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THE STATE °fALASKA July 24, 2019 GOVERNOR MIKE DUNLEAVY Ms. Lindsay Wright SEQ Specialist and Land Technician ENI US Operating Co Inc 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503-5818 Re: Location Clearance Rock Flour #2 (PTD 2061660) Rock Flour #3 (PTD 2070050) Maggiore #1 (PTD 2070060) Nikaitchuq #1 (PTD 2040180) Nikaitchuq #2 (PTD 2040380) Nikaitchuq #3 (PTD 2042600) Nikaitchuq #4 (PTD 2050010) Dear Ms. Wright: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.aloska.gov Eni US Operating Company Inc. (Eni) has requested guidance regarding the final site clearances for seven exploration wells located on its leases. The seven referenced wells are listed above. All seven wells have been plugged and abandoned in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) regulations and the approved sundry applications. The AOGCC approves the location clearances for these seven wells. The Maggiore #1, Rock Flour 42 and Rock Flour #3 well sites were initially inspected by the AOGCC on July 12, 2007. Due to debris left at the sites, final location clearances were not issued at that time. The sites were subsequently cleaned by Eni between August 1, 2010 and August 3, 2010. Photographs of these three well locations taken during the inspections and a closeout report were provided to AOGCC on October 1, 2010 and October 11, 2010, respectively. After a thorough review, these onshore well sites were found to be in compliance with location clearance requirements as stated in 20 AAC 25.170. By email dated July 2, 2008, the AOGCC responded to requests from the prior operator (Kerr- McGee) and the State of Alaska Department of Environmental Conservation concerning the status of the four offshore Nikaitchuq wells. The AOGCC responded that the wells were plugged and abandoned as required by AOGCC regulation 20 AAC 25.112 and offshore location clearance requirements as stated in 20 AAC 25.172. The AOGCC requires no further work on the subject wells or locations at this time. However, Eni remains liable if any problems occur with these wells in the future. Sincerely, '?"AtZ"'dL� Jessie L. Chmielowski Commissioner • • �/ McMains, Stephen E (DOA) (PT D -; l (lo -- 1 (nip From: Conway Patrick [ Patrick .Conway ©enipetroleum.com] Sent: Wednesday, October 27, 2010 1:03 PM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); McMains, Stephen E (DOA); Fairbanks, Trevor P (DNR); Graika Don; Brink Jason Subject: RE: ENI exploration site cleanup Attachments: Cement and waterbody.jpg; Cement.jpg; Maggiore.jpg; P8240021.jpg; StickPicking effort.doc Jim, I apologize for the delayed response. I was on R &R when you're message came in and it slipped through the cracks. The 7/12/2007 agency inspection was conducted while the stickpicking operation was ongoing. Fairweather employees returned to the sites in the days following the inspection and retrieved the debris that was identified in the AOGCC report associated with that visit. Rock Flour concrete and 12x12 timber were removed at that time. In August of 2010 I visited Maggiore, Rock Flour 2 and Rock Flour 3 via a helicopter. We assessed aerially, then landed and walked down each site. With the exception of the concrete that was found at Maggiore and a few small, weathered pieces of wood (presumably broken pallets and survey lathe), the sites were free of man made debris. With respect to the waterbodies at Maggiore, the depth of water is approximately 6 -12 ". No casing stub or man made debris is visible. Patrick Conway /Don Graika IV � FEIN 0 2 O Nikaitchuq Environmental Coordinator (0) 907 - 670 -8501 (C) 907 - 903 -1762 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, October 11, 2010 4:41 PM To: Conway Patrick Cc: Schwartz, Guy L (DOA); McMains, Stephen E (DOA); Fairbanks, Trevor P (DNR) Subject: FW: ENI exploration site cleanup I've read through the string of emails and reviewed your 9 page "ClosureDocumentation" which is inclusive of several photos of debris at and recovered from Maggiore 1, and single photos from overflight of RockFlour 2 and 3 locations. Please provide additional description regarding statement you make below in an email to DNR's Trevor Fairbanks - "At this time it was determined that Rock Flour 2 and 3 had been cleared of all debris identified in 2007." - When was the debris from Rock Flour locations removed? - How did you determine adequacy of Rock Flour locations site clearance? - Did you land at the Rock Flour locations? Inability to do on- ground survey was deficiency noted in Rock Flour 2 location clearance inspection conducted in 2007. Regarding Maggiore 1, settlement and ponding appears to have developed at the location. The 2007 inspection did not identify any settlement/ponding issues. Have you assessed if this settlement is coincident to the P &A'd well? Is casing stub exposed below water level? Jim Regg Inspection Supervisor AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 1 • • From: Schwartz, Guy L (DOA) Sent: Monday, October 11, 2010 3 :09 PM To: Regg, James B (DOA) Subject: FW: ENI exploration site cleanup Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Conway Patrick [mailto: Patrick .Conway @enipetroleum.com] Sent: Friday, October 01, 2010 3:54 PM To: Schwartz, Guy L (DOA) Cc: Brink Jason; Graika Don Subject: FW: ENI exploration site cleanup Guy, As requested, the message that was sent to DOG (Trevor Fairbanks) and the documentation certifying final cleanup of the well sites for Eni explorations wells Maggiore #1 and Rock Flour #2 & #3 are attached. Please don't hesitate to call if you have any questions. Patrick Conway /Don Graika Nikaitchuq Environmental Coordinator (0) 907 - 670 -8501 (C) 907 - 903 -1762 From: Conway Patrick Sent: Tuesday, August 24, 2010 4:01 PM To: 'Fairbanks, Trevor P (DNR)'; Graika Don Cc: Easton, John R (DNR) Subject: RE: ENI exploration site cleanup Trevor, A reconnaissance flight was conducted on August 1, 2010 to document the condition of each of the sites described in the attached document titled " AOGCC Letters ". Eni representatives Patrick Conway and Mark Lowther were onboard. At this time it was determined that Rock Flour 2 and 3 had been cleaned of all debris identified in 2007. The 12x12 timber at Maggiore 1 that was referenced in the report had been removed. However, two relatively small chunks of cement remained at this site. At the time appropriate tools were not available to remove the remaining cement pieces from this location. On August 3, 2010 Conway returned to Maggiore 1 with Steve Millea and Caitlin Crandall to remove the remaining cement. Approximately 400 pounds of cement was broken into more manageable pieces and loaded onto the helicopter. As built drawings and photos of each location are included in the attachment titled "ClosureDocumentation ". Please don't hesitate contact Don /me with any further questions. Thanks, Patrick Conway /Don Graika Nikaitchuq Environmental Coordinator 2 Office: 907 - 670 -8501 Cell: 907 - 903 -1762 From: Fairbanks, Trevor P (DNR) [mailto :trevor.fairbanks @alaska.gov] Sent: Monday, August 16, 2010 1:09 PM To: Graika Don Cc: Conway Patrick; Easton, John R (DNR) Subject: ENI exploration site cleanup Don, ENI has surrendered several lease including Maggorie and Rock