Intergran.Zeolite Cement (X Adj.Tot.Cts) 0.00 0.00 0.00 Tot. Intergran.Auth.Clay Cement(XAdj.Tot.Cts) 0.00 0.00 0.00 Total Intergranular Cements (XAdj.Tot.Cts) 19.00 6.40 6.40 Total Detrital Matrix (X Adj.Tot.Cts.) 32.00 10.77 10.77 Tot. Ca1c.Dissolved Frmwrk(XTot.Frame.Fract.) 0.00 0.00 0.00 Total Intergranular Porosity (XAdj.Tot.Cts.) 1.00 0.34 0.34 Calc.Secondary Porosity (X Adj.Tot.Cts.) 0.00 0.00 0.00. Tot. Calc. Visible Porosity (XAdj. Tot. Cts.) 1.00 0.34 0.34 Ca1c.Secondary Porosity (X Tot.Vis. Porosity) 0.00 0.00 0.00 Total Intergranular Volume (X Adj.Tot. Cts.) 49.00 16.50 16.50 Compaction Loss(X Adj. Tot. Cts) 21.63 Bulk Volume Corrected Compaction Loss 25.91 Calculated Initial Porosity 38.13 Tot. Framework-Unknowns-Folk (Total Counts) 228.00 228.00 228.00 Q Quartzose Components•Folk (X Framework) 113.00 49.56 49.56 F Feldspathic Components-Folk.(X Framework) 35.00 15.35 15.35 L Lithic Components-Folk (XFramework} 80.00 35.09 35.09 *********~*****~x**,~-x****,r****************~***** COMMENTS ~******~***,~**~*****~~*,r***~x*******+~x** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. It is very difficult to differentiate deformed argillaceous fragments from matrix material. Some ankerite occurs as overgrowths on detrital dolomite. The matrix material may contain significant microporosity. The siderite is very finely crystalline and is irregularly developed. It tends to occur in small scattered cl usters. Dust rims on many quartz grains are very poorly developed or are not. present and this makes delineation of ove rgrowths very difficult. The authigenic plagioclase occurs as overgrowths on a plagioclase grain. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.O.: Pioneer Cronus #1, Sec 8, TBN, R6E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7755 Mean size = 0.306mm (1.71 Phi) Sorting = .644 Phi Porosity = 17.6 Permeability (md) = 3.23 Total Counts = 300 Lithology: Medium-grained well sorted glauconitic quartzose sandstone cemented by siderite and grading to sandy .ironstone Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7755 .PCT Date: 06-18-2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COM POSITION COMPOSITION COMPOSITION COMPOSITION (#) (X t otal cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 27 9.0 40.9 9.0 38.6 Stable Heavy Minerals(Zir/Tour/Rut/Gar) 1 0.3 1.5 0.3 1.4 Nondescript Polycryst.Qtz (2-5 subunits) 6 2.0 9.1 2.0 8.6 Glauconite 13 4.3 19.7 4.3 18.6 Clay/Mud Peloid (non•glauconitic) 16 5.3 24.2 6.3 27.1 Nudstone/Shale Fragment 3 1.0 4.5 1.0 4.3 Unknown Framework Grain A 0.0 0.-0 0.3 1.4 PORES Rim Moldic and Shrinkage Pores 4 1.3 80.0 1.3 80.0 Fracture Pore (natural) 1 0.3 20.0 0:3 20.0 PORE-.FILLERS Very Sideritic Matrix (33-66X of matrix) 12 4.0 80.0 4.0 80.0 Rhomb siderite (finely xline <.06mm) 1 0.3 6.7 0.3 6.7 Detrital Glauconite or Other Clay Rim 1 0.3 6.7 0.3 6.7 Quartz Overgrowth 1 0.3 6.7 0.3 6.7 REPLACEMENT COMPONENTS Ferroan Calcite Replacing Unknown 1 0.3 25.0 0.0 0.0 Non-glauconitic Peloid replaced by Kaol. 2 0.7 50.0 0.0 0.0 Mud/clay Peloid/Glau. repl. by siderite. 1 0.3 25.0 0.0 0.0 FRACTURES/SHALE LAMINAE/BURROWS Kaolinite Fracture Fil l 6 2.0 2.9 2.0 2.9 Sideritic Clay/Mud Lamina or Burrow Fi11 1 0.3 0.5 0.3 0.5 Very Sideritic Clay/Mud Lamina or Burrow 2 03 67.7 96.7 67.7 96.7 OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Total Framework Grains (X Total Rock) 66.00 22.00 23.33 Total Framework - Unknowns (XTotal Rock) 66.00 22.00 23.00 Q - quartzose Components (XFrmwork - Unknown) 34.00 51.52 49.28 F - Feldspathic.Components (XFrmwrk - Unknwn) 0.00 0.00 0.00 L - Lithic Components (% Framework - Unknwn) 32.00 48.48 50.72 Total Framework-Unkn.(Dickinson-TotQtFL Cts) 33.00 11.00 11.00 Qt quartzose Comp. (Dickinson}(XTotal QtFL) 33.00 100.00 100.00 F - Feldspathic.Comp.(DickinsonY(XTotal QtFL) 0.00 0.00 0.00 L - Lithic Compon. (Dickinson)(XTotal QtFU 0.00 0.00 0.00 Tot. Framework-Unkn.(Dickinson-TotQmFLt Cts) 33.00 11.00 11.00 Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) 27.00 81.82 81.82 F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) 0.00 0.00 0.00 Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) 6.00 18.18 18.18 Total Quartz (X framework) 33.00 50.00 47.14 Total Monocrystalline quartz (X Framework) 27.00 40.91 38.57 Total Polycrystalline quartz (X Framework) 6.00 9.09 8.57 Total Chert (X Framework) 0.00 0.00 0.00 Total Sandstone/Siltstone/Qtzite (X Frmwrk) 0.00 0.00 0.00 C/Q Ratio 6.00 0.18 0.18 Total Feldspar (X Framework) 0.00 0.00 0.00 Total Plagioclase (X Framework 0.00 0.00 0.00 Total Potassium.Feldspar (X Framework) 0.00 0.00 0.00 P/F Ratio 0.00 0.00 0.00 Total Ductile (X Framework) 32.00 48.48 50.00 Total Clay Peloids (X Framework) 29.00 43.94. 45.71 Total Nonoxidized Glauconite (X Framework) 13.00 19.70 18.57 Total Oxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 13.00 19.70 18.57 Total Nonglauconitic peloids (X Framework) 16.00 24.24 27.14 Total Phyllite (X Framework) 0.00 0.00 0.00 Total Organic Fragments (X Framework) 0.00 0.00 0.00 Total Muscovite and Chlorite (X Framework) 0.00 0.00 0.00 Total Chamosite&Iron-rich ooids (XFramework) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Siope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. T8N. R6E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7755 SUMMARY CALCULATIONS COUNTS PRESENT .RECONSTRUCTED. DESCRIPTIONS (#) COMPOSITION COMPOSITION Total DetritalCarbonate Frags. (X Framework) 0.00 0.00 0.00 Total Fossil Fragments (X Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(% Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X Framework) 0.00 0.00 0.00 Total Siderite Fragments (X Framework) 0.00 0.00 0.00 Total Siliceous Fossil Fragments(X Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 216.00 72.00 72.00 Total Clay Laminae & Burrows (X Total Rk.) 204.00 68.00 68.00 Total Dispersed Matrix (XTotal Rock) 12.00 4.00. 4.00 Total Carbonate Cements (X Total Rock) 1.00 0.33 0.33 Total Siderite Cements (X Total Rock) 1.00 0.33 0.33 .Total AnkeriteCement (X Total Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 0.00 0.00 0.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (X Tot. Rock) 1.00. 0.33 0.33 Total Oil Stain (X Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock). 1.00 0.33 0.33 Total Chert 8 Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 0.00 0.00 0.00 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 14.00 4.67 4.67 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 1.00 7.14 7.14 M - Matrix (X Carb.Cem+Mtx+Other Cements) 12.00 85.71 85.71 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 1.00 7.14 7.14 Total Counts (Tot.counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 6.00 2.00 2.00 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total. Rock) 5.00 1.67 1.67 Tot. Calc. Intergran. Porosity(X Total Rock) 3.60 1.20 1.20 Tot. Calc. Intragran. Porosity(X Total Rock) 14.40 4.80 4.83 Tot.. Shrinkage Porosity (X Total Rock) 4.00 1.33 1.33 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 61.50 20.50 20.53 Total Calculated Microporosity(X Total Rock) 53.30 17.77 18.07 Calculated Secondary Porosity (X Total Rock) 4.80 1.60 1.33 Tot.Intergranular Cements incl.Clays(XTot.Rk) 2.00 0.67 0.67 Total Solid Components (Total Counts) 238.50 0.00 0.00 Calculated Grain-Density 691.90 2.90 2.90 Tot. Framework+Intergranular Compon.(Tot.Cts) 90.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 16.00 17.78 17.78 Compaction Loss(X Framework+Intergran. Comp.) 19.30 Bulk Volume Corrected Compaction Loss 23.47 Calculated Initial Porosity 37.08 ***********~x*:t*~t*~x**,t*****~t~t*~rx**,t*,tit*,t***,t COMMENTS ~,tr~**~,t****~-x~x*****~**~x*,t:t**:t*~r*~x,~~,t****** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. The unknown framework grain replaced by ferroan calcite may be glauconite pellet. The sideritic matrix probably contains significant hidden microporosity. It is very difficult to assess the amount of clay in the sideritic matrix. The siderite tends to mask much of the clay present. Most clastic grains seem to float in highly sideritic matrix. The glauconite pellets tend to be a pale green color and some have patches of non-glauconitic clay. Shrinkage pores tend to occur along the borders of clay pellets but some occur internally in mud fragments.. Ferroan calcite and/or kaolinite partially replace a few clay pellets. The natural fracture pore may actually be a fracture infilled by kaolinite in which the kaolinite has been was hed or plucked out artificially. The kaolinite-filled fracture is up to 0.75mm wide and locally forms two branches. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, TBN, R6E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7756 Mean size = 0.240mm (2.06 Phi) Sorting = .6 Phi Porosity = 20.3 Permeability (md) _ .355 Total Counts = .300 Lithology: Fine-grained well sorted glauconitic quartzose sandstone cemented by siderite grading to sandy ironstone Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7756 .PCT Date: 06-18.2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Polycrystalline Qtz(cherty polygonal) Nondescript Polycryst.Qtz (>5 subunits) Dense Chert Quartzose Sandstone Rock Fragment Nondescript Polycryst.Qtz (2-5 subunits) Phyllite Glauconite Clay/Mud Peloid (non-glauconitic) Mudstone/Shale Fragment PORES Intergranular Pores Rim Moldic and Shrinkage Pores PORE-FILLERS Very Sideritic Matrix (33-66% of matrix) Ankerite Quartz Overgrowth REPLACEMENT COMPONENTS FRACTURES/SHALE LAMINAE/BURROWS Very Sideritic Clay/Mud Lamina or Burrow OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) Mudstone Fragment COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED- . COMPOSITION- COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cots) (X fraction) 65 21.7 57.0 -21.7 57.0 1 0.3 0.9 0.3 0.9 3 1.0 2.6 1.0 2.6 5 1.7 4.4 1.7 4.4 2 0.7 1.8 0.7 1.8 3 1.0 2.6 1.0 2.6 1 0.3 0.9 0.3 0.9 29 9.7 25.4 9.7 25.4 2 0.7 1.8 0.7 1.8 3 1.0 2.6 1.0 2.6 7 2.3 50.0 2.3 50.0 7 2.3 50.0 2.3 50.0 30 10.0 93.8 `10.0 - 93.8 1 0.3 3.1 0.3 3.1 1 0.3 3.1 0.3 3.3 137 3 45.7 1.0 100.0 45.7 100.0 1.0 100.0 100.0 SUMMARY CALCULATIONS DESCRIPTIONS Total Framework Grains (X Total Rock) Total Framework - Unknowns (XTotal Rock) Q - Quartzose Components (%Frmwork - Unknown) F - Feldspathic.Components (XFrmwrk - Unknwn) L - Lithic Components (X Framework - Unknwn) Total Framework-Unkn.(Dickinson-TotQtFL Cts) Qt - Quartzose Comp. (Dickinson)(XTotal QtFL) F -feldspathic.Comp.(Dickinson)(XTotal QtFL) L - Lithic Compon. (Dickinson)(XTotal QtFL) Tot. Framework-Unkn.(Dickinson-TotQmFLt Cts) Qm - Monocryst.Qtz. (Dickinson)(%Total QmFLt) F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) Total Quartz (X Framework) Total Monocrystalline quartz (% Framework) Total Polycrystalline quartz (X Framework) Total Chert (X Framework) Total SandstonelSiltstone/Qtzite (X Frmwrk) C/Q Ratio Total Feldspar (X Framework) Total Plagioclase (X Framework Total Potassium.Feldspar (X Framework) P/F Ratio Total Ductile (% Framework) Total Clay Peloids (X Framework) Total Nonoxidized Glauconite (X Framework) Total Oxidized Glauconite (X framework) Total Glauconite (incl. oxidized)(XFramework) Total Nonglauconitic peloids (% Framework) Total Phyllite (X Framework) Total Organic Fragments (X Framework) Total Muscovite and Chlorite (X Framework) Total Chamosite&Iron-rich ooids (XFramework) Total DetritalCarbonate Frags. (X Framework) Total Fossil Fragments (% Framework) COUNTS PRESENT (#) COMPOSITION 114.00 -38.00 117.00 39.00 79.00 67.52 0.00 0.00 38.00 32.48 80.00 26.67 79.00 98.75 0.00 0.00 1.00 1.25 80.00. 26.67 67.00 83:75 0.00 0.00 13.00 16.25 72.00 63.16• 65.00 57.02 7.00 6.14 5.00 4.39 2.00 1.75 12.00 0.15 0.00 0.00 o.oo o.oo 0,00 0.00 0.00 0.00 35.00 30.70 31.00 27.19 29.00 .25.44 0.00 0.00 29.00 25.44 2.00 1.75 1.00 0.88 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 RECONSTRUCTED COMPOSITION 38.00 39.00 67.52 0.00 32.48 26.67 98.75 0.00 1.25 26.67 83.75 0.00 16.25 63.16 57.02 6.14 4.39 1.75 0.15 0.00 0.00 o.oo 0.00 30.70 27.19 25.44 0.00 25.44 1.75 0.88. 0.00 0.00 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. TBN. R6E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7756 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Calcite and Limest. Frags.(X Framework) 0.00 0..00 0.00 Total Dolomite Fragments (X Framework) 0.00 0.00 0.00 Total Siderite Fragments (X Framework) 0.00 0.00 0.00 Total Siliceous Fossil Fragments(X Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X .Total Rk) 167.00 55.67 55.67 Total Clay Laminae & Burrows (X Total Rk.) 137.00 45.67 45.67 Total Dispersed Matrix (XTotal Rock) 30.00 10.00 10.00 Total Carbonate Cements (X Total Rock) 1.00 0.33 0.33 Total Siderite Cements (X Total Rock) 0.00 0.00 0.00 Total AnkeriteCement (X Total Rock) 1.00 0.33 0.33 Total Kaolinite (% Tot.Rock) 0.00 0.00 0.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (% Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (X Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 1.00 0.33 0.33 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 0.00 0.00 0.00 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 32.00 10.67 10.67 C - Carbonate Cem. (X Carb.Cem+Mtx.+Other Cem) 1.00 3.13 3.13 M - Matrix (X Carb.Cem+Mtx+Other Cements) 30.00 93.75 93.75 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 1.00 3.13 3.13 Total Counts (Tot counts artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 0.00 0.00 0.00 Total Oversize Grains (X Tot. Counts) 3.00 1.00 1.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 14.00 4.67 4:67 Tot. Calc. Intergran. Porosity(X Total Rock) 13.00 4.33 4.33 Tot. Calc. Intragran. Porosity(X Total Rock) 17.20 5.73 5.73 Tot. Shrinkage Porosity. (X Total Rock) 7.00 2.33 2.33 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 58.50 19.50 19.50 Total Calculated Microporosity(X Total Rock) 44.50 14.83 14.83 Calculated. Secondary Porosity (X Total Rock) 7.00 2.33 2.33 Tot.Intergranular Cements incl.Clays(XTot.Rk) 2.00 0.67 0.67 Total Solid Components (Total Counts) 241.50. 0.00 0.00 Calculated Grain-Density 679.52 2.81 2.81 Tot. Framework+Intergranular Compon.(Tot.Cts) 160.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 39.00 24.38 24:38 Compaction Loss(X Framework+Intergran. Comp.) 12.93 Bulk Volume Corrected Compaction Loss 17.10 C 1 1 t d I` 1 P a cu a e m tia orosity 37.31 ~x~-a***~x~,~x*,t***,f,E***~xt~x~x****,txx*****~~~~,t COMMENTS ***~x**,~**,tt***+k*,t:t~*,t****~x~r***~~**,rt~** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. The quartzose sandstone fragments are very fine-grained and well sorted and contain very minor muscovite and p lagioclase. They. are cemented by quartz overgrowths and suturing and contain minor visible porosity.. The sideritic matrix probably contains significant hidden microporosity. It is very difficult to assess the amount of clay in the sideritic matrix. The Siderite tends to mask much of the clay present. Most clastic grains seem to float in highly sideritic matrix. The glauconite pellets tend to be a-pale green color and some have patches of non-glauconitic clay. Shrinkage pores tend to occur along the borders of clay pellets but some occur internally in mud fragments. Ferroan calcite and/or kaolinite partially replace a few clay pellets. A few thin discontinuous open fractures cut across portions of the sideritic matrix. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, T8N, R6 E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7757 Mean size = 0.276mm (1.86 Phi) Sorting = .572 Ph i Porosity = 19.I Permeability (md) _ .323 Tot al Coun ts = 300 Lithology: Medium-grained well sorted glauconit ic quartzose sandstone cemented b y siderite grading to sand y ironstone Special Comment: Size and sorting data are measu red val ues and apply to framework fraction only. Poroperm Filename: 7757 .PCT Date: 06-18-2006 Fo rmula F ilename.ext: LCRETFRM.WK1 COMPONENT COUNTS. PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (% fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 44 14.7 43.6 -14.7 41.9 Dense Chert 2 0.7 2.0 0.7 1.9 Stable Heavy Minerals(Zir/Tour/Rut/Gar) 1 0.3 1'.0 0.3 1.0 Nondescript Polycryst.Qtz (2-5 subunits) 5 1.7 5.0 1.7 4:8 Glauconite 23 7.7 22.8 7.7 21.9 Clay/Mud Peloid (non-glauconitic) 16 5.3 15:8 6.3 18.1 Mudstone/Shale Fragment 9 3.0 8.9 3.0 8.6 Unknown Framework Grain 1 0.3 1.0 0.7 1.9 PORES Rim Moldic and Shrinkage Pores 9 3.0 100.0 3.0 100.0 PORE-FILLERS Very Sideritic Matrix (33-66X of matrix) 16 5.3 66.7 5.3 66.7 Rhomb siderite (finely xline <.06mm) 7 2.3 29.2 2.3 29.2 Ferroan Calcite 1 0.3 4:2 0.3 4.2 REPLACEMENT COMPONENTS Unknown Framework Grain replaced by Kaoli 1 0.3 25.0 0.0 0.0 Non•glauconitic Peloid replaced by Kaol. 2 0.7 50.0 0.0 0.0 Mud/clay Peloid/Glau. repl. by siderite 1 0.3 25.0 D.0 0.0 FRACTURES/SHALE LAMINAE/BURROWS Ankerite Fracture Fill 1 0.3 0.6 0.3 0.6 Sideritic Clay/Mud Lamina or Burrow Fill 9 3.0 5.6 3.0 5.6 Very Sideritic Clay/Mud Lamina or Burrow 1 52 50.7 93.8 50.7" 93.8 OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Framework Grains (X Total Rock) 101.00 33.67 35.00 Total Framework - Unknowns (%Total Rock) 100.00 33.33 34.33 Q - Quartzose Components (XFrmwork - Unknown) 52.00 52.00 50.49 F - Feldspathic.Components {XFrmwrk - Unknwn) 0.00 0.00 0.00 L - Lithic Components (% Framework - Unknwn) 48.00 48.00 49.51 Total Framework-Unkn.(Dickinson-TotQtFL Cts) 51.00 17.00 17.00 Qt - Quartzose Comp. (Dickinson)(XTotal QtFL) 51.00 100.00 100.00 F - Feldspathic.Comp.(Dickinson)(%Total QtFL) 0.00 0.00 0.00 L - Lithic Compon. (Dickinson)(%Total QtFU 0.00. 0.00 0.00 Tot. Framework-Unkn.(Dickinson•TotQmFLt Cts) 51.00 17.00 17.00 Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) 44.00 86.27 86.27 F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) 0.00 0.00 0.00 Lt - Lithic Comp. (Dickinson) (%Total QmFLt) 7.00 13.73 13.73 Total Quartz (X Framework) 49.00 48.51 46.67 Total Monocrystalline quartz (X Framework) 44.00 43.56 41.90 Total Polycrystalline quartz (X Framework) 5.00 4.95 4.76 Total Chert (X Framework) 2.00 1.98 1.90 Total Sandstone/5iltstone/Qtzite (% Frmwrk) 0.00 . 0.00 0.00 C/Q Ratio 7.00 0.13 0.13 Total Feldspar (X Framework) 0.00 0.00 0.00 Total Plagioclase (% Framework 0.00 0.00 0.00 Total Potassium.Feldspar (% Framework) 0.00 0.00 0.00 P/F Ratio 0.00 0.00 0.00 Total Ductile (% Framework) 48.00 47.52 48.57 Total Clay Peloids (X Framework) 39.00 .38.61 40.00 Total Nonoxidized Glauconite (X Framework) 23.00 22.72 21.90 Total Oxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 23.00 22.77 21.90 Total Nonglauconitic peloids (% Framework) 16.00 15.84 18.10 Total Phyllite (X Framework) 0.00 0.00 0.00 Total Organic Fragments (X Framework) 0.00 0.00 0.00 Total Muscovite and Chlorite (X Framework) 0.00 0.00 0.00 Total Chamosite&Iron-rich ooids (%Framework) 0.00 0.00 0.00 Total DetritalCarbonate Frogs. (% Framework) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, TSN, R6E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7757 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION- COMPOSITION Total Fossil Fragments (X Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(X Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X Framework) 0.00 0.00 0.00 Total Siderite Fragments (% Framework) 0.00 0.00 0.00 Total . Siliceous Fossil Fragments(% Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.D isprs.Mtx+Clay Lam.&Burrows (% Total Rk) 177.00 59.00- 59.00 Total Clay Laminae & Burrows (X Total Rk.) 161.00 53.67 53.67 Total Dispersed Matrix (XTotal Rock) 16.00 5.33 5.33 Total Carbonate Cements (X Total Rock) 8.00 2.67 2.67 Total Siderite Cements (X Total Rock) 7.00 2.33 2.33 Total AnkeriteCement (X Total Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 1.00 0.33 0.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 1.00 0.33 0.00 Total Detrital Clay Rims (X Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (% Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 0.00 0.00 0.00 Total Chert & Microxl. Quartz (% Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 0.00 0.00 0.00 Total Other Cements (% Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 24.00 8.00 8.00 C - C arbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 8.00 33.33 33.33 M - M atrix (X Carb.Cem+Mtx+Other Cements) 16.00 66.67 66.67 0 - Other Cem.(% Carb.Cem.+Mtx.+Other Cem.) 0.00 0.00 0.00 Total Counts (Tot.. counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 1.00 0.33 0.33 Total Oversize Grains (% Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 9.00 3.00 3.00 Tot. Calc. Intergran. Porosity(% Total Rock) 3.20 1.07 .1.07 Tot. Ca1c. Intragran. Porosity(X Total Rock) 24.60 8.20 8.10 Tot. Shrinkage Porosity (X Total Rock) 9.00 3.00 3.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 62.70 20.90 20.80 Total Calculated Microporosity(X Total Rock) 52.90 17.63 17.80 Calcu lated Secondary Porosity (% Total Rock) 10.20 3.40 3.00 Tot.I ntergranular Cements incl.Clays(XTot.Rk) 8.00 2.67 2.67 Total Solid Components (Total Counts) 237.30 0.00 0.00 Calcu lated Grain Density 682.29 2.88 2.87 Tot. Framework+Intergranular Compon.(Tot.Cts) 138.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 24.00 17.39 17.39 Compa ction Loss(% Framework+Intergran. Comp.) 20.11 Bulk Volume Corrected Compaction Loss 24.35 Calcu lated Initial Porosity 37.50 ********,r,~r*****~**,t******~r~x****~**~******** COMMENTS ~*~t*~~x********,r~****:~:t-,E**~,tt***,E,t***,t**~r The thin section was prepared from a l inch diameter. rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. The stable heavy mineral is a zircon. The count recorded as an ankerite fracture fill is probably a ferroan calcite fracture fill. It is very difficult to assess the amount of clay in the sideritic matrix. The Siderite tends to mask much of the clay present. Most clastic grains seem to float in highly sideritic matrix. The glauconite pellets tend to be a pale green color and some have patches of non-glauconitic clay. Shrinkage pores tend to occur along the borders of clay pellets but some occur internally in mud fragments. The sideritic matrix probably contains significant hidden micorporosity. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. T8N. R6E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7758 Mean size = 0.216mm f2.21 Phi) Sorting = .495 Phi Porosity = 13.6 Permeability (md) _ .104 Total Counts = 300 Lithology: Fine-grained well sorted slightly argillaceous glauconitic quartzose sandstone cemented by quay tz overgrowths and ferroan calcite and plastic deformation Special Comment: Size and sorting data are measured values and apply to framework fraction only. Poroperm Filename: 7758 .PCT Date: 06.18-2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cuts) (X fraction) (X total cuts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 183 61.0 75.3 61.0 74.7 Nondescript Polycryst.Qtz (>5 subunits) 3 1.0 1.2 1.0 1.2 Dense Chert 7 2.3 2.9 2.3 2.9 Quartzose Sandstone Rock Fragment 2 0.7 0.8 0.7 0.8 Stable Heavy Minerals(Zir/Tour/Rut/Gar) 1 0.3 0.4 0.3 0.4 Nondescript Polycryst.Qtz (2-5 subunits) 9 3,0 3.7 3.0 3.7 Plagioclase 1 0.3 0.4 0.3 0.4 Glauconite 32 10.7 .13.2 10.7 13.1 Clay/Mud Peloid (non-glauconitic) 3 1.0 1.2 1.0 1.2 Mudstone/Shale Fragment 1 0.3 0.4 0.3 0.4 Detrital Dolomite Fragment 1 0.3 0.4 0.3 0.4 Unknown Framework Grain 0 0.0 0.0 0.7 0.8 PORES Intergranular Pores 4 1.3 80.0 1.3 80.0 Rim Moldic and Shrinkage Pores 1 0.3 20.0 0.3 20.0 PORE-FILLERS Clay and Mud Matrix 4 1.3 12.5 1.3 12.5 Ankerite 1 0.3 3.1 0.3 3.1 Detrital Glauconite or Other. Clay Rim 1 0.3 3.1 0.3 3.1 Quartz Overgrowth 9 3.0 28.1 3.0 28.1 Ferroan Calcite 17 5.7 53.1 5.7 53.1 REPLACEMENT COMPONENTS Ferroan Calcite Replacing Unknown 2 0.7 100.0 0.0 0.0 .FRACTURES/SHALE LAMINAE/BURROWS Clay Laminae and Burrows 7 2.3 38.9 2.3 38.9 Sideritic Clay/Mud Lamina or Burrow Fill 7 2.3 38.9 2.3 38.9 Very Sideritic Clay/Mud Lamina or Burrow 4 1.3 22.2 1.3 22.2 OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS- COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITI ON Total Framework Grains (X Total Rock) 243.00 81.00 81.67 Total Framework - Unknowns (XTotal Rock) 243.00 81.00 81.00 Q - Quartzose Components (XFrmwork - Unknown) 205.00 84.36 84.36 F - Feldspathic.Components (XFrmwrk - Unknwn) 1.00 0.41 0.41 L - Lithic Components {X Framework - Unknwn) 37.00 15.23 15.23 Total Framework-Unkn.(Dickinson-TotQtFL Cts) 205.00 68.33 68.33 Qt - Quartzose Comp. (Dickinson)(XTotal QtFL) 204.00 99.51 99.51 F - Feldspathic.Comp.(Dickinson)(XTotal QtFL) 1.00 0.49 0.49 L - Lithic Compon. (Dickinson)(XTotal QtFL) 0.00 0.00 0.00 Tot. Framework-Unkn.(Dickinson-TotQmFLt Cts) 205.00 68.33 68.33 Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) 185.00 90.24 90.24 F-- Feldspath. Comp.(Dickinson)(XTotal QmFLt) 1.00 0.49 0.49 Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) 19.00 9.27 9.27 Total Quartz (X Framework) 195.00 80.25 79.59 Total Monocrystalline quartz (X Framework) 183.00 75.31 74.69 Total Polycrystalline quartz (X .Framework) 12.00 4.94 4.90 Total Chert (X Framework) 7.00 2.88 2.86 Total Sandstone/Siltstone/Qtzite (X Frmwrk) 2.00 0.82 0.82 C/Q Ratio 19.00 0.09 0.09 Total Feldspar (X Framework) 1.00 0.41 0.41 Total Plagioclase (X Framework 1.00 0.41 0.41 Total Potassium.Feldspar (X Framework) 0.00 0.00 0.00 P/F Ratio 1.00 1.00 1.00 Total Ductile (X Framework). 36.00 14.81 14.69 Total Clay Peloids (X Framework) 35.00 14.40 14.29 Total Nonoxidized Glauconite (X Framework)- 32.00 13.17 13.06 Total Oxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 32.00 13.17 13.06 Total Nonglauconitic peloids (X Framework) 3.00 1.23 1.22 POINT COUNT. ANALYSIS Region I.D.: .North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8, TBN, R6E Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 7758 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Phyllite (X Framework) 0.00 0.00 0.00 Total Organic Fragments (X Framework) 0.00 0.00 0.00 Total Muscovite and Chlorite (% Framework) 0.00 0.00 0.00 Total Chamosite&Iron•rich ooids (%Framework) 0.00 0.00 0.00 Total DetritalCarbonate Frags. (X Framework) 1.00 0.41 0.41 Total Fossil Fragments (X Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(X Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X Framework) 1.00 0.41 0.41 Total Siderite Fragments (X Framework) 0.00 0.00 -0.00 Total Siliceous Fossil Fragments(% Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 22.00 7.33 7.33 Total Clay Laminae & Burrows (X Total Rk.) 18.00 6.00 6.00. Total Dispersed Matrix (%Total Rock) 4.00 1.33 1.33 Total Carbonate Cements (X Total Rock) 18.00 6.00 6.00 Total Siderite Cements (% Total Rock) 0.00 0.00 0.00 Total AnkeriteCement (X Total Rock) 1.00 0.33 0.33 Total Kaolinite (X Tot.Rock) 0.00 0.00. 0.00 Total Chlorite (% Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (X Tot. Rock) 1.00 0.33 0.33 Total Oil Stain (X Tot. Rock) 0:00 0.00 0.00 Total Quartz Overgrowths (% Tot. Rock) 9:00 3.00 3.00 Total Chert & Microxl. Quartz (X Tot. Rock). 0.00 0.00 0.00 Total Pyrite/Marcasite (% Tot.Rock) 0.00 0.00 0.00 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 31.00 10.33 10.33 C -Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 18.00 58.06 58.06 M - Matrix (X Carb.Cem+Mtx+Other Cements) 4.00 12.90 12.90. 0 - Other Cem.(% Carb.Cem.+Mtx.+Other Cem.) 9.00 29.03 29.03 Total Counts (Tot.counts - artificial. pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 0.00 0.00 0.00 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 5.00 1..67 1.67 Tot. Calc. Intergran. Porosity(X Total Rock) 6.80 2.27 2.27 Tot. Calc. dntragran. Porosity(X Total Rock) 11.80, 3.93 3.93 Tot. Shrinkage Porosity (X Total Rock) 1.00 0.33 0.33 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 27.45 9.15 9.15 Total Calculated Microporosity(X Total Rock) 22.45 7.48 7.48 Calculated Secondary Porosity (X Total Rock) 1.00 0.33 0.33 Tot.Intergranular Cements incl.Clays(XTot.Rk) 27.00 9.00 9.00 Total Solid Components (Total Counts) 272.55 0.00 0.00 Calculated Grain Density 721.54 2.65 2.65 Tot. Framework+Intergranular Compon.(Tot.Cts) 282.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 36.00 12.77 12.77 Compaction Loss(X Framework+Intergran. Comp.) 25.18 Bulk Volume Corrected Compaction Loss 28.86 Calculated Initial Porosity 37.94 t*,rt********,tr**,tet,r***,~a~**,t,t**,t**:tx***~tt*****~x* COMMENTS ***,tx****,t*~***:r**:tt*:~***,~x**~xrx~~***,t~~ The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. The stable heavy mineral is a garnet. The glauconitic pellets range in color from pale olive green to grass green. It is very difficult to assess the amount of clay in the sideritic matrix. The Siderite tends to mask much of the clay present. Possible remnants of plagioclase occur in the ferroan calcite replacing unknown framework grains. Ferroan calcite cement occurs above well-developed quartz overgrowths. A trace of potassium feldspar extensively replaced by ferroan calcite is present. Traces of kaolinite replacing glauconite pellets are present. POINT .COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer .Cronus #1, Sec 8, T8N, R6E Age/Strat. Unit Designation: Kuparuk A Depth/Sample I.D.: 7772 Mean size = O.O68mm (3.88 Phi) Sorting = .371 Phi Porosity = 5.4 Permeability (md) _ .001 Total Counts = 300 ' Lithology: Ironstone with thin streaks of swirled quartzose very wel l sorted coarse siltstone and very fin e-grained sandstone cemented by siderite Special Comment: Size and sorting data are measured values and apply to framework fra ction only. Poroperm Filename: 7772 .PCT Date: 06-18-2006 Formula Filename.ext: LCRETFRM:WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED. ' COMPOSITION COMPOSITION COM POSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 19 6.3 90.5 6.3 90.5 Muscovite 1 0.3 4.8 0.3 4.8 Detrital Dolomite Fragment 1 0.3 4.8 0.3 4.8 PORES PORE-FILLERS Very Sideritic Matrix (33-66X of matrix) 6 2.0 30.0 2.0 30.0 Rhomb siderite (finely xline <.O6mm) 9 3.0 45.0 3.0 45.0 Kaoiinite 1 0.3 5.0 0.3 5.0 Ferroan Calcite 4 1.3 20.0 1.3 20.0 REPLACEMENT COMPONENTS FRACTURES/SHALE LAMINAE/BURROWS Ankerite Fracture Fill 2 0.7 0.8 0.7 0.8 Very Sideritic Clay/Mud Lamina or Burrow 2 57 85.7 99.2 85.7 99.2 OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS I (#) COMPOSITION COMPOSITION • - -------------•-----------------------------.. Total Framework Grains (X Total Rock) . ------- - 21.00 ------------ 7.00 ------• - ---- 7.00 Total Framework - Unknowns (XTotal Rock) 21.00 7.00 7.00 Q - Quartzose Components (XFrmwork - Unknown). 19.00 90.48 90.48 F - Feldspathic.Components (XFrmwrk - Unknwn) 0.00 0.00 0.00 L - Lithic Components (X Framework - Unknwn) 2.00 9.52 - 9.52 Total Framework-Unkn.(Dickinson-TotQtFL Cts) 19.00 6.33 6.33 Qt - Quartzose Comp. (Dickinson)(XTotal QtFU 19.00 100.00 100.00 F - Feldspathic.Comp.(Dickinson)(XTotal QtFL) 0.00 0.00 0.00 L - Lithic Compon. (Dickinson)(XTotal QtFL) 0.00 0.00 0:00 Tot. Framework-Unkn.(Dickinson-TotQmFLt Cts) 19.00 6.33 6.33. " Qm - Monocryst.Qtz. (Dickinson)(XTota1 QmFLt) 19.00 100.00 100.00 F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) 0.00 0.00 0.00 Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) 0.00 0.00 0.00 Total Quartz (X Framework) 19.00 90.48. 90.48 Total. Monocrystalline quartr (X Framework) 19.00 90.48 90.48 Total Polycrystalline quartz (X Framework) 0.00 0.00 0.00 Total Chert (X Framework) 0.00 0.00 0.00 Total Sandstone/siltstone/Qtzite (X Frmwrk) 0.00 0.00 0.00 C/Q Ratio 0.00 0.00 0.00 Total Feldspar (% Framework) 0.00 0.00 0'.00 Total Plagioclase (X Framework 0.00 0.00 0.00 Total Potassium.Feldspar (X Framework) 0.00 0.00 0.00 P/F Ratio 0.00 0.00 0.00 Total Ductile (X Framework) 1.00 4.76 4.76 Total Clay Peloids (X Framework) 0.00 0.00 0.00 Total Nonoxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Oxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 0.00 0.00 0.00 Total Nonglauconitic peloids (% Framework) 0.00 0:00 0.00 Total Phyllite (X Framework) 0.00 0.00 0.00 Total Organic Fragments (X Framework) 0.00 0.00 0.00 Total Muscovite and Chlorite (X Framework) 1.00 4.76 4.76 Total Chamosite&Iron-rich ooids (XFramework) 0.00 0.00 0.00 Total DetritalCarbonate Frags. (X Framework) 1.00 4.76 4.76 Total Fossil Fragments (X Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(% Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X Framework) 1.00 4.76 4.76 Total siderite Fragments (~ Framework) 0.00 0.00 0.00 Total Siliceous Fossil Fragments(X Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100:00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 263.00 87.67 87.67 Total Clay Laminae & Burrows (X Total Rk.) 257.00 85.67 85.67 Total Dispersed Matrix (XTotal Rock) 6.00 2.00 2.00 POINT COUNT ANALYSIS Region I.D.: .North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #I. Sec 8. T8N. R6E Age/Strat. Unit Designation: Kuparuk A Depth/Sample I.D.: 7772 SUMMARY CALCULATIONS. COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Carbonate Cements (X Total Rock) ..13.00 4.33 4.33 Total Siderite Cements (X Total Rock) 9.00 3.00 3.00 Total AnkeriteCement (X Total Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 1.00 0.33 0'.33 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 1.00 0.33 0.33 Total Detrital Clay Rims (X Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (X Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 0.00 0.00 0.00 Total Chert 8 Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 0.00 0.00 0.00 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (% Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 20.00 6.67 6.67 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 13.00 65.00 65.00 M - Matrix (X Carb.Cem+Mtx+Other Cements) 6.00 30.00 30.00 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 1.00 5.00 5.00 Total Counts (Tot.counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 2.00 0.67 0.67 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 0.00 0.00 0.00 Tot. Calc. Intergran. Porosity(X Total Rock} 1.60 0.53 0.53 Tot. Calc. Intragran. Porosity(X Total Rock). 0.00 0.00 0.00 Tot. Shrinkage Porosity (X Total Rock) 0.00 0.00 0.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 53.00 17.67 17.67 Total Calculated Microporosity(X Total Rock) 52.60 17.53 17.53 Calculated Secondary Porosity (X Total Rock) 0.00 0.00 0.00 Tot.Intergranular Cements incl.Clays(XTot.Rk) 14.00 4.67 4.67 Total Solid Components (Total Counts) 247.00 0.00 0.00 Calculated Grain Density 739.50 2.99 2.99 Tot. Framework+Intergranular Compon.(Tot.Cts) 41.00 0.00 0.00' Total Intergranular Volume (XFrame+Intergrn) 20.00 48.78 48.78 Compaction Loss(k Framework+Intergran. Comp.) -10.16 Bulk Volume Corrected Compaction Loss -19.84 Calculated Initial Porosity 38.62 ~r****,~x**,t*,t**~r**~x****~~rt****~x*******~***~x COMMENTS ,t**~t,~x~x*~t~,t~x~,t,~x**~x*,~x,k:t*~****~****~x**** The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for. potassium feldspa r and dual carbonates. The sideritic matrix probably contain minor hidden microporosity. Traces of glauconitic and non•glauconitic pellets are present. It is very difficult to assess the amount of clay in the sideritic matrix. The siderite tends to mask much of the clay present. The counts recorded as ankerite fracture fill actually are ferroan calcite fracture fill. The fracture is 0.0 25mm wide and locally is also filled by kaolinite. The quartzose siltstone/sandstone is concentrated in thin swirled streaks. POINT .COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. TBN. R6E Age/Strat. Unit Designation: Kuparuk A Depth/Sample I.D.: 7793 Mean size = 0.067mm (3.90 Phi) Sorting = .324 Phi Porosity = 6.6 Permeability (md) _ .008 Total Counts = 300 Lithology: Finely laminated burrowed argillaceous quartzose very well sorted coarse siltstone and very fin e-grained sandstone/mudstone/shale Special Comment: Size and sorting data are measured values and apply only to the framework fraction. The p Filename: 7793 .PCT Date: 06-18-2006 Formula Filename.exti LCRETFRM.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total. cnts) (X fraction). FRAMEWORK COMPONENT ', Monocrystalline Quartz. 160 53.3 89.4 53.3 89.4 Dense Chert 2 0:7 1.1 0.7 1.1 Stable Heavy Minerals(Zir/Tour/Rut/Gar) 1 0.3 0.6 0.3 0:6 Nondescript Polycryst.Qtz (2-5 subunits) 1 0.3 0.6 0.3 0.6 Plagioclase 1 0,3 0.6 0.3 0.6 Phyllite 1 0,3 0.6 0.3 0.6 Clay/Mud Peloid (non-glauconitic) 2 D J 1.1 0.7 1.1 Organic fragment 1 0.3 0.6 0.3 0.6 Muscovite 5 1.7 2.8 1.7 2.8 Unknown Framework Grain 5 1.7 2.8 1.7 2.8 PORES PORE-FILLERS Clay and Mud Matrix 46 15.3 .68.7 15.3 68.7 Ankerite 2 0.7 3.0 0.7 3.0 Rhomb Siderite (finely xline <.06mm) 3 i.0 4.5 1.0 4:5 Detrital Glauconite or Other Clay Rim 1 0.3 1.5 0.3 1:5 Quartz Overgrowth 4 1.3 6.0 1.3 6.0 Pyrite/Marcasite 3 1.0 4.5 1.0 4.5 Ferroan Calcite 8 2.7 11.9' 2.7 11.9 REPLACEMENT COMPONENTS fRACTURES/SHALE LAMINAE/BURROWS Clay Laminae and Burrows 53 17.7 98.1 17 J 98.1'. Sideritic Clay/Mud Lamina or Burrow Fill 1 0.3 1.9 0.3 1.9 .OVERSIZE GRAINS.(>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Framework Grains (X Total Rock) 179.00 59.67 59.67 Total. Framework -Unknowns (XTotal Rock) 174.00 58.00 58.00 Q - Quartzose Components (XFrmwork - Unknown) 164.00 94.25 94.25 F - Feldspathic.Components (XFrmwrk - Unknwn) 1..00 0.57 0.57 L - Lithic Components (X Framework - Unknwn) 9.00 5.17 5.17 Total Framework-Unkn.(Dickinson-TotQtFL Cts) 165:00 55.00 55.00 Qt - Quartzose Comp. (Dickinson)(XTotal QtFL) 163.00 98.79 98.79 f -Feldspathic.Comp.(Dickinson)(%Total QtFL) 1.00 0.61 0.61 L - Lithic Compon. (Dickinson)(XTotal QtFL) 1.00 0.61 0.6L Tot. Framework-Unkn:(Dickinson-TotQmFLt Cts) 165.00 55.00 55.00 Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) 160.00 96.97 96.97 F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) 1.00 0.61 0.61 Lt -Lithic Comp. (Dickinson) (XTotal QmFLt) 4.00 2.42 2.42 Total Quartz (X framework) 161.00 89.94 89.94 Total Monocrystalline quartz (X Framework) 160.00 89.39 89.39 Total Polycrystalline quartz (X Framework) 1.00 0.56 0.56 Total Chert (X Framework) 2.00 1.12 1.12 Total Sandstone/Siltstone/Qtzite (X Frmwrk) 0.00 0.00 0.00 C/Q Ratio 3.00 0.02 0.02 Total Feldspar (X Framework) 1.00 0.56 0.56 Total Plagioclase (X Framework 1.00 0.56 0.56 Total Potassium.Feldspar (X Framework) 0.00 0.00 0.00 P/F Ratio 1.00 1.00 1.00 Total Ductile (X Framework) 9.00 5.03 5.03 Total Clay Peloids (% Framework) 2.00 1.12 1.12 Total Nonoxidized Glauconite CX Framework) 0.00 0.00 0.00 Total Oxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 0.00 0.00 0.00 -Total Nonglauconitic peloids (X Framework) 2:00 1.12 1.12 Total Phyllite (X Framework) 1.00 D.56 0:56 Total Organic Fragments (X Framework) 1.00 0.56 0.56 Total Muscovite and Chlorite (~ Framework) 5.00 2.79 2.79 Total Chamosite&Iron-rich ooids (XFramework) 0.00 0.00 0.00 POINT COUNT. ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8. T8N, R6f Age/Strat. Unit Designation: Kuparuk A Depth/Sample I.D.: 7793 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total DetritalCarbonate Frags. (X Framework) 0.00 0.00 0.00 Total Fossil Fragments (X Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(X Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X Framework) 0.00 0.00 0.00 Total Siderite Fragments (X Framework) 0.00 0.00 0.00 Total Siliceous Fossil Fragments(X Frmwork) 0.00 0.00 0.00. Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) .300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) .100.00 33.33 33.33 'total Clay Laminae b Burrows (X Total Rk.) 54.00 18.00 18.00 Total Dispersed Matrix (XTotal Rock) 46.00 15.33 15.33 Total Carbonate Cements (X Total Rock) 13.00 4.33 4.33 Total Siderite Cements (X Totai Roek) 3.00 1.00 1.00 Total AnkeriteCement (X Total Rock) 2.00 0.6T 0.67 Total Kaolinite (X Tot.Rock) 0.00 0.00 0.00 Total Chlorite (X Tot. Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (X Tot. Rock) 1.00 0.33 0.33 Tota} Oil Stain (X Tot. Rock) 0.00 0.00. 0.00 Total Quartz Overgrowths (X Tot. Rock) 4.00 1.33 1.33 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 3.00 1.00 1.00 Total Other Cements (% Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 66.00 22.00 22.00 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 13.00 .19.70 19.70 M - Matrix (X Carb.Cem+Mtx+Other Cements) 46.00 69.70 69.70 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 7.00 10.61 10.61 Total Counts (Tot.counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X .Total Counts) 0.00 0.00 0.00 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 0.00 0.00 0.00 Tot. Calc. Intergran. Porosity(X Total Rock) 30.10 10.03 10.03 Tot. Calc. Intragran. Porosity(X Total Rock) 0.60 0.20 0.20 Tot. Shrinkage Porosity {X Total Rock) 0.00 0.00 0.00 Total Cale. Porosity(incl.lam.mtx)(X Tot. Rk) 65.65 21.88 21.88 Total Calculated Microporosity(X Total Rock) 65.65 21.88 21.88 Calculated Secondary Porosity (X Total Rock) 0.00 0.00 0.00 Tot.Intergranular Cements incl.Clays(XTot.Rk) 20.00 6.67 6.67 Total Solid Components (Total Counts) 234.35 0.00 0.00 Calculated Grain Density 632.90 2.70 2.70 Tot, Framework+Intergranular Compon.(Tot.Cts) 246.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 67.00. 27.24 27.24 Compaction Loss(X Framework+Intergran. Comp.) 11.68 Bulk Volume Corrected Compaction Loss 16.05 Calculated Initial Porosity 38.91 *~x*******,~x~x~x,rte****~*~x******~x~xtt***~** COMMENTS ****:t,t*****~****~*~r******,rx~~x,~~~x*********~x The thin section was prepared from a l inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. The matrix probably contains minor hidden microporosity. Traces of glauconitic and non-glauconitic pellets are present. The very fine grain size results in extensive component overlap and this makes component identification locall y very difficult. The stable heavy mineral is a probable zircon. The matrix contains much fine organic material. The phyllite count is questionable. POINT COUNT ANALYSIS Region I.D.: North. Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1, Sec 8. T8N, R6E Age/Strat. Unit Designation: Kuparuk A Depth/Sample I.D.: 7812 .Mean size = 0,067mm (3.90 Phi) Sorting = .371 Phi Porosity = 5.6 Permeability (md) _ .001 Total Counts = .300 Lithology: Finely laminated burrowed argillaceous quartzose very well sorted coarse siltstone and very fin e-grained sandstone/mudstone/shale Special Comment: Size and sorting data are measured values and apply only to the framework fraction: The p Filename: 7812 .PCT Date: 06-18-2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Dense Chert Nondescript Polycryst.Qtz (2.5 subunits) Plagioclase Clay/Mud Peloid (non-glauconitic) Organic fragment Muscovite Chlorite Unknown Framework Grain PORES PORE-FILLERS Clay and Mud Matrix Sideritic Matrix (sid.10-33X of matrix) Ankerite Rhomb Siderite (finely xline <.06mm) Pyrite/Marcasite Ferroan Calcite REPLACEMENT COMPONENTS FRACTURES/SHALE LAMINAE/BURROWS Clay Laminae and Burrows OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) 123 41.0 85.4 -41.0 85.4 3 1.0 2.1 1.0 2.1 2 0.7 1.4 0.7 1.4 3 1.0 2.1 1.0 2:1 1 0.3 0.7 0.3 0.7 7 2.3 4.9 2.3 4.9 3 1.0 2.1 1.0 2:1 1 0.3 0.7 0.3 0.7 I 0.3 0.7 0.3 0,7 38 12.7 77.6 12.7 77.6 5 1.7 10.2 1.7 10.2 2 0.7 4.1 0.7 4.1 1 0.3 2.0 0.3 2.0 2 0.7 4.1 0.7 4.1 1 0.3 2.0 0.3 2.0 107 35.7 100:0 35.7 100.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Framework Grains (k Total Rock) 144.00 48.00 48.00 Total Framework - Unknowns (XTotal Rock) 143.00 47.67 47.67 Q - q uartzose Components (XFrmwork - Unknown) 128.00 89.51 89.51 F - Feldspathic.Components (XFrmwrk - Unknwn) 3.00 2:10 2.10 L - L ithic Components (X Framework - Unknwn) 12.00 8.39 8.39 Total Framework-Unkn.(Dickinson-TotQtFL Cts) 131.00 43.67 43.67 Qt - quartzose Comp. (Dickinson)(XTotal QtFU 128.00 97.71 97.71 F - F eldspathic.Comp.(Dickinson)(XTotal QtFL) 3.00 2.29 2.29 L - L ithic Compon. (Dickinson)(XTotal QtFL) 0.00 0.00 0.00 Tot. Framework-Unkn.(Dickinson-TotQmFLt Cts) 131.00 43.67 43.67 Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) 123.00 93.89 93.89 F - F eldspath. Comp.(Dickinson)(XTotal QmFLt) 3.00 2:29 2.29 Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) 5.00 3.82 3.82 Total Quartz (X Framework) 125.00 86.81 86.81 Total Monocrystalline quartz (X Framework) 123.00 85.42 85.42 Total Polycrystalline quartz (X Framework) 2..00 1.39 1.39 Total Chert (X Framework) 3.00 2.08 2.08 Total Sandstone/siltstone/Qtzite (X Frmwrk) 0.00 0.00 0.00 C/Q R atio 5.00 0.04 0.04 Total Feldspar (X Framework) 3.00 2.08 2.08 Total Plagioclase (X Framework 3.00 2.08 2.08 Total Potassium.Feldspar (X framework) 0.00 0.00 0:00 P/F R atio 3,00 1.00 1.00 Total Ductile (X Framework) 12.00 8.33 8.33 Total Clay Peloids (X Framework) 1.00 0.69 0.69 Total Nonoxidized Glauconite (X Framework) 0.00 0.00" 0.00 Total Oxidized Glauconite (X framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 0.00 0:00. 0.00 Total Nonglauconitic peloids (X Framework) 1..00 0.69 0.69 Total Phyllite (X framework) 0.00 0.00 0.00 Total Organic Fragments (X Framework) 7.00 4:86 4.86 Total Muscovite and Chlorite (X Framework) 4.00 2.78 2.78 Total Chamosite&Iron-rich ooids (XFramework) 0.00 0.00 0.00 Total DetritalCarbonate Frags. (X Framework) 0.00 0.00 0.00 Total Fossil Fragments (X Framework} 0.00 0.00 0:00 Total Calcite. and Limest. Frags.(X Framework) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: Pioneer Cronus #1. Sec 8. T8N. R6E Age/Strat. Unit Designation: Kuparuk A Depth/Sample I.D.: 7812 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Dolomite Fragments (X Framework) 0.00 0.00 0.00 Total Siderite Fragments (X Framework) 0.00 0.00 0.00 Total Siliceous Fossil Fragments(X Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 150.00 50.00 50.00 Total Clay Laminae & Burrows (% Total Rk.) 107.00 35.67 35.67 Total Dispersed Matrix (XTotal Rock) 43.00 14.33 14.33 Total Carbonate Cements (X Total Rock) 4.00 1.33 1.33 Total Siderite Cements (X Total Rock) 1.00 0.33 0.33 Total AnkeriteCement (X Total Rock) 2.00 0.67 0.67 Total Kaolinite (X Tot.Rock) 0.00 0.00 0.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (X Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (X Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 0.00 0.00 0.00 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 2.00 0.67 0.67 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem,(Total Counts) 49.00 16.33 16.33 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 4.00 .8.16 8.16 M - Matrix (X Carb.Cem+Mtx+Other Cements) 43.00 87.76 87.76 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 2.00 4.08 4.08 Total Counts (Tot counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 0.00 0.00 0.00 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0:00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 0.00 0.00 0.00 Tot. Ca1c. Intergran. Porosity(X Total Rock) 27.20 9.07 9.07 Tot. Calc. Intragran. Porosity(X Total Rock) 0.30 0.10 0.10 Tot. Shrinkage Porosity (X Total Rock) 0.00 0.00 0.