flour sites. According to our records both sites had some debris reported onsite as of 2007. Patrick said that he visited the sites and removed the debris the first week of August. In order for us to release the acreage we need verification that the site been cleaned. Therefore, in lieu of flying DOG staff to the site to verify they have been cleaned up a report stating the location of sites visited, material removed, people present along with pictures before and after should be suffice. Please let me know if you have any questions, Thanks Trevor Trevor Fairbanks DNR Division Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, AK 99501 Tel: 269 -8885 This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 3 eocl��f�.fr �`z Regg, James B (CED) From: Schwartz, Guy L (DOA) Sent: Tuesday, October 5, 2010 11:22 AM To: Conway Patrick Cc: Brink Jason; Regg, James B (DOA) Subject: RE: ENI exploration site cleanup Patrick, The photo documentation is sufficient for the final site clearance. We will be issuing a letter to you shortly for these wells stating the site has been cleared by AOGCC. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Conway Patrick [ma iIto: Patrick. Conway@enipetroleum.com] Sent: Friday, October 01, 2010 3:54 PM To: Schwartz, Guy L (DOA) Cc: Brink Jason; Graika Don Subject: FW: ENI exploration site cleanup Guy, As requested, the message that was sent to DOG (Trevor Fairbanks) and the documentation certifying final cleanup of the well sites for Eni explorations wells Maggiore #1 and Rock Flour #2 & #3 are attached. Please don't hesitate to call if you have any questions. Patrick Conway/Don Graika Nikaitchuq Environmental Coordinator (0) 907-670-8501 (C) 907-903-1762 From: Conway Patrick Sent: Tuesday, August 24, 2010 4:01 PM To: 'Fairbanks, Trevor P (DNR)'; Graika Don Cc: Easton, John R (DNR) Subject: RE: ENI exploration site cleanup Trevor, A reconnaissance flight was conducted on August 1, 2010 to document the condition of each of the sites described in the attached document titled "AOGCC Letters". Eni representatives Patrick Conway and Mark Lowther were onboard. At this time it was determined that Rock Flour 2 and 3 had been cleaned of all debris identified in 2007. The 12x12 timber at Maggiore 1 that was referenced in the report had been removed. However, two relatively small chunks of cement remained at this site. At the time appropriate tools were not available to remove the remaining cement pieces from this location. On August 3, 2010 Conway returned to Maggiore 1 with Steve Millea and Caitlin Crandall to remove the remaining cement. Approximately 400 pounds of cement was broken into more manageable pieces and loaded onto the helicopter. As built drawings and photos of each location are included in the attachment titled "ClosureDocumentation". Please don't hesitate contact Don/me with any further questions. 4 . Day 1 7/10/07 12:30 pm start due to foggy conditions — clean -up of Maggiore #1 and Rock Flour #3 The 1 day of clean -up involved Maggiore #1 and Rock Flour #3 along with a significant portion of the ice road. Both locations were strewn with trash involving absorbent rags, plastic, safety glasses, wrenches, pallets (broken), delineators and survey stakes. Each location took approximately 3 hours to pick -up and the ice road roughly two hours. Maggiore #1 had a very large 12" X 12" timber that could not be picked -up on Day 1, so it was decided to leave it until Day 4 when we could get the helicopter closer to the location. Rock Flour #3 has a large cement block still on location. It measures approximately 5 ft. X 3 ft. and weighs close to 200 pounds. This piece