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 97.05 32.35 32.35 Total Calculated Microporosity(X Total Rock) 97.05 32.35 32.35 Calculated Secondary Porosity (% Total Rock) 0.00 0.00 0.00 Tot.Intergranular Cements incT.Clays(XTot.Rk) 6.00 2.00 2.00 Total .Solid Components (Total Counts) 202.95 0.00 0.00 Calculated Grain Density 535.37 2.64 2.64 Tot. Framework+Intergranular Compon.(Tot.Cts) 193.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 49.00 25.39 25.39 Compaction. Loss(X Framework+Intergran. Comp.) 13.23 Bulk Volume Corrected Compaction Loss 17.73 Calculated Initial Porosity 38.62 ************~****~***~*~xrr~r******,tt***~*,r* COMMENTS ,r**********~x*:rk*~x*******,rk****~~***,tt~*~,t~tx The thin section was prepared from a 1 inch diameter rotary sidewall plug and is stained for potassium feldspa r and dual carbonates. The matrix probably cohtains.minor hidden microporosity. A few arenaceous/siliceous forams are present. The very fine grain size results in extensive component overlap and this makes component identification locall y very difficult. The count recorded as chlorite is questionable. This could be an altered muscovite. The matrix contains much fine organic material. Core Lab acsExv®m oerm~s~max Pioneer Natural Resources Alaska, Inc. Cronus No. 1 Well Cronus Exploratory Unit Alaska ~ . _. ~~ fANFIDE~I~ I~EC1~~~ ~~~ 2 s zoos Alaska Oil & bas Cons. Commission Anchorage This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the olient. The conclusions, inf`ercuces; deductions and opinions rendered herein reflect the examination, study and testing of these items, and represent the best judgement of Core Iaboratories. Any reliance nn the intiinnation contained herein concerning the profitability ar productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared frrr the exclusive and confidential use of the client .+nd no other party. PETROLEUM SERVICES 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 ~ 1 ~'~ t ~' CORE LABORATORIES LP HOUSTON ADVANCED TECHNOLOGY CENTER Pioneer Natural Resources Alaska, Inc. Cronus No.1 Well Cronus Exploratory Unit Alaska ~~' CMS-300 ROTARY CORE ANALYSIS CL File No.: HOU-060257 Date: April 25, 2006 Analyst(sJ: TW, LA, JH Drilling Fluid:0il Base Mud Sample Depth Net Confining Porosity Permeability Beta Alpha Grain Number stress Klinkenberg Kair Density Footnote ft psig °~ mD mD R -1) microns cm3 29 6288.00 2200 9.94 0.010 0.016 1.49E+12 4.82E+01 2.716 28 6301.00 2200 13.28 0.371 0.431 7.33E+10 8.70E+01 2.688 27 6307.00 2200 11.44 0.087 0.107 2.02E+10 5.59E+00 2.724 26 7112.00 2200 6.58 0.078 0.085 1.83E+10 4.55E+00 2.442 (1) 25 7117.00 2200 12.25 0.061 0.085 7.23E+11 1.42E+OZ 2.679 24 7127.00 2200 11.45 0.028 0.042 4.76E+12 4.19E+02 2.671 23 7144.00 2200 8.57 0.011 0.016 1.03E+13 3.53E+02 2.612 22 7153.00 2200 13.43 0.086 0.116 5.88E+11 1.63E+02 2.694 21 7158.00 2200 12.25 0.023 0.034 4.23E+12 3.12E+02 2.700 20 7172.00 Ambient 10.82 0.066 0.146 2.667 (2) 19 7196.00 2200 9.84 0.006 0.010 2.29E+13 4.04E+02 2.682 18 7250.00 Ambient 11.45 0.098 0.201 2.695 (2} 17 7262.00 Ambient 10.95 0.039 0.100 2.719 (2) 16 7269.00 2200 11.35 0.019 0.029 4.93E+12 3.01E+02 2.679 15 7282.00 2200 10.29 0.012 0.021 7.50E+12 2.84E+02 2.690 14 7289.00 2200 11.22 0.017 0.027 5.24E+12 2.69E+02 2.730 13 7296.00 2200 9.59 0.007 0.012 1.25E+13 2.56E+02 2.685 12 7345.00 2200 8.66 0.004 0.008 2.14E+13 3.03E+02 2.690 11 7384.00 Ambient 10.32 0.104 0.211 2.670 (2) 10 7755.00 Ambient 17.56 3.230 4.220 3.224 (1,2) 9 7756.00 2200 20.33 0.355 0.418 2.45E+11 2.73E+02 3.149 8 7757.00 2200 19.06 0.323 0.378 1.40E+11 1.42E+02 2.918 7 7758.00 2200 13.59 0.104 0.132 2.23E+11 7.23E+01 2.660 6 7759.00 5 7772.00 Ambient 5.40 0.001 0.009 3.343 (2) 4 7793.00 2200 6.63 0.008 0.018 1.76E+14 4.50E+03 2.677 Page 1 of 2 CORE LABORATQRIES LP HOUSTON ADVANCED TECHNOLOGY' CENTER Pioneer Natural Resources Alaska, Inc. ~~ Cronus No. 1 Well Cronus Exploratory Unit Alaska CMS-300 ROTARX CORE ANALYSIS CL File No.: HOU-060257 Date: Apri125, 2406 AnaVy$t('s), TW, LA, JH Drilling Fluld:0it Base Mud Sample .Depth Net confining Porosity Permeability Beta Alpha Grain Number .stress KIlnkenbe Kaffir pensity Footnote ft psig °~ mD mD ft(-1) microns Cm3 7797.00 7810.00 7812.00 220D 5.63 .0.001 0.002 2.20E+16 5.24E+04 2.668 Footnotes (1) :Denotes fractured or chipped sample. Permeability and/ar porosity may be optimistic. (2) :Denotes sample unsuitable for measurement at stress. Porosity detemined using Archimedes bulk volume at ambient conditions. Permeability measurements made with un-steady state profilE permeameter. Page 2 of 2' CORE LABORATORfES LP HOUSTON ADVANCED TECHNOLOGY CENTER Pioneer Natural Resources Alaska, Inc. Cronus No. 1 Weil Cronus Exploratory Unit Alaska ~~ Care tali Iwo CL File No.: HOU-060257 Date: Apri125, 2006 Analyst(s~: TVII, LA, JH Drilling Fluid:0il Base Mud CMS-300 ROTARY CORE ANALYSIS -DEAN STARK FLUID SATURATIONS Sample Depth Net Confining Porosity Permeabili Saturation Grain Number Stress Klinkenber Kafir Oil Water Density Footnote ft prig % mD mD % Pore Volurrtie g/cm3 Description 29 6288.00 2200 9.94 0.010 0.016 57.5 41.4 2.716 Sd vfg sshy lam slty 28 6301.00 2200 13.28 0.371 0.431 57.4 42.2 2.688 Sd vfg sshy sfty 27 6307.00 2200 11.44 0.087 0.107 47.3 44.6 2.724 Sd vfg sshy lam sRy 26 7112.00 2200 6.58 0.078 0.085 1.5 78.8 2.442 Sd vfg sshy lam slty carb (1) 25 7117.00 2200 12.25 0.061 0.085 58.9 36.5 2.679 Sd vfg sshy sglauc 24 7127.00 2200 11.45 0.028 0.042 64.8 34.6 2.671 Sd vF fg sshy sglauc 23 7144.00 2200 8.57 0.011 0.016 29.3 64.4 2.612 Sd vfg shy lam sshy 22 7153.00 2200 13.43 0.086 0.116 57.9 33.3 2.694 Sd fg vsshy 21 7158.00 2200 12.25 0.023 0.034 70.0 28.8 2.700 Sd fg vsshy 20 7172.00 Ambient 10.82 0.066 0.146 63.3 28,3 2.667 Sd vF fg sshy sglauc (2) 19 7196.00 2200 9.84 0.006 0.010 54.1 38.6 2.682 Sd vf-fg sshy sglauc 18 7250.00 Ambient 11.45 0.098 0.201 70.4 26.9 2.695 Sd vfg sshy sglauc (2) 17 7262.00 Ambient 10.95 0.039 0.100 62.8 35.3 2.719 Sd vfg sshy sglauc (2) 16 7269.00 2200 11.35 0.019 0.029 68.3 28.4 2.679 Sd of-tg sshy sglauc 15 7282.00 2200 10.29 0.012 0.021 52.2 38.2 2.690 Sd vfg sshy sglauc 14 7289.00 2200 11.22 0.017 0.027 72.4 26.3 2.730 Sd vfg sshy sglauc 13 7296.00 2200 9.59 0.007 0.012 49.1 41.0 2.685 Sd vfg sshy sglauc 12 7345.00 2200 8.66 0.004 0.008 56.4 39.5 2.690 Sd vfg shy sglauc 11 7384.00 Ambient 10.32 0.104 0.211 58.3 39.2 2.670 Sd vfg sshy sglauc (2) 10 7755.00 Ambient 17.56 3.230 4.220 13.9 59.7 3.224 Sd vf-fg shy sfty glauc pyr (1,2) 9 7756.00 2200 20.33 0.355 0.419 64.5 32.7 3.149 Sd vf-fg shy sfty glauc pyr 8 7757.00 2200 19.06 0.323 0.378 56.5 39.7 2.918 Sd vf-fg shy slty glauc pyr 7 7758.00 2200 13.59 0.104 0.132 41.5 48.0 2.660 Sd fg sshy glauc 6 7759.00 No Recovery 5 7772.00 Ambient 5.40 0.001 0.009 21.5 63.4 3.343 Sd vFg vshy slty v pyr (turbidite) (Z) 4 7793.00 2200 6.63 0.008 0.018 16.8 80.9 2.677 Sd vfg shy lam sity (turbidite) Page 1 of 2 CORE LABORATOR/ES LP HOUSTON ADVANCED TECHNOLOGY CENTER Pioneer Natural Resources Alaska, Inc. Cronus No. 1 Well Cronus Exploratory Unit Alaska ~~ taretati .~~~ CL Fiie No.: HOU-060257 Date: April 25, 2006 Analyst(s): TW, LA, JH Drilling Fiuid:0i1 Base Mud CMS-300 ROTARY CORE ANALYSIS -DEAN STARK FLUID SATURATIONS Sample Depth Net Confining Porosity Permeabil' Saturation Grain Number stress Klinkenberg Kair Oil Water Density Footnote >t psig % mD mD % Pore Volume g/cm3 Description 7797.00 No Recovery 7810.00 No Recovery 7812.00 2200 5.63 0.001 0.002 15.7 79.8 2.668 Sd vfg vshy lam slty (turbidite) Footnotes (1) :Denotes fractured or chipped sample. Permeability andlor porosity may be optimistic. (2) :Denotes sample unsuitable for measurement at stress. Porosity detemined using Archimedes bulk volume at ambient conditions. Permeability measurements made with un-steady state profile permeameter. Page Z of 2 Pioneer Natural Resources Alaska, Inc. CL File No.: HOU-060257 Cronus No. 1 Well Date: Apri125, 2006 Cronus Exploratory Unit Analyst(s): TW, LA, JH Alaska ~~ Drilling Fluid:0i1 Base Mud o~~,~ APPENDIX A: EXPLANATION OF CMS-300 TERMS "b", "Beta, and "Alpha" K,~ = Equivalent non-reactive liquid permeability, corrected for gas slippage, mD Ka;, = Permeability to Air, calculated using K,;, and b, mD b = Klinkenberg slip factor, psi R (Beta) = Forcheimer inertial resistance factor, ft'' a (Alpha) = A factor equal to the product of Beta and K„,. This factor is employed in determining the pore level heterogeneity index, h. H; = logo (aRl/RQI) a, microns = 3.238E"g pK~ 0 = Porosity, fraction RQI = Reservoir Quality Index, microns RQI = 0.0314(K/e)o.s For further information please refer to: Jones, S.C.: "Two-Point Determination of Permeability and PV vs. Net Confining Stress" SPE Formation Evaluation (March 1988) 235-241. Jones S.C.: "A Rapid Accurate Unsteady-State Klinkenberg Permeameter," Soc. Pet. Ena. J. (Oct. 1972) 383-397. Jones, S.C.: "Using the Inertial Coefficient, R, To Characterize Heterogeneity in Reservoir Rock: SPE 16949 (September 1987). Amaefule, J.O.; Kersey, D.G.; Marschall, D.M.; Powell, J.D.; Valencia, L.E.; Keelan, D.K.: "Reservoir Description: A Practical Synergistic Engineering and Geological Approach Based on Analysis of Core Data,: SPE Technical Conference (Oct. 1988) SPE 18167. Pioneer Natural Resources Alaska, Inc. Cronus No. 1 Well Cronus Exploratory Unit Alaska HOU-060257 Klinkenberg Permeability vs Porosity 10 ~ 0.1 E .. a R d E w a d a e w ~ 0.01 Y 0.001 0.0001 Porosity (%) 0 2 4 6 8 10 12 14 16 18 20 Awn ~! ~''~`~h ~! "~1 Sperry-Sun • • Sperry-sun DRILLING SERVICES Pioneer Natural Resources END OF WELL REPORT Cronus #1 CONfIDENTIAI RECEIVEn ~}- r~~ 2 5 2006 '` E~ ~ G~ Cons. Ctxrsnission Andiorage ~pCa -Ulm! ~a e,~,w~ ~l~~~ ~ t 3 ~52`d • • TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Reports 6. Show Reports 7. Days vs Depth 8. Survey Report -Baker Information 9. Engineering Log /Well Diagram Pore Pressure 10. Data C D speri-~y-sun ORILLIfYG 5ER111CE5 s • GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: Wellhead Coordinates Wellhead Coordinates Location; SDL Engineers: Pioneer Natural Resources Doyon Akita Arctic Fox #1 Cronus # 1 Cronus Unit North Slope Alaska United States 50-103-20523 AK-AM-0004253758 1St March 2006 19St March 2006 X= 413,055 Y= 5,874,246 4079' FSL, 3022' FEL Section 8 Township T8N, Range R6E Mark Lindloff Doug Wilson Eugene Payne Wayne Hermanson Company Geologist: SSDS Unit Number: T. Bicklein ,Don Brazzalorio 107 sperl-~~-sun QRILL111lG 5ER1fIGE5 ~ • • Cronus # 1 -Diary of Events 1St March 2006 Rig up and prepare to spud well. ' tad March 2006 Wait on crossover. Spud well and drill 12 %4" hole from 89' MD drill with Bit No. 1 STC XR+, TFA = 0.75 . with 8.9 ppg mud at 300 viscosity. Drill to 1358' ' MD, performing surveys every 500'. Average ROP was 180 ft/hr and mud weight was 9.2 ppg. Formation consisted of primarily clay with sand stringers. Some lignite was noted in the 240' cuttings sample. Methane hydrates were noted at 890-920' MD and 1012-1055' MD. Continous drilled gas from 1193' MD. Average drilled gas in this interval was 85 units. 3rd March 2006 Drill from 1358' to 1644' MD, where a 20 stand short trip was performed, with maximum short trip gas of 290 units. Continue drilling from 1644' MD to 2350' MD. Mud weight ranged from 9.2 to 9.5 ppg through this drilling interval. Average ROP was 73.5 ft/hr. Formation consisted of clay grading to claystone in places with sandy interbeds. Average drilling gas was 83 units in this interval ' 4th March 2006 Drill from 2350' to 2515' MD, which was the 12 '/4" total depth. Average drilled gas was 85 units. Circulated bottoms up with sweep pumped before ' bottoms up, which resulted in a mud ring at the bell nipple. Circulated hole clean and performed a 14 stand short trip. Circulated bottoms up and prior to bottoms up a mud rmg was noted. Maximum bottoms up gas was 285 units. Circulated hole clean and ' tripped out of hole for Wireline electric logs. Wireline logs stopped at 350' .Picked up the BHA and run in hole, where a bridge was encountered at 441' MD. Washed and re amed budge with resultant clay to surface. ' 5th March 2006 Tripped in hole to 2515' MD, pumped sweep with clay to surface. Maximum trip gas was 126 units. Circulated another bottoms up, then tripped out of the ' hole. Run Wireline logs without incident. Rigged up to run 9 5/8" 401b/ft casing and ran in to 2500' MD, with good mud returns. Circulated bottoms up with maximum gas of 74 units. Continued circulating and rigged up to cement. ' 6th March 2006 Circulated casing with average gas of 11 units. Pump cement and displace cement with 180 bbls of 8.9 ppg Enviromul oil based mud. -good cement to ' surface. Nippled down diverter and nipple up BOP. Pump out pits to trucks and clean pits. 7th March 2006 Nipple up BOP, clean pits and add 580 bbls of 8.9 ppg Enviromul oil based mud to pits. Test BOP and pickup 8 %2" Bit #2 DS70FNPV with TFA= 1.035 and drilling assembly and trip in hole. Tag cement at 2406' MD. Test 9 5/8" casing. 8th March 2006 Test 9 5/8" casing, drill cement and float equipment, where circulated maximum gas of 179 units of trapped gas while drilling cement between float and casing • • 'i~ , shoe. Drill casing shoe ans rathole and 20' of new hole to 2535' MD. Performed a Leak Off Test to 16.2 ppg EMW. Drilled new * %2" hole from 2535' to 3241' MD. Average drilled gas was 43 units with a maximum peak of 221 units noted at 2969' MD. The formation drilled in this interval primarily consisted of Claystone with minor siltstones. 9th March 2006 Drill 8 %" hole from 3241 to 4514' MD, performing gyro syrveys ' every 500'. Circulate bottoms up. Wiper trip ti 9 5/8" casing shoe. Average gas was 34 units with a maximum peak of 217 units at 4480' MD. Mud weight was 8.9 ppg Enviromul oil based mud. Average ROP was 93.6 ft/hr during this interval. The formation consisted of claystones with intrbedded siltstones and minor tuffs. 10th March 2006 Wiper trip to 9 5/8" casing shoe from 4515'. Ran back to bottom and washed last joint. Circulated bottoms up with maximum wiper trip gas of 75 units. Drill 8 %" hole from 4515 to 5532' MD. Mud weight was gradually increased to 9.5 ppg. Average ROP was 70 ft/hr. Average gas was 36 units for this interval with a maximum peak of 243 units at 4564' MD. The formation consisted of claystones interbedded with siltstones with sandstone stringers and minor tuffs and chalky limestones. ' 11th March 2006 Dri118 1/2"' hole from 5532 to 6673' MD. Mud weight gradually increased to 9.8 ppg. Average ROP was 48 ft/hr. Average gas was 65 units for this interval with a maximum peak of 531 units at 6316' MD. The formation consisted of primarily of siltstones interbedded with sandstones from 5540' MD with gradation to claystones below 5850' MD and interbedded sandstones from 6250' MD that form the Turbidite sequence at the base of the Colville group. 12th March 2006 Dri116673' to 7113' MD . Pulled tight at connection at 7113' MD t and twist off the 4" drill pipe at the pin /box 2 stands below surface. Run in with an overshot and got on fish. Circulate bottoms up. Mud weight gradually increased to 10.5 ppg. Average ROP was 57 ft/hr. Average gas was 45 units for this interval with a ' maximum peak of 132 units at 6950' MD. The formation consisted of primarily of claystones interbedded with siltstones and sandstones of the Turbidite sequence. 13th March 2006 Circulate bottoms up -max gas 95 units. Pull out of hole. Lay down 5 singles for inspection. Continue to trip out with tight hole from 6920' to 6800', 6520' and 6250'. Kelly up at 6250' and circulate bottoms up -max gas 41 units. Unable to ' rotate, work pipe and jar, finally came free with 260 klbs. Pull out of hole -lay down bent spiral HWDP. Test BOP's. Run in hole with BHA and pick up spiral HWDP. 14th March 2006 Run in hole to 6824' Pick up singles and precautionary ream to bottom. Trip Gas 54 units. Dril18 1/2" hole from 7113' to 7528' through a number of sand sequences: 7100'-7180'; 7260'-7305' and 7340'-7410'. Maximum gas over the sandstone intervals ranged from 185 to 255 units. Pipe became stuck while attempting to make a connection at 7528'. Pump two weighted walnut sweeps and jar on stuck pipe. ~~ i ' 1 15t" March 2006 Jar and work stuck pipe. Shut well in while conducting contraband search of camp and personnel. Rig up and run free point logs. Determine free point at 7434'. Pull out of hole with free point collar locator tools. Start running in with back-off charge on wireline. 16t" March 2006 Run in with back-off charge on wireline and back off pipe at 7422'. Circulate bottoms up and pull out of hole. Rig up Baker wireline and run "Mini Slam with orientation" (DIL; ZDL; CN; GR; DIR and CAL) from 2501' to 7400'. POOH with logging tools and rig down Loggers. Start making up fishing tools. Slip & cut drill line. 17t" March 2006 Make up BHA and run in hole. Screw into fish. Circulate and jar pipe (max trip gas gas 49 u) -pipe came free after approximately 8 hours of jarring. Circulate and reduce mud weight to 9.6 ppg with LVT. POOH with fish. 18t" March 2006 Finish pulling fishing assembly out of hole with no problems. Run in hole with 8.5" drilling assembly to 6913'. Break circulation and wash from 6913' to 7528' as precaution. No problems experienced. Drill 8.5" section from 7528'- 7630' using 10- 12K WOB, 130 RPM and 465 gpm flow rate. 19t" March 2006 Dri118.5" section from 7630' to a total depth of 7941' using 10-12K WOB, 130 RPM and 465 gpm flow rate. Average ROP was 68 ft/hr. Max gas of 608 units occurred over the Kuparuk sand section from at 7758' to 7776'. Circulate hole clean and pull 15 stands to 6817' for wiper trip. Trip in to 7898', circulate bottoms up with max gas of 52 units. Pump slug and pull pipe to Log. Rig up and start running wireline logs. 20`" March 2006 Run wireline logs (Quad-Combo; Coring tool run 1 & 2 and M-Rex tool. 21t" March 2006 Rig down Loggers and prepare to pick up tubing for cement job (plugs). Sperry drilling S®rvices Mudlogger's Morning Report astomer: Pioneer Well: Cronus #1 Area: North Slope Lease: Exploration Rig: Doyon Akita AF1 Job No.: AK-AM-4253758 Report No.: 1 Date: 3/1 /2006 Depth 0 Footage Last 24 hrs: 0 Rig Activity: Prepare to spud Report For: Stallings / McDade Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pumps 0 spm Flow rate 0 gpm Gas* 0 units 0 unit; ( 0 units @ 0 ) Pump Capacity 2.849 gps~ ( ) Pump Liner & Strk 6X8 in. Pump Pres 0 psi Mud Wt In 8.70 ppg Visc 300 secs API filt 8.5 ml HTHP ml Mud Wt at Max Gas 8.9 ppg D.qud Wt Out 8.70 ppg PV 51 cP YP 54 Ibs/100ft2 Gels 24 \ 27 \ _ pH 9.0 Sd 0 °i Bit No.: 1 `:"/t On Bit: Type: STC XR+ Bit Size: 12 1/4 RPM: 0 Hrs. On Bit: 0.0 Jets: 1 x 12 Total Revs on Bit: 2 x 16 1 x 18 TFA: 0.7500 0 Footage for Bit Run Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: _ to ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Cu~rr,nt Lilhol~i~~v: Sand ~~ (:I,~; ~~~,3vel % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec~ Ri u and pre are to spud. Logging Engineer: Doug Wilson /Mark Lindioff 10000 units = 100% Gas In Air ustomer: : 2 Pioneer Report No ' °`~"°~ Well: . Cronus #1 Date: 3/2/2006 s perry C3 r;niing s®rvGc~s Area: North Slope Depth 1358 udlogger's Morning Report Lease: Rig: Job No.: Exploration Footage Last 24 hrs: 1260 Doyon Akita AF1 Rig Activity: Drilling AK-AM-4253758 Report For: Stallings I McDade Current R.O.P. 226 ft/hr Gas' 138 units 24 hr Avg 180 ft/hr ( 880 0/85 unit: ( 159 ( 24 hr Max ft/hr @ 1308 ) units @ 1199 ) ) Pump and Flow Data Pumps 186 spm Flow rate 531 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 2000 psi Mud Wt In 9.20 ppg ~Aud Wt Out 9.20 ppg Visc 200 secs API filt 8.0 ml HTHP ml Mud Wt at Max Gas 9.2 ppy PV 37 cP YP 65 Ibs/100ft2 Gels 27 \ 33 \ pH 8.5 Sd 2.5 °i. Bit No.: 1 Type: ',^/t On Bit: 15-20 RPM: STC XR+ Bit Size: 91 Hrs. On Bit: 12 1/4 Jets: 1 x 12 2 x 16 1 x 18 TFA: 0.7500 7.0 Total Revs on Bit: 19K(Surf) Footage for Bit Run 12Rn Trip Depth: Short Trip Depth Tight Spots: to ft Trip Gas: ft Short Trip Gas: to Mud Cut: ppg Trip CI: ppm Mud Cut: ppg Short Trip CI: ppm to ,Feet of Fill on Bottom: ft CurrFnt Lith~_~I~,~~,~ 111 ~~~ S~+n~1 '~0 ~, CI ~~ ~~i i.~l °!~ %LCM ft units ft units ft units ft units Connection Gas and Mud Cut ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg Depth 1000 to 1050 1192 to 1199 1250 to 1261 1311 to 1382 1468 1476 Gas in units Max Background 41 2 159 110 138 80 155 80 139 75 GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot 4107 17717 15612 18021 16557 24 hr Rec< Spud well at 98', drill 12 1/4" hole to 525', surve ,drill to 1017', surve ,drill to 1358' Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air : 3 ustomer: Pioneer Report No t e .~,~, ~"" ' ~ . Well: Cronus #1 Date: 3/3/2006 Sperry Oriliing Services Area: North Slope Depth 2350 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 992 Rig: Doyon Akita AF1 Rig Activity: Drilling Job No.: AK-AM-4253758 Report For: Stallings I McDade Current 24 hr Avg 24 hr Max R.O.P. 7 ft/hr 73.5 ft/hr ( 842 ft/hr @ 1554 ) Gas* 102 units 83 unit: ( 398 units @ 2048 ) ( ) Pump and Flow Data Pumps 191 spm Flow rate 542 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 2288 psi Mud Wt In 9.50 ppg Visc 98 secs API filt 7.4 ml HTHP ml Mud Wt at Max Gas 9.5 ppg D.9ud Wt Out 9.50 ppg PV 30 cP YP 49 Ibs/100ft2 Gels 17 \ 30 \ pH 8.5 Sd 1.5 °i Bit No.: 1 Type: STC XR+ Bit Size: 12 1/4 Jets: 1 x 12 2 x 16 1 x 18 TFA: 0.7500 `:^.'t On Bit: 12.5 RPM: 104 Hrs. On Bit: 20.5 Total Revs on Bit: 60K(Surf) Footage for Bit Run 2''52 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 1644 ft Short Trip Gas: 290 Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to t0 Feet of Fill on Bottom: ft Current Liihol ~ ~:: Sand ~0 ~~ C'I~i,~ '0 51~t % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 1740 to 1770 279 52 31478 2020 to 2080 398 52 45741 to to 24 hr FZec~ Drill from 1358' to 1644' MD, short trip 20 stands, maximum short trip gas 290 units, drill 12 1/4" hole from 1644' to 2350' MD. Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air : 4 ustomer: Pioneer Report No ~ -' ~1~ . Well: Cronus #1 Date: 3/4/2006 Sperry Qrill'ing Sarvic~s Area: North Slope Depth 2515 Mudlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 165 Rig: Doyon Akita AF1 Rig Activity: Cleanout Trip Job No.: AK-AM-4253758 Report For: Stallings / McDade Current 24 hr Avg 24 hr Max R.O.P. 0 ft/hr 39.3 ft/hr ( 246 ft/hr @ 2476 ) Gas* 30 ream units 85 unit: ( 134 units @ 2399 ) ( ) Pump and Flow Data Pumps 193 spm Flow rate 550 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 2460 psi Mud Wt In 9.50 ppg Visc 103 secs API filt 5.5 ml HTHP ml Mud Wt at Max Gas 9.5 ppg ~Aud Wt Out 9.50 ppg PV 35 cP YP 42 Ibs/100ft2 Gels 15 \ 22 \ _ pH 8.3 Sd 0.75 Vii, Bit No.: 1 Type: STC XR+ Bit Size: 12 1/4 Jets: 1 x 12 2 x 16 1 x 18 TFA: 0.7500 `:^Jt On Bit: 10-20 RPM: 105 Hrs. On Bit: 24.7 Total Revs on Bit: 60K(Surf) Footage for Bit Run 217 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 2310 ft Short Trip Gas: 285 Mud Cut: 9.5 ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Curronl Lithulu~~.;: Sand 8i) ,~ Ul;st ~U Slst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec~ Drill 12 1/4" hole from 2350 to 2515' MD (12 1/4" TD), CBU- ump sweep-mud rin at bell nipple, circ hole clean, pum slu ,Short trip 14 stands, CBU-mud ring before BU, maximum as 285 units on bottoms u , circ hole clean, pump 40 bbl sweep, pump slug, TOOH for Elogs, L/D 8" DC's, R/U and run Elogs, Elogs stopped at 350', POOH w/ E-logs, P/U BHA , TIH, Tagged at 441' MD, Wash and ream bridge, clay to surface while reaming/ circ. Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air : 5 ustomer: Pioneer Report No `'~' ~"' ~` t `, . Well: Cronus #1 Date: 3/5/2006 Sp@rry Oriiling s®rvicas Area: North Slope Depth 2515 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 0 Rig: Doyon Akita AF1 Rig Activity: Circ out Csg Job No.: AK-AM-4253758 Report For: Stallings / McDade Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ ) Gas* 11 circ units unit: ( 74 units @ cbu csg ) ( ) Pump and Flow Data Pumps 104 spm Flow rate 298 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 455 psi Mud Wt In 9.50 ppg Visc 97 secs API filt 5.4 ml HTHP ml Mud Wt at Max Gas 9.5 ppy ~Aud Wt Out 9.50 ppg PV 36 cP YP 43 Ibs/100ft2 Gels 15 \ 23 \ 28 pH 8.0 Sd 0.75 % Bit No.: Type: Bit Size: Jets: x x x TFA: ~~^.'t On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: 2515 ft Trip Gas: 126 Mud Cut: 9.5 ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithol~,~iy: Sand 8u Clyst 20 % Slst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec~ Circ and ream and wash brid e from 441', TIH to 2515- kell up and wash to bottom- um sweep, cla to surface, maximum trip as 126 units, circ another BU, pump slug, TOOH for Elogs, run Elo s, L/D 8" BHA, R/U to run 9 5/8" 40 Ib/ft csg, Run casing to 2500' -good returns, CBU -maximum gas 74 units, continue circulating and rig up to cement. Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air ustomer: Pioneer Report No.: 6 -' °° .~ ` ` Well: Cronus #1 Date: 3/6/2006 Sperry or-~n~ng s®rvGc~s Area: North Slope Depth 2515 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 0 Rig: Doyon Akita AF1 Rig Activity: N/U -clean pits Job No.: AK-AM-4253758 Report For: Stallings I McDade Current 24 hr Avg 24 hr Max R.O.P, ft/hr ft/hr ( ft/hr @ ) Gas' 0 units 11 unit: ( units @ ) ( ) Pump and Flow Data Pumps 104 spm Flow rate 296 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 378 psi Mud Wt In 8.90 ppg Visc 50 secs API filt ml HTHP 3.6 ml Mud Wt at Max Gas ppy ~.~ud Wt Out ppg PV 25 cP YP 20 Ibs/100ft2 Gels 9 \ 12 \ pH Sd Bit No.: Type: Bit Size: Jets: x x x TFA: ~^.'t On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: 9.5 ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Currant Lithoingy: sand 5ii ~ I~.~st 2(1 % Slst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec< Circ casin -average gas 11 units, cement casing, displace cement with 180 bbls 8.9 oilbased mud, good cement to surface, N/D diverter, N/U BOP, pump out its to truck and clean pits. Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air ustomer: Pioneer Report No.: 7 `~ t""~" ~` ' ` Well: Cronus #1 Date: 3/7/2006 Sperry Orill'ing Services Area: North Slope Depth 2515 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 0 Rig: Doyon Akita AF1 Rig Activity: Test 9 5/8" csg Job No.: AK-AM-4253758 Report For: Stallings I McDade Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ ) Gas* units unit: ( units @ ) ( ) Cuttings sample Good Fair Poor Pump and Flow Data Pumps spm Flow rate gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 378 psi Mud Wt In 8.90 ppg Visc 90 secs NAP/H20 60/33 % HTHP 3.6 ml Mud Wt at Max Gas ppg ~Aud Wt Out ppg PV 27 cP YP 19 Ibs/100ft2 Gels 11 \ 1_4 \ ES 320.0 Sd °! Bit No.: 2 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x _x TFA: 1.0350 '.^Jt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Currant Lithol~~gy: Sand 3U Clyst 20 ~!, Slst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec~ Ni ple up BOP, clean pits. Add 580 bbls oil based Enviromul mud to pits, Test BOP, P/U 8 1/2" Bit & BHA and TIH, Tag cement at 2406' MD, Test 9 5/8" casing Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air : 8 ustomer: Pioneer Report No ~' `' ~-'" . Well: Cronus #1 Date: 3/8/2006 sp®rry arilfing barvic®s Area: North Slope Depth 3241 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 726 Rig: Doyon Akita AF1 Rig Activity: Drilling Job No.: AK-AM-4253758 Report For: Stallings I McDade Current 24 hr Avg 24 hr Max R.O.P. 82 ft/hr 55.8 ft/hr ( 519 ft/hr @ 2839 ) Gas* 32 units 43 unit: ( 221 units @ 2969 ) ( ) Cuttings sample Good x Pump and Flow Data Pumps 258 spm Flow rate 510 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2150 psi Mud Wt In 8.90 ppg Visc 100 secs NAP/H20 60/34 % HTHP 3.6 ml Mud Wt at Max Gas 8.9 ppg r`Aud Wt Out 8.90 ppg PV 24 cP YP 21 Ibs/100ft2 Gels 12 \ 14 \ ES 363 Sd 0.25 °4. Bit No.: 2 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 'PJt On Bit: 10-12 RPM: 125 Hrs. On Bit: 12.7 Total Revs on Bit: Footage for Bit Run 7?5 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lilhol~u~~,': Sand 1uU ~ Clyst Ci Slst °% %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec< Test casin ,drill cement and float equipment, circulated maximum gas of 179 units of tra ped as while drilling cement between float and shoe, drilled 8 1/2" hole from 2515 to 2535, erformed LOT to 16.2 ppg EMW, Drill 8 1/2" hole from 2535' to 3241'. Logging Engineer: Doug Wilson /Mark Lindloft 10000 units = 100% Gas In Air ustomer: Pioneer : 9 Report No ' ''~`~ '~~- i~` Well: Cronus #1 . Date: 3/9/2006 sp®rry Grilling sarvic®s Area: North Slope Depth 4514 udlogger's Morning Report Lease: Rig: Job No.: Exploration Doyon Akita AF1 AK-AM-4253758 Footage Last 24 hrs: 1273 Rig Activity: Wiper Trip Report For: Stallings I McDade Current 24 hr Avg R.O.P. 0 ft/hr 93.6 ft/hr ( 223 Gas" 0 units 34 unit: ( 217 ( Cuttings sample Good x 24 hr Max ft/hr @ 4347 units @ 4480 ) ) ) Pump and Flow Data Pumps 258 spm Flow rate 510 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2300 psi Mud Wt In 8.90 ppg Visc 70 secs NAP/H2O 60/34 % HT ~:1ud Wt Out 8.90 ppg PV 27 cP YP 16 Ibs/100ft2 Gels HP 3.6 ml Mud Wt at Max Gas 8.9 ppg 9 \ 11 \ _ ES 388 Sd 0.25 °i Bit No.: 2 Type: DS70FNPV Bit Size: ~.^/t On Bit: 10-12 RPM: 130 Hrs. On Bit: 8 1/2 Jets: 6 x 15 x x _TFA: 1.0350 26.8 Total Revs on Bit: Footage for Bit Run 1`!`~`! Trip Depth: ft Trip Gas: Short Trip Depth 4514 ft Short Trip Gas: Tight Spots: to to Mud Cut: ppg Trip CI: ppm NCU Mud Cut: _ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft C~irrenl Lilhulr ~~y: 7U ~ Silt 25 Lly~sl 5 TUFF %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth Gas in units Max Background 4368 to 4510 217 35 to to to GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot 18137 455 99 23 24 hr Rec~ Drill 8 1/2" hole from 3241 to 4514' MD, doing ro devia tion surve sever 500', CBU, erform wi er trip to 9 5/8" casing shoe. Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air : 10 ustomer: Pioneer Report No . Well: Cronus #1 Date: 3/10/2006 Sp®rry ~riliing Sarvic®s Area: North Slope Depth 5532 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 1017 Rig: Doyon Akita AF1 Rig Activity: Drilling Job No.: AK-AM-4253758 Report For: Stallings I McDade Current 24 hr Avg 24 hr Max R.O.P. 95 ft/hr 70 ftlhr ( 206 ft/hr @ 4712 ) Gases 32 units 36 unit: ( 243 units @ 4564 ) ( ) Cuttings sample Good x Pump and Flow Data Pumps 258 spm Flow rate 510 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2800 psi Mud Wt In 9.40 ppg Visc 74 secs NAP/H20 60/32 % HTHP 4.8 ml Mud Wt at Max Gas 9.4 ppg ~Aud Wt Out 9.40 ppg PV 32 cP YP 17 Ibs/100ft2 Gels 11 \ 14 \ ES 374 Sd 0.3 °~„ Bit No.: 2 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 `:^Jt On Bit: 10-12 RPM: 115-130 Hrs. On Bit: 41.3 Total Revs on Bit: Footage for Bit Run 3017 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 4514 ft Short Trip Gas: 75 Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithulr,q,': ~5 ''o Siltst 60 "~~ Clyst 5 ~~ Sandst ~~ %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 4557 to 4565 243 50 20846 565 103 21 4688 to 4701 169 65 13016 413 99 27 to to 24 hr Rec~ Wi er trip to 9 5/8" casing shoe from 4515', TIH, wash to bottom, CBU- maximum gas 75 units, Drill 4515' to 5532' MD, Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air ustomer: Pioneer Report No.: 11 ' `` ~""t ~~~_~ ~"'" Well: Cronus#1 Date: 3/11/2006 sp®rry Oirilling S3®rvic®s Area: North Slope Depth 6673 udlogger's Morning Report Lease: Rig: Job No.: Exploration Doyon Akita AF1 AK-AM-4253758 Footage Last 24 hrs: 1145 Rig Activity: Drilling Report For: Stallings / McDade Current 24 hr Avg R.O.P. 88 ft/hr 48 ft/hr ( 266 Gas'` 38 units 65 unit; ( 531 ( Cuttings sample Good x 24 hr Max ft/hr @ 6230 units @ 6316 ) ) ) Pump and Flow Data Pumps 243 spm Flow rate 480 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2929 psi Mud Wt In 9.80 ppg Visc 78 secs NAP/H2O i5.6/34.