was also left in place because of its size. Rock Flour #3 had an inordinate amount of trash. The ice road from Maggiore #1 to the north included survey stakes, delineators, orange plastic snow fencing and miscellaneous items dropped from trucks. Seven miles of ice road were picked up before flying back to Deadhorse for the evening. Day 2 Date? 12:30 pm start due to foggy conditions — clean -up of Hemi State well and Rock Flour #2 Day 2 concentrated on cleaning up the Hemi State well, Rock Flour #2 and a stretch of ice road approximately 3 miles long. Hemi State was reasonably clean since it had limited work and equipment on location. However, we left in place some large timbers on the sides of the pad due to their size. Rock Flour #2 had significant trash and locations that appeared to have had a snow blower chewing up pallets and survey stakes. This pad was the worst of the ENI project and took approximately 3.5 hours to clean with 3 pickers. The mud spill site was spotted and marked with stakes and sand bags. The ice road from Rock Flour #2 to the MP 1 pad was picked up with another significant amount of trash located at the site of the 22 man camp and the guard shack. At 8:00 pm I drove to the intersection of the ENI ice road with the Spine Road and met with DNR officials about the East Creek crossing. In attendance were Jack Winters and Bill Morris who escorted me to the place of concern. They mentioned that gravel will have to be moved back into place due to flooding and a rush of water that washed it from its original location. Approximately 50 to 100 yards of area of the fish- bearing stream are affected. According to Bill Morris, the slotting of the ice bridge or the piling of overburden snow was done incorrectly and caused the damning of water that eventually forced its way through the slot where the ice bridge was cut. Unfortunately, there are no pictures and this is speculation. The DNR will provide us with pictures of the area taken in the summer of 2006. Day 3 Date? 9:00 am start due to foggy conditions — agency inspection day with ice road clean -up. • • Day 3 started with the agency visits to the individual sites and picking up Gordon Matumeak in Nuiqsut. I informed Gordon that the ice road trash pick -up was not completed and he informed me that he would rather inspect the road once it was done. Later in the day Gordon was taken back to Nuiqsut to return at a later date. Bob Britch will be taking ADEC out to the spill site in August and this would be a good time for Gordon to visit. DNR and AOGCC visited all sites and told us that they would sign off on each site. They were later taken back to Deadhorse. The trash crew returned to the field and picked up approximately 7 miles of ice road. Delineators, survey stakes, snow fences, foam, absorbent pads, headlights, tools, front - loader teeth, banding and miscellaneous wood littered the road. At 6:00 pm I drove to Oliktok Point to clean the ENI pad at Nikaitchuq and found the surface area littered with wood pieces, absorbent pads, plastic, foam and other miscellaneous forms of trash. A very large amount of debris was located over the sides of the pad on the ocean side. The west side of the pad is approximately 40 feet high and very steep. It will be a tough clean -up effort to get it picked. Day 4 Date? 10:30 am start due to foggy conditions — videographer day with ice road clean -up. Day 4 started with the videographer recording video of the surrounding area and Maggiore #1. At this time the large timber and some cement chunks were picked up as the videographer was recording. Proceeded north along the ice road and saw an occasional survey stick along the way. We circled over Rock Flour #3 and flew to a nearby river channel for the videographer. Once the videographer was finished, the trash pick -up continued with delineators, flagging and any other objects of significance. Due to time restrictions, some survey stakes remain on the ground. PHOTOS • • '-.