~ % HT ~,1ud Wt Out 9.80 ppg PV 33 cP YP 18 Ibs/100ft2 Gels HP 4.4 ml Mud Wt at Max Gas 9.7 ppg 10 \ 14 \ ES 412 Sd 0.5 ° Bit No.: 2 Type: DS70FNPV Bit Size: ~^Jt On Bit: 14.00 RPM: 137 Hrs. On Bit: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 59.0 Total Revs on Bit: Footage for Bit Run 4158 Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to Mud Cut: ppg Trip CI: ppm Mud Cut: _ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft i:urrent Lith~~l~~q ~5 Siltst 75 Clyst ii ", S~~ndst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth Gas in units Max Background 6275 to 6365 531 40 to to to GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot 46424 1314 409 110 19 24 hr Rec~ Drill 5532 to 6673' MD. Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air ustomer: Pioneer Report No.: 12 IL~ ` Well: Cronus #1 Date: 3/12/2006 sp®rr-y Qrilling s®r..ic®s Area: North Slope Depth 7113 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 440 Rig: Doyon Akita AF1 Rig Activity: Circulate BU Job No.: AK-AM-4253758 Report For: Stallings / McDade Current 24 hr Avg 24 hr Max R.O.P. 0 ft/hr 57 ft/hr ( 189 ft/hr @ 6230 ) Gas" 38 units 45 unit: ( 132 units @ 6950 ) ( ) Cuttings sample Good x Pump and Flow Data Pumps 239 spm Flow rate 478 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 3088 psi Mud Wt In 10.00 ppg Visc 75 secs NAP/H2O 58/31 % HTHP 4.4 ml Mud Wt at Max Gas 10.0 ppg ~Aud Wt Out 10.00 ppg PV 41 cP YP 15 Ibs/100ft2 Gels 10 \ 15 \ _ ES 434 Sd 0.5 °! Bit No.: 2 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 ~~^J! On Bit: 14 RPM: 130 Hrs. On Bit: 66.8 Total Revs on Bit: Footage for Bit Run 4F`!8 Trip Depth: 7113 ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to ~ Feet of Fill on Bottom: ft Current ~itholuyy: Siltst 90 Clyst 2 Sandst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 6943 to 6958 132 42 9849 433 199 58 14 6997 to 7009 116 45 9097 316 118 38 8 to to 24 hr Rec~ Drill 6673' to 7113' MD, pull tight on connection at 7113 and twist off 4' drill pipe 2 stands below surface, . run in with overshot and et on fish, circulate bottoms up. Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air ustomer: Pioneer Report No.: 13 ~°'~ "`~~ Well: Cronus #1 Date: 3/13/2006 Sp®rry Oritling SBrVices Area: North Slope Depth 7113 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 0 Rig: Doyon Akita AF1 Rig Activity: P/U BHA Job No.: AK-AM-4253758 Report For: Stallings I McDade Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ ) Gas* units unit: ( units @ ) ( ) Cuttings sample Good x Pump and Flow Data Pumps 0 spm Flow rate 0 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 0 psi Mud Wt In 10.10 ppg Visc 110 secs NAP/H2O 14.8/35.; % HTHP 4.2 ml Mud Wt at Max Gas 10.1 ppg ~.9ud Wt Out 10.10 ppg PV 40 cP YP 17 Ibs/100ft2 Gels 12 \ 16 \ _ ES 422 Sd 0.5 °i. Bit No.: 3 - 2rr1 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 ~;^Jt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: 7113 ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithulu~~~,/: ~ ~o Siltst 90 Clyst 2 Sandst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec< Circulate bottoms u -max as 95 units. Pull out of hole. La down 5 singles for inspection. Continue to trip out with ti ht hole from 6920' to 6800', 6520' and 6250'. Kell up at 6250' and circulate bottoms u - max gas 41 units. Unable to rotate, work pipe and jar, finally came free with 260 klbs. Pull out of hole -lay down bent spiral HW. Test BOP's. Run in hole with BHA and pick up spiral HW. Logging Engineer: Wayne Hermanson /Mark Lindloff 10000 units = 100% Gas In Air : 14 ustomer: Pioneer Report No _ ''~'~ ``" ' ~~ . Well: Cronus #1 Date: 3/14/2006 sp®rry Qriiiing s®rvic®s Area: North Slope Depth 7528 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 415 Rig: Doyon Akita AF1 Rig Activity: Jarring Job No.: AK-AM-4253758 Report For: Brown / McDade Current 24 hr Avg 24 hr Max R.O.P. 0 ft/hr 60 ft/hr ( 175 ft/hr @ 7466 ) Gas" 43 units 110 unit: ( 255 units @ 7392 ) ( ) Cuttings sample Good x Pump and Flow Data Pumps 195 spm Flow rate 382 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2340 psi Mud Wt In 10.00 ppg Visc 74 secs NAP/H2O 57/32 % HTHP 4.2 ml Mud Wt at Max Gas 10.0 ppy ~Aud Wt Out 10.00 ppg PV 37 cP YP 17 Ibs/100ft2 Gels 10 \ 14 \ _ ES 441 Sd 0.3 Bit No.: 3 - 2rr1 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 ~"Jt On Bit: 13-16 RPM: 140 Hrs. On Bit: 6.9 Total Revs on Bit: 44.3 Footage for Bit Run 415 Trip Depth: 7113 ft Trip Gas: 54 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current ~ithology: 95 % Shale 5 % Sst % % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 7120 to 7180 222 75 18563 500 98 35 25 7259 to 7305 185 80 14245 556 176 64 44 7342 to 7418 255 80 20185 827 292 91 50 7435 to 7497 200 87 14483 746 324 125 98 24 hr Rec~ Run in hole to 6824' Pick u sin les and recautiona ream to bottom. Trip Gas 54 units. Drill 8 1/2" hole from 7113' to 7528' throu h a number of sand se uences: 7100'-7180'; 7260'-7305' and 7340'-7410'. Max gas over the sandstone intervals ranged from 185 to 255 units. Pipe became stuck while atempting to make a connection at 7528' . Pump 2 weighted walnut sweeps and jar on stuck pipe. Logging Engineer: Wayne Hermanson /Mark Lindloff 10000 units = 100% Gas In Air r- LILt ; 'T'om ~,.J Sperry ~riliing S®rvices Mudlogger's Morning Report ustomer: Pioneer Well: Cronus #1 Area: North Slope Lease: Exploration Rig: Doyon Akita AF1 Job No.: AK-AM-4253758 ~ Report No.: 15 Date: 3/15/2006 Depth 7528 Footage Last 24 hrs: 0 Rig Activity: Fishing Report For: Brown / McDade Current R.O.P. Gas* Cuttings sample ft/hr units Good 24 hr Avg ft/hr ( unit: ( ( x 24 hr Max ft/hr @ units @ ) ) ) Pump and Flow Data Pumps spm Flow rate Pump Capacity 1.979 Pump Liner & Strk 5X8 Pump Pres psi gpm gps in. Mud Wt In 9.90 ppg ~Aud Wt Out 9.90 ppg Visc 60 se PV 35 cP cs NAP/H20 65.5/31.5 % HTHP 4.4 ml Mud Wt at Max Gas 9.9 ppy YP 12 Ibs/100ft2 Gels 9 \ 14 \ ES 452 Sd 0.5 %, Bit No.: 3 - 2rr1 \-^Jt On Bit: 13-16 Type: RPM: DS70FNPV 140 Hrs. Bit Size: 8 1/2 On Bit: 6.9 Jets: 6 x 15 x Total Revs on Bit: 44.3 x TFA: 1.0350 Footage for Sit Run 415 Trip Depth: Short Trip Depth Tight Spots: to ft Trip Gas: ft Short Trip Gas: to Mud Cut: ppg Mud Cut: _ppg to Feet of Fill Trip CI: Short Trip CI: on Bottom: ppm ppm ft Current Lithology: ~5 ''o Shale 5 '~~~ Sst % % %LCM ft ft ft ft units units units units ppg ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ft units ft units ft units ppg ppg ppg ppg Depth Gas in units Max Background _ to _ to _ to to GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot 24 hr Rec~ Jar and work stuck pipe. Shut well in while conducting contraband search of camp and personnel. Rig up and run free point logs. Determine free point at 7434'. Pull out of hole with free point collar locator tools. Start running in with back-off charge. Logging Engineer: Wayne Hermanson /Mark Lindloff 10000 units = 100% Gas In Air ~ ~ ustomer: Pioneer Report No.: 16 `~~'~' ~"" '-`"` "~ Well: Cronus #1 Date: 3/16/2006 sp®rry or-i~l~n se g s®rvic®s Area: North Slope Depth 7528 ~ Lease: Exploration Footage Last 24 hrs: 0 Rig: Doyon Akita AF1 Rig Activity: Fishing e,x Job No.: AK-AM-4253758 Report For: Brown / McDade o .., o,~, Mudlogger's Morning Report ~~.~, Current 24 hr Avg 24 hr Max mo. Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) a ,w., Pumps spm Flow rate T gpm Gas` units unit: ( units @ ) Pump Capacity 1.979 gps ( ~ ) v Pump Liner & Strk 5X8 in. Cuttings sample Good x - e Pump Pres psi Mud Wt In 9.90 ppg Visc 68 secs NAP/H2O 68.5/31.5 % HTHP 4.4 ml Mud Wt at Max Gas 9.9 ppy P~~ud Wt Out 9.90 ppg PV 36 cP YP 14 Ibs/100ft2 Gels 10 \ 14 \ _ ES 440 Sd 0.5 Bit No.: 3 - 2rr1 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 ti^Jt On Bit: 13-16 RPM: 140 Hrs. On Bit: 6.9 Total Revs on Bit: 44.3 Footage for Bit Run 415 Trip Depth: ft Trip Gas: Mud Cut: ppg - Trip CI: ppm Short Trip Depth ~.,o ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ~ Current Lithulogy: 95 ~ ~ Shale 5 ~~ Sst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft _- units ppg ft units ppg _ ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to 24 hr Recs Run in with back-off charge and back off pi eat 7422'. Circulate bottoms u and pull out of hole. Rig up Baker wireline and run Mini Slam with orientation (DIL; ZDL; CN; GR; DIR & CAL) from 2501' to 7400'. POOH with logging tools and rig down Loggers. Start making up fishing tools. Slip & cut drill line. Logging Engineer: Wayne Hermanson /Mark Lindloff 10000 units = 100% Gas In Air ustomer: Pioneer Report No : 17 _ ~""`~", `~'~ Well: Cronus #1 . Date: 3/17/2006 Sperry Oril[ing s®rv~c®s Area: North Slope Depth 7528 udlogger's Morning Report Lease: Rig: Job No.: Exploration Doyon Akita AF1 AK-AM-4253758 Footage Last 24 hrs: Rig Activity: Report For: 0 POOH w/ fish Brown !McDade Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ Gas" 0 units 20 unit: ( 59 units @ Cuttings sample Good x Pump and Flow Data Pumps spm Flow rate gpm TG ) Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres psi Mud Wt In 9.90 ~Aud Wt Out 9.90 ppg ppg Visc 68 secs NAP/H20 68.5/31.5 % HTHP 4.4 ml PV 36 cP YP 14 Ibs/100ft2 Gels 10 \ 14 \ _ Mud Wt at Max Gas 9.9 ES 440 Sd ppg 0.5 °/, Bit No.: 3 - 2rr1 Type: Wt On Bit: 13-16 RPM: DS70FNPV Bit Size: 140 Hrs. On Bit: 8 1/2 Jets: 6 x 15 6.9 Total Revs on Bit: x 44.3 x TFA: Footage for Bit Run 1.0350 415 Trip Depth: Short Trip Depth Tight Spots: 7528 to ft Trip Gas: ft Short Trip Gas: to 49 Mud Cut: Mud Cut: to ppg Trip CI: _ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft Current Lith~logy: 95 % Shale 5 % Sst % % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec~ Make up BHA and run in hole. Screw into fish. Circulate and jar pipe (max gas 49 u) -pipe came free after approximately 8 hours of iarrinci. Circulate and reduce mud weight to 9.6 ppg with LVT. POOH with fish. Logging Engineer: Wayne Hermanson /Mark Lindloff 10000 units = 100% Gas In Air : 18 ustomer: Pioneer Re ort No ~'~' ' ` ' "` " `~ p . Well: Cronus #1 Date: 3/18/2006 Sp®rry Orilting Services Area: North Slope Depth 7630 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 102 Rig: Doyon Akita AF1 Rig Activity: Drill ahead Job No.: AK-AM-4253758 Report For: Brown / McDade Current 24 hr Avg 24 hr Max R.O.P. 63 ft/hr ft/hr ( 166 ft/hr @ 7617 ) Gas' 0 units 20 unit: ( 59 units @ TG ) ( ) Cuttings sample Good x Pump and Flow Data Pumps 208 spm Flow rate 409 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2276 psi Mud VVt In 9.60 ppg Visc 68 secs NAP/H20 73.3/26.7 % HTHP 4.4 ml Mud Wt at Max Gas 9.6 ppg Mud Wt Out 9.60 ppg PV 27 cP YP 12 Ibs/100ft2 Gels 8 \ 12 \ ES 504 Sd 0.5 °i, Bit No.: 4 - 2rr1 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 ~~Nt On Bit: 39002.00 RPM: 2 Hrs. On Bit: 1.7 Total Revs on Bit: 10.2 Footage for Bit Run 102 Trip Depth: 7528 ft Trip Gas: 33 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: ~~0 Shale 10 ,, Sltst ~, ^,,~GM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 7528 to 7630 173 123 13229 609 228 60 19 to to to 24 hr Rec~ POOH with fish. La down fishin BHA. Pick up new BHA & RIH. Drill 8 1/2" hole from to 7630' Logging Engineer: Wayne Hermanson /Mark Lindloff 10000 units = 100% Gas In Air : 19 ustomer: Pioneer Re ort No . p Well: Cronus #1 Date: 3/19/2006 Sp®rry Drilling S®rvic®s Area: North Slope Depth 7941 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 311 Rig: Doyon Akita AF1 Rig Activity: E-Log Job No.: AK-AM-4253758 Report For: Brown / McDade Current 24 hr Avg 24 hr Max R.O.P. 70 ft/hr 41.3 ft/hr ( 166 ft/hr @ 7617 ) Gas* 193 units 125 unit: ( 608 units @ 7289 ) ( ) Cuttings sample Good x Pump and Flow Data Pumps 203 spm Flow rate 400 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2260 psi Mud Wt In 9.60 ppg Visc 68 secs NAP/H2O 73.0/27.0 % HTHP 4.4 ml Mud Wt at Max Gas 9.6 ppg I\~lud Wt Out 9.60 ppg PV 31 cP YP 13 Ibs/100ft2 Gels 9 \ 14 \ ES 458 Sd 0.5 °i Bit No.: 4 - 3rr1 Type: DS70FNPV Bit Size: 8 1/2 Jets: 6 x 15 x x TFA: 1.0350 \1~t On Bit: 8-10 RPM: 80-120 Hrs. On Bit: 7.5 Total Revs on Bit: 10.2 Footage for Bit Run 1n2 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 7941 ft Short Trip Gas: 52 Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Gurrent Lithology: 100 % Shale ~, Sltst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 7600 to 7622 270 70 13195 617 230 59 19 7758 to 7776 608 78 46209 3375 957 314 48 to to 24 hr Rec~ Drill 8 1/2" hole from 7630' to 7941'. Intersect Ku aruk sand from 7758' to 7776' with a maximum as peak of 608 units. Circulate until hole clean. Wi er trip 7 stds. Circulate until hole clean with a maximum wiper trip gas of 52 units. Pull out of hole to run Logs. Rig up and start running wireline logs. Logging Engineer: Wayne Hermanson /Mark Lindloff 10000 units = 100% Gas In Air ustomer: Pioneer Report No : 20 AIt...ILM ,~„ Well: Cronus #1 . Date: 3/20/2006 Sp®rry Qrillir~g S®rvices Area: North Slope Depth 7941 udlogger's Morning Report Lease: Exploration Rig: Doyon Akita AF1 Job No.: AK-AM-4253758 Footage Last 24 hrs: 0 Rig Activity: E-Log Report For: Brown I McDade Current R.O.P. ft/hr Gas'` units Cuttings sample Good 24 hr Avg 24 hr Max ft/hr ( ft/hr @ unit; ( units @ ( x ) ) ) Pump and Flow Data Pumps spm Flow rate gpm Pump Capacity gps Pump Liner & Strk in. Pump Pres psi Mud Wt In 9.80 ppg Mud Wt Out 9.80 ppg Visc 70 secs NAP/H2O 65.0/24.0 % HTHP 4.4 ml Mud Wt at Max Gas ppg PV 33 cP YP 13 Ibs/100ft2 Gels 9 \ 14 \ ES 447 Sd 0.5 °4. Bit No.: Type: ~.Nt On Bit: RPM: Bit Size: Jets: x x x TFA: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: Short Trip Depth Tight Spots: to ft Trip Gas: Mud Cut: ppg Trip CI: ppm ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM ft units ft units ft units ft units Connection Gas and Mud Cut ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg Depth to to to to GAS PEAKS Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 24 hr Rec~ Run E-lo .Quad-Combo. Corin tool 1 & 2. M-Rex tool . Note: no gas to report. Logging Engineer: Wayne Hermanson /Eugene Payne 100 units = 100% Gas In Air : 21 ustomer: Pioneer Report No t-~#so-,IL.IL , ~ . Well: Cronus #1 Date: 3/21/2006 Sp®rry Qrilling SBrvicas Area: North Slope Depth 7941 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 0 Rig: Doyon Akita AF1 Rig Activity: Plug Back Job No.: AK-AM-4253758 Report For: Brown I McDatle Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ ) Gas" units 25 unit: ( 112 units @ TG ) ( ) Cuttings sample .Good x Pump and Flow Data Pumps spm Flow rate gpm Pump Capacity gps Pump Liner & Strk in. Pump Pres psi Mud Wt In 9.80 ppg Visc 72 secs NAP/H2O 73.0/27.0 % HTHP 4.4 ml Mud Wt at Max Gas 9.8 ppy Mud Wt Out 9.80 ppg PV 34 cP YP 14 Ibs/100ft2 Gels 9 \ 12 \ ES 434 Sd 0.5 °4 Bit No.: Type: Bit Size: Jets: x x _ x TFA: ~1!t On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec~ Finish wireline to in with corin tool. Ri down Lo ers. Run in hole ickin u 42 sin les of 2 7/8" tubin .Run in to bottom with 4' DP. Circulate hole clean -max as 122 units. Ri up Halliburton Cementers. Pump and displace cement plug #1 - bacground gas while pumping cement 25 units. Pull out of hole to set second cement plug. Logging Engineer: Wayne Hermanson /Eugene Payne 100 units = 100% Gas In Air r r ~ rN ~ ~ ~ ~ ~ r ~ rrrr, r ~ ~ r ~ r^^N Sperry- SV~ WELL NAME: Cronus # 1 LOCATION: North Slope OPERATOR; Pioneer Natural Resources AREA: Cronus Unit D R 1 L iL l N G 5 E R V 1 C fE 9 CONTRACTOR; Doyon/Akita Arctic Fox #1 STATE Alaska BIT RECORD BIT # Bit Type Bit Size Depth IN Depth OUT Footage Bit Hours TFA AVG ROP WOB RPM PUMP Press PUMP GPM TORQUE ftlKlbs MW ppg Krevs Bit Grade Remarks 1 STC XR+ 12.25" 89.0 2515.0 2417.0 24.7 0.7500 97.8 15.3 105 2250 500 2 8.9-9.5 73 2,2,WT,H,3,1,BT,TD Pull for TD 2 DS70FNPV 8.5" 2515.0 7113.0 4598.0 66.7 1.1800 68.9 12-12 138 3000 483 9.5-10.1 1,1,NO,A,X,1,NO,TW Twist off 2 stds from surface 3 DS70FNPV 8.5" 7113.0 7528.0 415.0 6.9 1.1800 60.1 10-12 130 3050 460 10.0 44.3 Stuck in hole -Fish 4 DS70FNPV 8.5" 7528.0 7941.0 413.0 7.6 1.1800 54.3 a-1o 120 3000 465 9.6 10.2 Total Depth • ~ ~ ~ ~r ~ <rs s ~r ~^~- rs ~, ~ s ~r ~ +~^~ ~s rr rr Sperry-S U C1 Drilling Services Water-based Mud Record Oil-based Mud Record Company: Pioneer Natural Resources Well: Cronus # 1 Rig: Doyon Akita Arctic Fox # 1 Mud Co.: Baroid Lease: Area: North Slope -Alaska Job No: AK-AM-0004253758 Spud Date: 01 Mar 2006 TD Date: 19 Mar 2006 Casing Record 16" CSC 98 ft MD 9 5/8" 2500 ft MD 7" Liner N/A Date Water Depth ft - MD Wt ppg Vis sec PV YP Ib/100 Gels Ib/100ft` Filt m/30m Rsoontsoo R200/R100/R6/R3 Cake 32nds Solids % Water % Sd % Pm pH MBT Pf/Mf Chlor ppm(k) Hard Ca++ Remarks 28-Feb 100 8.60 40 5 6 15.0 161111-/-/-I- 1 99 9.0 11.0 300 80 S ud makeu water 1-Mar 100 8.70 300 51 54 24/27/ 8.5 1561105184159/24/23 2 2.7 97 0.15 9.0 23.0 0.10/0.30 400 40 Ri u 2-Mar 1250 9.20 200 37 65 27/33/ 8.0 939/102/84/62/27/25 2 6.8 93 2.50 0.10 8.5 22.0 0.05/0.30 400 20 Drillin 12 1/4 hole 3-Mar 2300 9.50 98 30 49 17/30/ 7.4 109/79/66148116114 2 7.8 92 1.50 0.10 8.5 18.0 0.05/0.40 400 20 Drillin 12 1/4 hole 4-Mar 2515 9.50 103 35 42 15/22/ 5.5 112/77/62144/15113 2 7.8 92 0.75 8.3 17.0 -/0.40 400 20 TD 12 1/4 hole/ elo s 5-Mar 2515 9.50 97 36 43 15/23/28 5.4 115/79/59/44/15113 2 7.8 92 0.75 8.0 17.0 -/0.50 400 20 Run 9 5/8 casing Date Oil Depth ft - MD Wt pp Vis sec PV YP Ib/100 Gels Ib/100ft1 HTHP m/30m Rsoo/RSOO R200/R700/R6/R3 Cake 32nds Solids % NAP/ Water Sd % Alk Pom-m THTS cacl2 ppb WPS ppm ES volts ~cs/HOS °io/vo~ Remarks 6-Mar 2515 8.90 50 25 20 9/12/ 3.6 70145/35/24/9/7 1 32.o/s1.o 5.00 407 Nipple up/disp. to 8.9 oil mud 7-Mar 2515 8.90 90 27 19 11/14/ 3.6 73146137125/10/9 1 2.8 80.0/33.0 3.00 4.00 37.32 297,692 320 1.6/1.2 Trip in hole w/ 8 1/2 ass 8-Mar 3300 8.90 100 24 21 12/14/ 3.6 69/45/36/26111/10 1 3.0 80.0/34.0 0.25 5.10 5.40 39.79 250,305 363 1.1/1.9 Drilling 8.5" hole 9-Mar 4515 8.90 70 27 16 9/11/ 3.6 70/43/32/211817 1 2.7 so.o/3a.o 0.25 4.5 5.20 43.90 269,227 388 0.9/1.7 Short trip 10-Mar 5500 9.40 74 32 17 11/14/ 4.0 74/46/641221918 1 4.8 65.2/34.8 0.30 5.4 5.80 42.53 274,946 374 1.2/3.6 Drilling 8.5" hole 11-Mar 6650 9.80 78 36 19 10/14/ 4.4 91/55/41/27/918 1 6.7 65.6/34.4 0.50 4.40 6.00 42.53 281,320 412 2.3/4.5 Drilling 8.5" hole 12-Mar 7113 10.00 75 41 15 10/15/ 4.4 97/56/43/27/9/8 1 7.9 65.2/34.8 0.50 4.10 5.80 41.16 274,739 434 2.9/4.9 Fishing 13-Mar 7113 10.10 110 40 17 12/16/ 4.2 97/57/42/28/9/8 1 9.0 84.8/35.2 0.50 4.10 5.70 39.79 268,036 422 4.4/4.6 Trip in to complete hole 14-Mar 7528 10.00 74 37 17 10/14/ 4.2 91/54/40/26/9/8 1 7.8 s7.o/32.0 0.30 2.50 5.90 42.53 274,946 441 3.0/4.8 Drill /Stuck pipe 15-Mar 7528 9.90 66 35 12 9/14/ 4.4 82147136/21/8/7 1 7.9 s1.o/2s.o 0.50 3.10 6.70 39.79 288,469 452 3.3/4.6 Run free oint 16-Mar 7528 9.90 68 36 14 10/14/ 4.4 86150138/22/9/8 1 7.9 81.0/28.1 0.50 3.10 6.70 39.79 288,469 440 3.3/4.6 Retrieve pipe & E-Lo 17-Mar 7528 9.60 60 25 12 9/12/ 4.6 62/37127/1917/6 1 7.5 ss.o/2a.o 0.50 2.00 6.80 32.93 281,320 520 3.3/4.2 RIH -Free fish & POOH 18-Mar 7528 9.60 68 27 12 10/14/- 4.4 66/39/29/18/7/6 1 7.5 ss.o/2a.o 0.50 4.10 6.10 32.93 281,320 504 3.3/4.2 RIH/Drill 8.5" section 19-Mar 7941 9.80 68 31 13 9/14/- 4.4 75144/32/2017/6 1 8.4 ss.o/2a.o 0.50 4.40 5.80 34.30 289,647 458 3.8/4.6 Drill to TD, POOH 20-Mar 7941 9.80 70 33 13 9/14/- 4.4 79146134/2117/6 1 8.4 ss.o/2a.o 0.50 4.60 5.80 34.30 289,647 447 3.8/4.6 Wireline Lo in l l $per~-Sun ' DRILLING SERVICES Show Report Well Name: Cronus#1 Depth (MD) 2040 to 2100 ft Location: NORTH SLOPE (TVD) 2040 to 2100 ft Operator: PIONEER NATURAL RESOURCES Show Report No. 1 ~' Report Prepared By: Doug WilsoN Mark Lindloff Date/Time: 3/3!2006 Report Delivered To: Tavia Bicklein Interpretation: Oil show corresponds to marker at the top of Colville,. Sand: It brn - tn, opq-tins!, predom qtr, sbang-sbrnd, sft to Ise grn, uncons-prly cmt, pr porosity, 80% strong, bright yellow fluoresence, slow to moderate bright yellow cut. Good oil stain. ' GAS : Before / Max /After 50 units / 398 units /170 units ~, 1 % Depth 2040 ft Gas x Units # 398 Mud Chlorides (ppm) = NA --Flowline------ Suction -----Show ---------------------------------------------- Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 25 1 . . - 0.00 = 25.1 C1/C2 =###1t# C2 0 00 - 0 00 = 0 00 C1/C3 =## . . . ~ C3 0.00 - 0.00 = 0.00 C1/C4 =##### 1 C4 0.00 - 0.00 = 0.00 C1/C5 = NPH C5 0.00 - 0.00 = 0.00 Production 100.0 -- ~. Analysis Gas Oil Water xNon-Producible H drocarbons y 2 Depth # 2100 ft Gas x Units 167 Mud Chlorides ( m) = NA - --------: ----- ----------- Flowline §uction pp - ------------------------------------------------- §how Gas PPm pPm PPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 _ _ _ ~ _ _ _ _ _ ------- - ---- , C1 13 4 - 0 00 = 13 4 C1/C2 =##### . . . ' C2 0.00 - 0.00 = 0.00 C1/C3 =##### C3 0 00 - 0 00 = 0 00 C1/C4 =##~/## Oil . . . C4 0 00 - 0 00 = 0 00 C1/C5 =##### . . . i C5 0.00 - 0.00 = 0.00 ------------- NPH 1 0 `' Production Analysis Gas Oil Water xNon-Producible Hydrocarbons . -' 3 °i° Depth ft Gas x Units 604 Mud Chlorides (ppm) = NA - --Flowline------Suction ----- Show ---------------------------------------------- Hydrocarbon Ratios C1 C1 C1 C1 ' C2 C3 C4 C5 ppm ppm ppm ', (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 - 0 00 = 0 0 C1/C2 =## Y#i! . . . r C2 - 0 00 = 0 00 C1/C3 =##### . . C3 - 0.00 = 0.00 C1/C4 =##### NPH ' C4 - 0.00 = 0.00 C1/C5 =##### C5 - 0.00 = 0.00 ;: Production 100.0 _ -~ ' _ --------- Analysis Gas Oil Water Non-Producible Hydrocarbons - ,~ 4 Depth 8148 ft Gas x Units 1144 Mud Chlorides (ppm) = NA Gas Flowline Suction Show PPm Ppm pPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 - ,~ - - - - _ _ _ C1 - 0 00 = 0 0 C1/C2 =##### . . Oil C2 - 0.00 = 0.00 C1/C3 =##### C3 - 0 00 = 0 00 C1/C4 =##>~## . . C4 - 0 00 = 0 00 C1/C5 =##### - - - - - - - - . . 'i C5 - 0.00 = 0.00 ------------ NPH 1 0 ' Production Analysis Gas Oil Water Non-Producible Hydrocarbons . h ~ [ _ RaaJL~ry, i~. : ~ VF U ~C,1 sperry-Sun DRILLING SERVICES Show Report ili Well Name: Cronus#1 Depth (MD) 6268 to 6321 ft ~`~ Location: NORTH SLOPE (TVD) 6268 to 6321 ft Operator: PIONEER NATURAL RESOURCES Show Report No. 2 Report Prepared By: Doug Wilson/ Mark Lindloff Date/Time: 3/11/2006 Report Delivered To: Tavia Bicklein . i::N+:.y :f4A:....., A:, , Interpretation: Gas show corresponds to sand in Colville (Albian),. Sand: light to medium gray, very fine to fine grain, grading to siltstone,subangular to subround, unconsolidated, well sorted, very silty, noncalcareous, no fluorescence, no cut fluorescense. Siltstone -light to medium gray, -sandstone interbeds, carbonaceous specks and laminations I GAS : Before / Max /After 50 units / 523 units /120 units .:::, .'.3 :..i i 1 °i° °'~ Depth 6280 ft Gas x Units # 523 Mud Chlorides (ppm) - NA ~j ------------------ ------------ ------------------- ---------------------------- i Flowline Suction Show ~ f Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 ~ y I ( ) PPm PPm PPm li i Steam Still PPM's in 1000's H drocarbon Ratios 000 0 i C1 45 8 0 00 . __ I . - . = 45.8 C1/C2 = 33.6 i C2 1 37 - 0 00 = 1 37 C1/C3 = 108 3 . . . . - C3 0.42 - 0.00 = 0.42 C1/C4 = 405.3 C4 0.11 - 0.00 = 0.11 C1/C5 = 2410.5 NPH C5 0.02 - 0.00 = 0.02 Production 100.0 - _ ~ ~ = - Analysis Gas Oil Water xNon-Producible Hydrocarbons 2 Depth # 6282 ft Gas x Units 509 Mud Chlorides ( m) = NA - - - -- - --Flowline Suction - _ pp Show - -------------------------------------------- Gas :: PPm Ppn- Ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 0.0 __--- - - - ~ - _ ~~ C1 44 0 - 0 00 = 44 0 C1/C2 = 34 4 __ - ' . . . . - C2 1.28 - 0.00 = 1.28 C1/C3 = 111.5 - i :T C3 0 39 - 0 00 = 0 39 C1/C4 = 414 6 Oil __ - . . . . 11 - 0 C4 0 00 = 0 11 C1/C5 = 2441 7 - i . . . . C5 0.02 0.00 = 0.02 ------------------------------------------------------------------------ ------------ NPH 1 0 - I N.. ; Production Analysis Gas Oil Water xNon-Producible Hydrocarbons . 3 °i° Depth 6308 ft Gas x Units 503 Mud Chlorides (ppm) = NA Flowline------Suction ----- Show ---------------------------------------------- C C Hydroca 1 C 2 C rbon Ratio 1 3 s C1 C C4 C i 1 5 ppm ppm ppm ~ (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 43 5 - 0 00 = 43 5 C1/C2 = 30 7 . _ . . . . C2 1.42 - 0.00 = 1 42 C1/C3 = 101 1 " . . ~ i' C3 0.43 - 0.00 = 0.43 C1/C4 = 395.3 NPH C4 0.11 - 0.00 = 0.11 C1/C5 2070.5 - - C5 0.02 - --- 0.00 = --- 0.02 -- -- ---------- ----------------------------------------------- sl' Production --- - ! 100.0 _ - -' ~ ------- I) ~il~ Analysis Gas Oil Water xNon-Producible Hydrocarbons -- I;I iii 4 -- Depth 6314 ft Gas x Units 532 Mud Chlorides (ppm) = NA Gas - --_ Flowline Suction Show PPm PPm PPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 - _ _ . _ . _ _ _ i; C1 45 2 - 0 00 = 45 2 C1/C2 = 33 7 . . . . - - Oil C2 1.34 - 0.00 = 1.34 C1/C3 = 107.6 42 - 0 C3 0 00 = 0 42 C1/C4 = 393 0 . . . . C4 0 12 - 0 00 = 0 12 C1/C5 = 2151 9 i - - - - . . . . C5 0.02 - 0.00 = 0.02 ------------------------------ --------------------------------- ------"--"'- NPH Production Analysis Gas Oil Water xNon-Producible Hydrocarbons i.. ... ,:. .N .. ~~',r::. ::. . ... .. .:... ~. ,Iii.:..:..... :..:....::::.:... .: i : ~'. ' 1 s pe rl'~/-sun ..l! l 1~~:: . ~. Well Name: Cronus #1 Depth (MD) 6790 co 7020 ft DRILLING SERVICES Show Report Location: NORTH SLOPE (TVD) 6790 to 7020 ft Operator: PIONEER NATURAL RESOURCES Show Report No. 3 Report Prepared By: Doug Wilson/ Mark Lindloff Date/Time: 3/12/2006 Report Delivered To: Tavia Bicklein I Interpretation: Gas show corresponds to sandstone in Colville Turbidite at 6942-6958' MD =Sandstone-light graywhite,light gray, tan, very fine to fine grain, angular to subangular, moderately sorted, friable to very firm, calcareaous in part, quartz, argillaceous,silty, sme carbonaceous specks, 5-10% visual porosity in part, chalky lithic matrix, very dull gold sample fliorescence, fair milky very dull gold GAS : Before / Max /After 50 units / 523 units /120 units cut fluorescence 1 % Hydrocarbon Ratios Depth 6790 ft Gas x Units # 523 Mud Chlorides (ppm) = NA C1 C1 C1 C1 --Flowline------ Suction ----- Show ------------------------------------"--------- C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 2.0 - 0.00 = 2.0 C1/C2 = 21.5 . C2 0.09 - 0.00 = 0.09 C1/C3 = 43.5 C3 0.05 - 0.00 = 0.05 C1/C4 = 95.2 C4 0.02 - 0.00 = 0.02 C1/C5 = 1000.0 NPH C5 0.00 - 0.00 = 0.00 ! ------------------------------------------------------------------------------------ Product!on 100.0 _ Analysis Gas Oil Water xNon-Producible Hydrocarbons ~ i ~ 2 % I~ Depth # 6850 ft Gas x Units 509 Mud Chlorides (ppm) = NA Flowline Suction Show Gas ~ PPm PPm PPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 C1 3.4 - 0.00 = 3.4 C1/C2 = 22.7 ! C2 0.15 - 0.00 = 0.15 C1/C3 = 53.1 C3 0.06 - 0.00 = 0.06 C1/C4 = 141.7 Oil ; C4 0.02 - 0 00 = 0 02 C1/C5 = 1700 0 ! - - - - - - - - - - . . . C5 0.00 - 0.00 = 0.00 NPH - ---------------------------------------------------------------------------------- 1 0 Production . Analysis Gas OII Water xNon-Producible Hydrocarbons s % Hydroca rbon Ratios Depth 6950 ft Gas x Units 503 Mud Chlorides (ppm) = NA C1 C 1 C1 C 1 ------------------ ---------------------------------------------------------------- Flowline Suction Show - - C2 C - - 3 C4 C 5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 9 8 - 0 00 = 9 8 C1/C2 = 22 2 . . . . . C2 0.44 - 0.00 = 0.44 C1/C3 = 49 2 _ . C3 0.20 - 0.00 = 0.20 C1/C4 = 144.8 NPH ~ - C4 0.07 - 0.00 = 0.07 C1/C5 = 1407.0 ~ i - C5 0.01 - 0.00 = 0.01 . ------------------------------------------------------------------------------------ Product!on 100.0 ~ Analysis Gas Oil Water xNon-Producible Hydrocarbons . - ~ -- 4 % i Depth 7002 ft Gas x Units 532 Mud Chlorides (ppm) = NA Gas ------------------ ------------ ------------------------------------------------- Flowlme Suction Show _ _ _ _ - - PPm pPm PPm _ _ _ _ _ _ (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 1 9 1 - 0 00 = 9 1 C1/C2 = 28 8 - - _ ---- ------ __ . . . . _ C2 Oil 0.32 - 0.00 = 0.32 C1/C3 = 77.1 i _ C3 0.12 - 0.00 = 0 12 C1/C4 = 239 4 - . . C4 0.04 - 0.00 = 0 04 C1/C5 = 2274 3 - - - - - ~ - - . . C5 0.00 - 0.00 = 0.00 NPH - - ---------------------------- --------------------------------------------- 1 0 Production . Analysis Gas Oil Water xNon-Producible Hydrocarbons i ~~rss;:::,::;u:... m;, {.! N ~ "! i ~ 4q :n ~ .. !. ..i e y I !. ~ i !...,, i ; u.;- I Ii~i~4: ~~ r ie ' sperry-SU11 DRILLING SERVICES Show Report '!:'Liilei!!i!i!ii Well Name: Cronus#1 Depth (MD) 7120 to 7180 ft Location: NORTH SLOPE (ND) 7120 to 7180 ft Operator: PIONEER NATURAL RESOURCES Show Report No. 4 Report Prepared By: Wayne Hermanson/ Mark Lindloff Date/Time: 3!14/2006 Report Delivered To: Tavia Bicklein Interpretation: Gas show corresponds to sandstone over interval 7120'-7180' Sandstone: white to light gray, very fine to fine ~ rained, an ular to sub an ular, well sorted, calcareous cement, ve friable to soft, abundant carbonaceous flecks in art, '' 9 9 9 ry p poor to fair por, instantaneous pale blue white cut florescence. GAS : Before / Max /After 82 units / 222 units / 87 units cut fluorescence P 1 °i° I I Depth 7143 ft Gas x Units # 192 Mud Chlorides (ppm) = NA i! ------------------------------------------------------------------------------------ ,;, Flowline Suction Show i Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 i ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 16 4 0 00 1 . _ . - . = 6.4 C1/C2 = 38.1 - C2 0 43 - 0 00 = 0 43 C1/C3 = 210 3 . . . . C3 0.08 - 0.00 = 0.08 C1/C4 = 607.4 C4 0.03 - 0.00 = 0.03 C1/C5 = 781.0 NPH C5 0.02 - 0.00 = 0.02 Production 100.0 _ Analysis x Gas x Oil Water Non-Producible Hydrocarbons ~ -- 2 Depth # 7157 ft Gas x Units 222 Mud Chlorides (ppm) = NA Flowline Suction Show Gas ~~ PPm PPm PPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 _ _ - - - - - _ _ C1 18 6 - 0 00 = 18 6 C1/C2 = 36 9 . . . . C2 0.50 - 0.00 = 0.50 C1/C3 = 189.4 C3 0 10 - 0 00 = 0 10 C1/C4 = 530 4 Oil -- . . . . C4 0 04 - 0 00 = 0 04 C1/C5 = 742 5 . . . . C5 0.03 - --- 0.00 = --- 0.03 ------------- NPH 1 0 ~ i :< " Production Analysis x Gas x Oil Water Non-Producible Hydrocarbons . I s °i° Depth ft Gas x Units Mud Chlorides (ppm) = --Flowline------Suction ----- Show ---------------------------------------------- C C Hydroca 1 C 2 C rbon Ratio 1 3 s C1 C C4 C 1 5 !, ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 - = C1/C2 = . C2 - = C1/C3 = C3 - = C1/C4 = NPH C4 - = C1/C5 = C5 - _ ' Production ! ' 100.0 - ~~ - - ~ Analysis Gas Oil Water Non-Producible Hydrocarbons - - 4 Depth ft Gas x Units Mud Chlorides (ppm) = Gas Flowline Suction Show - ~ - PPm PPm PPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 _ _ _ _ _ _ _ _ - C1 - = C1/C2 = _ - - - - Oil C2 - = C1/C3 = C3 - = C1/C4 = C4 - = C1/C5 = - - - C5 - = ------------------------------ --------------------------------------------- NPH 1 0 - r Production Analysis Gas Oil Water Non-Producible Hydrocarbons c!!i e~iN'~if : '.:..