`'- . } •µ i .»- . " � . yY "e ..r1.Na o,w, ''e., '`+W" ,y r..` err J . �•; k '0 'r .� re x Rock Flour #2 after clean -up — shows mud -spill in- between two yellow sand bags i h ' S q I Y E V'+ 'Iv i .'!4 . • g! s '-� 4 , ` " 7 y \k . fi - 4,3.., _?, h •,1 '"' _ - ? t .. Z ' 7 ' } , M - C. if . y ', ` r„. 4 . , , ,( 'L -�.,.f'3ai . . . _ , *4x .c , ^ ' 7 . • . ^a..' 1 ,,, '1,'M,. Y . ' d r ti t . � , `> ,: r : s -S.a.. 4 " r w ''''.;:;:..:',M''..-• � ' x w .r',_ .'.r Maggiore #1 after clean -up • • • e'. Maggiore #1 after clean -up — shows large 12X12 timber that has been picked up. • • ifoz. . .74 .: ..:. •rte _ . ~� Maggiore #1 after clean -up • • - Maggiore #1 after clean -up ,,,,,•_.. { � .:, ; YI , tJ' ' ,'� il- I�` w 4h - . ,ti d y S �- ti . ,,yam s + x x '4 ,t -•. �r"` a ,� 'f7i✓'1e"`rre. 4 £= r [!� � r '"'' . Maggiore #1 soil mound — typical of all • • L ‘1041111111.b Rock Flour #3 after clean -up. Shows cement block that was left • • ' 4 4P1 6 . 1 1104111100110 Rock Flour #3 after clean -up. 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V.' - .'" - • + : - , ' ' • ,1 A '. - = '','• ' ' '' ,. - ,,," , ''s. it* i , • - -` - - !int ' " '), ' • ilf , 0*.- i „ • _s ' 4 ,.... . -- -, • - ..- 1. .. -, -I '' ,, , - „, . • I , . •t „ , • . . i• ' 1 ' ' ' S` .. .-4 ' . - ..ri-- '. ' ..... , . . . .. _ _ • - . e f 14 Ilk -- ' ••,ot . • xSdY a 1 7 t I �i F • .~~~:. ~~ ~~~ .~~ ~iir, .A.. 0 ~ `~„ ~ ~. ~: MICROFILMED 6/30/2010 DO N4T PLACE, ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc l~ ~~: ~ DATA SUBMITTAL COMPLIANCE REPORT 4/14/2009 Permit to Drill 2061660 Well Name/No. ROCK FLOUR 2 Operator ENI PETROLEUM MD 4332 TVD 4332 Completion Date 3/16/2007 Completion Status P&A Current Status P&A REQUIRED INFORMATION Mud Log Yep Samples IVo DATA INFORMATION Types Electric or Other Logs Run: Text to long for this data field. See 10-407 Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D C Las 15001 Induction/Resistivity D C Las 15002 Porosity ED C Pds 15003 Report: Final Well R I ~ C Pdf 15004 Sam le p ED C Pdf 15005 Seismic/Velocity 1!og 15001 Mud Log J?D C Dls 15096 Dip -ED C Las 15095 Formation Tester ~D C Dis 15097 See Notes Log See Notes /~ Y Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 0 4319 Open 4/12/2007 HDIL, MARL, ZDL, CN, CALIPER, GR, DSL, ZDL 3623 4319 Open 4/12/2007 MR Explorer 2D Diffusion. CGM & LAS Open 4/12/2007 Final Report, Mudlogs, LAS ,and Daily report w/Graphics 3650 4319 Open 4/12/2007 SideWall Core and Particle Size Analysis Report with Photos 1500 4280 Open 4/12/2007 VSP 2 Col 110 4332 Open 5/7/2007 Formation Log MD 11-Jan- 2007 1914 4274 Open 3894 4154 Open 5/1/2007 Multiple Formation LAS Tester Data plus Graphics 3670 4274 Open CBIL Circumferential Borehole Imaging Log Col 1 3894 4154 Open 5/7/2007 Res Char Instrument, Sample view Log, Fast Response Quartz Guage, GR Log 16-Jan-2007 API No. 50-029-23335A0-00 UIC N DATA SUBMITTAL COMPLIANCE REPORT 4/14/2009 Permit to Drill 2061660 Well Name/No. ROCK FLOUR 2 MD 4332 TVD 4332 Completion Date 3/16/2007 1~6a See Notes Operator ENI PETROLEUM Completion Status P&A 2 Col 1 Sample 5 Col 1 Dip 5 Col 1 Magnetic Resonance 5 Col 1 Gamma Ray Spectro 5 Col 1 Induction/Resistivity 5 Col 1 Induction/Resistivity 5 Col 1 ~g Gamma Ray 5 Col 1 LL~og Neutron 5 Col 1 og Induction/Resistivity 25 Blu