•... ..a..a•. i i ~ ' . ~ !': a!, k' r !~!! . . ~. .:.::.:.... f ~iili:e'%3.. .: is : !y,.. .. ..:::.....::M...........::.r:: .. i....~....r... n.... .: .(:. Y'u~i: I;:::i.I:....:::...:~~!:'r:!::!:!::.:....: i.,^; !ji:ur^..rr,y!'iF. ! sperry-$1111 DRILLING SERVICES Show Report ~111~::31ii;iiLi!rl!lii!.iii'.!.;i~ H!!. I; ~ i ! i~.{Ilil y I: Well Name: Cronus #1 Depth (MD) 7259 to 7497 ft Location: NORTH SLOPE (TVD) 7259 to 7497 ft Operator: PIONEER NATURAL RESOURCES Show Report No. 5 Report Prepared By: Wayne HermansoN Mark Lindloff Datelfime: 3/14/2006 Report Delivered To: Tavia Bicklein Interpretation: Gas show corresponds to sandstone over interval 7259'-7418' Sandstone: white to light gray, very fine to fine grained, angular to sub angular, well sorted, calcareous cement, very friable to soft, abundant carbonaceous flecks in part, poor to fair por, fluoresence contaminated by oil base mud, instantaneous bright Yellow cut florescence. GAS : Before / Max /After 80 units / 255 units / 88 units 1 Depth 7289 ft Gas x --Flowline------Suction ----- S °i° Units # 185 Mud Chlorides (ppm) = NA how ---------------------------------------------- Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 14 3 0 00 . __ . - . = 14.3 C1/C2 = 25.6 - ~ C2 0.56 - 0.00 = 0.56 C1/C3 = 81.0 C3 0.18 - 0.00 = 0.18 C1/C4 = 222.7 _ -- ~~ ; C4 0.06 - 0.00 = 0.06 C1/C5 323.9 NPH ~. C5 0.04 - --- 0.00 = --- 0.04 Production Analysis x Gas x Oil Water Non-Producible Hydrocarbons 100.0 - -- .._~ _- - ~ ~ . _ it 2 % Depth - #- 7355- ft--Gas x Units 216 Mud Chlorides (ppm) = NA _ _ -- Flowline Suction Show - -------------------------------------------- PPm PPm PPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios s 10.0 ~ ---- - __ - - - - - - - - - C1 17.0 - 0.00 = 17.0 C1/C2 = 25.2 ---- _ _ __ -- C2 0.67 - 0.00 = 0.67 C1/C3 = 72.2 -_ C3 0 24 - 0 00 = 0 24 C1/C4 = 223 1 Oil _ . . . . C4 0 08 - 0 00 = 0 08 C1/C5 = 368 6 -- . . . . C5 0.05 - 0.00 = 0.05 ---------------------------------------------------------------------- -------------- NPH 1 0 ~ Production Analysis x Gas x Ufl Water Non-Producible Hydrocarbons . s °i° Depth 7392 ft Gas x Units 255 Mud Chlorides (ppm) = NA ------------------ ---------------------------------------------------------------- Flowlme Suction Show C - C Hydrocarbon Ratio 1 C1 - 2 C3 s C1 C - - C4 C 1 5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 20.2 - 0.00 = 20.2 C1/C2 = 24.4 . _ _ C2 0.83 - 0.00 = 0.83 C1/C3 = 69 1 . C3 0.29 - 0.00 = 0.29 C1/C4 = 221.8 NPH C4 0.09 - 0.00 = 0.09 C1/C5 = 403.7 - ~ C5 0.05 - 0.00 = 0.05 ------------------------------------------------------------------------------------ Production !I!i Analysis x Gas x Uil Water Non-Producible Hydrocarbons 100.0 - ~ - _ -- _ -- 4 /o ° l Depth 7480 ft Gas x Units 200 Mud Chlorides (ppm) = NA Flowline §uction §how PPm PPm PPn~ (Steam Still PPM's in 1000's) Hydrocarbon Ratios Gas 10,0 l r __- _ - - - - - _ --_ _ - -,_~_ - - C1 14 5 - 0 00 = 14 5 C1/C2 = 19 4 . . . . Oil C2 0.75 - 0.00 = 0.75 C1/C3 = 44.7 C3 0.32 - 0 00 = 0 32 C1/C4 = 115 9 - . . . C4 0 13 - 0 00 = 0 13 C1/C5 = 147 8 ~ - - - - ~~ . . . . C5 0.10 - 0.00 = 0.10 ------------------------------ --------------------------------------------- NPH 1 0 Production Analysis x Gas x Oil Water Non-Producible Hydrocarbons Hi? leeeei:!~:i i!!~ii ~ ~ I : i i i:l ~ °j!.' ii 1 : 1 ) ~ ~ { Y ~ . i ' i !yl^ $ . 3] : :!:: : .i::l. .i{ 1 .i.n.r~Y:N; ,S : i. iiiip Y~!~ e :!.!II : :I i :i: i : ::: ii.:i Sper~-Sun DRILLING SERVICES Show Report Well Name: Cronus#1 Depth (MD) 7758 to 7776 ft Location: NORTH SLOPE (TVD) 7758 to 7776 ft '' Operator: PIONEER NATURAL RESOURCES Show Report No. 6 Report Prepared By: Wayne HermansoN Mark Lindloff Date/Time: 3/19/2006 Report Delivered To: Tavia Bicklein InterpretatlOn: Gas show corresponds to sandstone over interval 7758'-7776' Sandstone: buff to light brown, very fine to course grained, sub round to angular, poorly sorted, calcareous & clay matrix in part, abundant glauconite and pyrite, friable to moderately cemented, dull orange sample fluorescence, pale yel cut florescence which may be mostly from oil base mud. GAS : Before / Max /After 78 units / 608 units / 150 units 1 °i° ~ Depth 7289 ft Gas x Units # 185 Mud Chlorides (ppm) = NA --Flowlirie------ Suction ----- Show ---------------------------------------------- Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 46 2 0 . - . .00 = 462 C1/C2 = 13.7 C2 3 38 - 0 00 = 3 38 C1/C3 = 47 7 . . . . C3 0.97 - 0.00 = 0.97 C1/C4 = 215.9 '~ C4 0.21 - 0.00 = 0.21 C1/C5 = 962.7 NPH rv C5 0.05 - 0.00 = 0.05 Production 100.0 -- ~ ~ ~ . ---------------- ~ Analysis x Gas Oil Water Non-Producible H drocarbons y '' 2 Depth ft Gas x Units Mud Chlorides ( m) _ ------------------ ---------- Flowlme Suction - _--------- - pp ------ Show - ------ Gas PPm PPm PPm " (Steam Still PPM's in 1000's) Hydrocarbon Ratios 0.0 - _ . _. _ . ----- ... . ------ -- - -- _ _ C1 - = C1/C2 = '' C3 - = C1/C4 = Oil C4 - = C1/C5 = ~~ C5 - = ------------------------------------------------------------------------------------ NPH 1 0 r Production Analysis Gas Oil Water Non-Producible Hydrocarbons . a % Depth 7392 ft Gas x Units 255 Mud Chlorides (ppm) = NA Flowlme Suction Show Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 - = C1/C2 = . C2 - = C1/C3 = - C3 - = C1/C4 = NPH '' C4 - = C1/C5 = C5 - _ Production 100.0 -' ~ --------------- Analysis Gas Oil Water Non-Producible Hydrocarbons i 4 Depth ft Gas x Units Mud Chlorides (ppm) = Gas Flowlme Suction Show PPm ppm ppm (Steam. Still PPM's in 1000's) Hydrocarbon Ratios 10.0 _ . - - - -------- _ _ _ ---- C1 - = C1/C2 = Oil C2 - = C1/C3 = C3 - = C1/C4 = C4 - = C1/C5 = -- ---- ` C5 - = -----------°----------------- -------------------------------- ------------- NPH 1 0 Production Analysis Gas Oil Water Non-Producible Hydrocarbons Y, . • Pioneer Natural Resources 5 0 0 Spud well at 89' MD I I, 1000 1 1,/4" dole i I 2000 - - --~5/8" CSG a~-2-500 ft MD- 3000 - ~' 1 8 1/2" Hole 4000 - - i, --~b-ctu I ft 50001 - Pro nosed 6000 - I 1 7000 I 1. ~ _ , _, i 941' MD 7921' TVD 1 ' ~~ 8000 . i 9000 10000 • days Cronus # 1 10 15 20 25 30 • • Cronus 1 directional surveys from Baker-final.txt PIONEER NATURAL RESOURCES CRONUS #1 PAGE DRIFT COORDINATES DEVI ATION STAT ION TOTAL DEPTH ANGLE AZIMUTH T.V.D. N-S E-W N-5 E-W 100.00 .3 296.3 100.00 .OON .00E .OON .00E 150.00 .4 343.3 150.00 .33N .12E .33N .12E 200.00 .0 30.2 200.00 .31N .21w .64N .09w 250.00 .3 64.9 250.00 .07N .20E .70N .10E 300.00 .3 44.8 299.99 .22N .23E .92N .33E 350.00 .3 40.0 349.99 .16N .17E 1.09N .51E 400.00 .3 63.6 399.99 .23N .40E 1.32N .90E 450.00 .5 55.1 449.99 .19N .21E 1.52N 1.12E 500.00 .l 272.7 499.99 .23N .llw 1.74N 1.00E 550.00 .4 70.9 549.99 .025 .08E 1.73N 1.08E 600.00 .5 39.1 599.99 .13N .32E 1.86N 1.41E 650.00 .5 32.8 649.98 .44N .24E 2.29N 1.65E 700.00 .4 22.8 699.98 .28N .12E 2.57N 1.77E 750.00 .2 34.1 749.98 .25N .11E 2.83N 1.88E 800.00 .5 138.1 799.98 .Ols .11E 2.82N 1.99E 850.00 .8 129.2 849.98 .215 .34E 2.61N 2.33E 900.00 .8 131.6 899.97 .465 .56E 2.14N 2.89E 950.00 .9 134.2 949.97 .525 .53E 1.62N 3.42E 1000.00 .9 141.2 999.96 .595 .53E 1.04N 3.95E 1050.00 1.1 144.3 1049.96 .695 .53E .35N 4.48E 1100.00 1.1 144.9 1099.95 .805 .52E .455 4.99E 1150.00 1.5 147.3 1149.93 .975 .67E 1.425 5.66E 1200.00 1.4 152.4 1199.92 1.105 .62E 2.525 6.28E 1250.00 1.4 157.9 1249.90 1.135 .48E 3.655 6.76E 1300.00 1.5 160.7 1299.88 1.225 .51E 4.875 7.27E 1350.00 1.5 163.4 1349.87 1.205 .39E 6.075 7.66E 1400.00 1.4 162.8 1399.85 1.205 .37E 7.285 8.03E 1450.00 1.5 163.9 1449.84 1.205 .34E 8.475 8.37E 1500.00 1.5 154.8 1499.82 1.225 .45E 9.705 8.82E 1550.00 1.6 154.8 1549.80 1.245 .64E 10.945 9.46E 1600.00 1.6 158.6 1599.78 1.285 .54E 12.215 10.00E 1650.00 1.5 160.2 1649.76 1.275 .50E 13.485 10.51E 1700.00 1.5 158.7 1699.74 1.255 .47E 14.745 10.97E 1750.00 1.4 163.8 1749.73 1.225 .41E 15.965 11.38E 1800.00 1.4 166.2 1799.71 1.175 .32E 17.135 11.71E 1850.00 1.5 160.8 1849.70 1.205 .35E 18.335 12.06E 1900.00 1.4 167.5 1899.68 1.225 .34E 19.555 12.39E 1950.00 1.5 160.3 1949.66 1.245 .37E 20.785 12.76E 2000.00 1.4 167.0 1999.65 1.255 .35E 22.035 13.11E 2050.00 1.5 164.6 2049.63 1.255 .32E 23.285 13.43E 2100.00 1.6 163.2 2099.61 1.285 .33E 24.565 13.76E 2150.00 1.5 167.5 2149.60 1.285 .25E 25.835 14.01E 2200.00 1.5 166.0 2199.58 1.275 .30E 27.115 14.31E 2250.00 1.4 166.6 2249.56 1.225 .37E 28.335 14.68E 2300.00 1.4 166.4 2299.55 1.186 .19E 29.515 14.88E 2350.00 1.3 169.7 2349.53 1.135 .24E 30.645 15.12E 2400.00 1.2 172.0 2399.52 1.075 .18E 31.715 15.30E 2450.00 1.1 176.7 2449.51 1.025 .11E 32.735 15.41E 2508.00 1.4 154.1 2507.50 1.195 .34E 33.935 15.75E 2550.00 1.4 151.3 2549.49 .905 .50E 34.825 16.25E 2600.00 1.4 150.0 2599.47 1.075 .59E 35.895 16.84E Page 1 • Cronus 1 directional surveys from Baker-final.txt 00 2650 1.2 152.9 2649.46 1.025 .54E 36.915 17.38E . 00 2700 1.1 155.0 2699.45 .925 .45E 37.836 17.83E . 00 2750 .9 159.2 2749.44 .825 .32E 38.655 18.16E . 00 2800 .8 160.7 2799.43 .725 .27E 39.375 18.42E . 00 2850 .7 160.0 2849.43 .615 .22E 39.985 18.64E . 00 2900 .7 165.2 2899.43 .575 .19E 40.556 18.83E . 00 2950 .6 168.6 2949.42 .535 .14E 41.095 18.97E . 00 3000 .6 169.7 2999.42 .505 .11E 41.595 19.08E . 00 3050 .5 171.4 3049.42 .475 .10E 42.075 19.18E . 00 3100 .4 174.3 3099.42 .425 .05E 42.495 19.23E . 00 3150 .4 172.2 3149.41 .345 .03E 42.835 19.25E . 00 3200 .3 168.0 3199.41 .305 .05E 43.145 19.30E . 00 3250 .3 164.2 3249.41 .295 .06E 43.435 19.36E . 00 3300 .4 167.8 3299.41 .315 .07E 43.745 19.43E . 00 3350 .4 178.1 3349.41 .355 .05E 44.095 19.49E . 00 3400 .4 183.6 3399.41 .375 .01E 44.475 19.50E . 00 3450 .4 180.2 3449.41 .345 .Olw 44.815 19.48E . 00 3500 .4 176.7 3499.41 .335 .OlE 45.145 19.49E . 00 3550 .4 179.4 3549.41 .345 .OOw 45.485 19.49E . 00 3600 .4 181.1 3599.40 .375 .01E 45.845 19.50E . 00 3650 .5 175.8 3649.40 .405 .02E 46.245 19.52E . 00 3700 .6 184.3 3699.40 .455 .OOW 46.695 19.52E . 00 3750 .6 190.4 3749.40 .515 .06W 47.216 19.46E . 00 3800 .6 196.8 3799.39 .545 .llW 47.745 19.35E . 00 3850 .7 206.3 3849.39 .565 .21w 48.305 19.13E . 00 3900 .8 218.6 3899.39 .555 .36w 48.855 18.77E . 00 3950 .9 228.8 3949.38 .535 .52w 49.385 18.25E . 00 4000 1.0 234.2 3999.37 .505 .65W 49.885 17.60E . 4050 00 1 1 239.3 4049.37 .505 .75w 50.395 16.84E . 00 4100 . 1.2 243.6 4099.36 .465 .85w 50.855 15.99E . 00 4150 1.2 249.0 4149.35 .435 .94w 51.285 15.05E . 00 4200 1.3 252.3 4199.33 .385 1.04W 51.665 14.01E . 00 4250 1.4 255.6 4249.32 .345 1.16W 52.015 12.85E . 00 4300 1.6 258.3 4299.30 .315 1.28w 52.315 11.57E . 00 4350 1.6 260.3 4349.28 .255 1.36w 52.565 10.21E . 00 4400 1.6 263.6 4399.26 .195 1.40W 52.755 8.81E . 00 4450 1.6 266.0 4449.24 .145 1.42W 52.895 7.39E . 00 4500 1.6 269.7 4499.22 .065 1.44w 52.955 5.95E . 00 4550 1.7 272.1 4549.20 .O1N 1.46w 52.945 4.50E . 00 4600 1.7 274.1 4599.18 .08N 1.50w 52.875 3.00E . 00 4650 1.8 276.9 4649.16 .15N 1.51w 52.725 1.49E . 00 4700 1.8 279.4 4699.13 .21N 1.54W 52.515 .04w . 00 4750 1.9 281.5 4749.11 .27N 1.57w 52.245 1.61w . 00 4800 1.9 282.4 4799.08 .32N 1.61W 51.915 3.22W . 00 4850 2.0 282.6 4849.05 .37N 1.66W 51.545 4.88w . 00 4900 2.1 284.5 4899.02 .42N 1.73w 51.125 6.60w . 00 4950 2.2 288.0 4948.98 .52N 1.81W 50.595 8.41W . 00 5000 2.4 290.7 4998.94 .66N 1.91W 49.945 10.32w . 00 5050 2.6 293.4 5048.89 .84N 2.05W 49.105 12.37W . 00 5100 2.9 296.6 5098.83 1.04N 2.20W 48.065 14.57W . 00 5150 3.2 299.5 5148.76 1.25N 2.35W 46.805 16.92W . 00 5200 3.5 302.1 5198.68 1.48N 2.51W 45.325 19.43w . 00 5250 3.8 303.3 5248.58 1.70N 2.67w 43.625 22.1OW . 00 5300 4.0 304.0 5298.46 1.89N 2.83w 41.735 24.92w . 00 5350 4.3 305.3 5348.33 2.06N 2.98W 39.675 27.91W . 00 5400 4.6 305.7 5398.18 2.24N 3.14W 37.435 31.05W . 00 5450 4.8 306.4 5448.01 2.43N 3.32w 35.005 34.37w . 00 5500 4.9 306.8 5497.83 2.54N 3.42W 32.455 37.80W . 00 5550 4.9 306.2 5547.65 2.54N 3.43w 29.915 41.23w . 00 5600 4.9 306.4 5597.46 2.53N 3.43w 27.385 44.66w . 00 5650 5.0 306.1 5647.28 2.55N 3.49w 24.825 48.15w . 00 5700 5.0 305.1 5697.09 2.53N 3.54w .22.295 51.69w . 5750.00 5.0 305.5 5746.89 2.54N 3.56W 19.765 55.25W Page 2 • • Cronus 1 directional surveys from Baker- final.txt 5800.00 4.9 305.8 5796.70 2.53N 3.54w 17.225 58.79w 5850.00 5.1 306.4 5846.51 2.58N 3.53w 14.645 62.32w 5900.00 5.2 307.0 5896.31 2.69N 3.60w 11.955 65.92w 5950.00 5.4 307.5 5946.09 2.83N 3.69w 9.125 69.61w 6000.00 5.7 308.5 5995.86 2.99N 3.80w 6.145 73.41w 6050.00 5.9 309.5 6045.61 3.16N 3.91w 2.985 77.32w 6100.00 6.1 310.3 6095.33 3.34N 4.OOw .35N 81.32w 6150.00 6.2 311.5 6145.05 3.50N 4.03w 3.85N 85.35w 6200.00 6.2 312.4 6194.76 3.61N 4.02w 7.46N 89.37w 6250.00 6.3 313.2 6244.46 3.71N 4.02w 11.17N 93.39w 6300.00 6.4 313.5 6294.15 3.81N 4.04W 14.99N 97.44w 6350.00 6.6 314.5 6343.83 3.91N 4.05w 18.90N 101.49w 6400.00 6.7 315.8 6393.50 4.06N 4.06w 22.96N 105.55W 6450.00 6.8 316.9 6443.15 4.24N 4.06w 27.20N 109.60w 6500.00 7.0 318.5 6492.79 4.45N 4.06w 31.64N 113.66w 6550.00 7.0 319.9 6542.41 4.62N 4.OOW 36.26N 117.66W 6600.00 7.2 321.2 6592.03 4.81N 3.93w 41.08N 121.59W 6650.00 7.3 322.5 6641.62 4.98N 3.89w 46.05N 125.48w 6700.00 7.1 323.2 6691.23 5.O1N 3.77w 51.07N 129.25w 6750.00 6.8 324.2 6740.86 4.88N 3.59w 55.95N 132.84w 6800.00 7.0 325.5 6790.50 4.90N 3.44W 60.84N 136.28w 6850.00 7.0 327.0 6840.13 5.04N 3.39w 65.89N 139.67w 6900.00 7.1 328.1 6889.75 5.20N 3.29w 71.09N 142.96w 6950.00 7.3 329.6 6939.35 5.39N 3.26w 76.48N 146.22w 7000.00 7.4 331.2 6988.94 5.54N 3.16w 82.02N 149.38w 7050.00 7.7 332.1 7038.52 5.76N 3.09w 87.78N 152.47w 7100.00 7.7 333.1 7088.06 5.95N 3.OSw 93.73N 155.55w 7150.00 7.7 334.0 7137.61 6.OON 3.OOw 99.73N 158.55w 7200.00 7.9 335.2 7187.15 6.15N 2.92w 105.88N 161.47w 7250.00 8.1 336.3 7236.66 6.36N 2.87w 112.24N 164.34w 7300.00 8.1 337.6 7286.16 6.47N 2.77w 118.71N 167.1iw 7350.00 8.3 340.2 7335.64 6.70N 2.53w 125.41N 169.64w 7400.00 8.4 341.1 7385.11 6.84N 2.44W 132.25N 172.08W 7450.00 8.6 342.2 7434.57 6.99N 2.32W 139.24N 174.41W 7500.00 8.8 343.2 7484.00 7.19N 2.22w 146.43N 176.62w 7550.00 8.8 343.9 7533.41 7.35N 2.20w 153.77N 178.83w 7600.00 8.6 345.4 7582.83 7.28N 2.OlW 161.05N 180.84w 7650.00 8.5 346.5 7632.28 7.22N 1.78w 168.27N 182.62w 7700.00 8.6 347.5 7681.72 7.24N 1.67w 175.51N 184.28w 7750.00 8.6 349.1 7731.16 7.33N 1.53w 182.84N 185.81w 7800.00 8.4 350.5 7780.61 7.27N 1.31W 190.11N 187.12w 7850.00 8.3 352.0 7830.08 7.17N 1.12w 197.28N 188.24w 7900.00 8.2 350.3 7879.57 7.04N 1.05w 204.32N 189.29w 7942.00 8.2 350.3 7921.14 5.89N 1.Olw 210.21N 190.30w THE FIRST POINT INFORMATION: 100.00 .3 296.3 100.00 .OON .00E .OON .00E THE LAST POINT INFORMATION: 7942.00 8.2 350.3 7921.14 5.89N 1.Olw 210.21N 190.30w FINAL EAST-WEST DRIFT = 190.30 W FINAL NORTH-SOUTH DRIFT = 210.21 N FINAL DRIFT DISTANCE = 283.55 FT FINAL DRIFT DIRECTION = N 42.15 W Page 3 Cronus #1, API # 50-103-20523 CONTCNTS: 1 set Color Logs 1" / 100' Engineering Log l" / 1000' Well Diagram Pore Pressure Log 1 Data CD Digital data IJMF & PDF's