I~,~og Induction/Resistivity 25 Blu Well Cores/Samples Information: Interval Name Start Stop Sent Received API No. 50-029-23335-00-00 Current Status P&A UiC N 3894 4154 Open 5/7/2007 Res Char Instrument, Sample view Log, Fast Response Quartz Guage, GR Log 16-Jan-2007 3823 4177 Open 5/7/2007 Sidewall Coregun 12-Jan- 2007 1992 4275 Open 5/7/2007 Hexagonal DIP Log 12-Jan- 2007 3700 4284 Open 5/7/2007 MREL 12-Jan-2007 1992 4302 Open 5/7/2007 Digital Spectralog 12-Jan- 2007 0 4306 Open 5/7/2007 High Def Induction Log, GR, Cali 12-Jan-2007 0 4306 Open 5/7/2007 High Def Induction Log, Multi Array Acoustilog, Comp-Z-Denislog, Neu, GR, Cali 12-Jan-2007 1992 4306 Open 5/7/2007 Multi Array Acoustilog, GR 12-Jan-2007 1992 4306 Open 5/7/2007 Comp Z-Densi, Comp Neu, GR 12-Jan-2007 321 4332 Open 5/7/2007 TVD ARC & RAB Resi and Composite Mode, 11-Jan- 2007 321 4332 Open 5/7/2007 MD ARC & RAB Resi and Composite Mode, 11-Jan- 2007 Sample Set Number Comments Cores a nd/or Samp les are required to be submitted. This record automatically created from Permit to Drill Module on: 12/20/2006. DATA SUBMITTAL COMPLIANCE REPORT 4/14/2009 Permit to Drill 2061660 Well Name/No. ROCK FLOUR 2 MD 4332 TVO 4332 Completion Date 3/16/2007 ADDITIONAL INFORMATION Well Cored? ©/ N $ t~ C.~ r~ ~ ~~ Chips Received? -~L~N- Analysis 6/ N Received? Comments: Operator ENI PETROLEUM Completion Status P&A Current Status P&A Daily History Received? Formation Tops ~N API No. 50-029-23335-00-00 UIC N 1 ~' __ - _ - -_ - - - Compliance Reviewed By: ___ Date: ~ ` '~~~ .,f r ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission .---~ TO: Jim Regg ~°~~ ~ ~~~?~~ ~ DATE: July 12, 2007 P. I. Supervisor FROM: Bob Noble SUBJECT: Location Clearance Petroleum Inspector Hemi St 3-9-11 (PTD 169-037) Rockflour #2 (PTD 206-166) ;/` Rockflour #3 (PTD 207-005) Maggiore #1 (PTD 207-006) July 12, 2007: I traveled to Exxon exploration well Hemi State 3-9-11, and ENI exploration wells Rockflour #2, Rockflour #3, and Maggiore #1 PTD 207-006 to verify location clearance. I was accompanied on the trip with a DNR inspector, a Field inspector for the North Slope Borough (Gordon Matumeak), and two Fairweather employees heading up the location clearance. We were able to land at all locations except Rockflour #2. Summary: I recommend that we land at Rockflour #2 for a better look. I feel there needs to be further cleanup work done at Rockflour #3, Hemi State 3-9-11, and Maggiore #1 as detailed in attached location clearance forms. Attachments: Photos Surface Abandonment/Location Clearance/ Suspended Well Forms 1) Hemi State 3-9-11 2) Rockflour #2 /' 3) Rockflour #3 4) Maggiore #1 ~+ ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment /Location Clearance /Suspended Well ( Title 20 AAC 25.170 ) J ~~~'~I 7l(~v FILE INFORMATION: Operator: ENI Well Name: Rockfour #2 Address: PTD No.: 206-166 API No. 50- Surface Location (From Sec. Line): Unit or Lease Name: North/South East/V1/est Field and Pool: Section: _ Township: _ Range: _ Meridian: _ Downhole P&A Date: 20 AAC 25.120 -ABANDONMENT MARKER: Insp. Date: Surtace Monument Approval Date: Post OD: (4" min) _" Length: ft. Set on (Wellhead, Csg , In Cmt) _ Height above final grade (4' min.): _ft. Casing stub_ft. below final grade Top of Marker Post Closed ? _ All openings closed ? Inspector: Insp. Date: Subsurface Monument Approval Date: Marker Plate Diameter: _" Distance below final grade Level: Thickness: _" Side Outlets removed or closed: Marker Plate Attached To Conductor-(Y/N) Cement to surface (all strings)? Inspector: Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate: Insp. Date: Approval Date: Inspector: Insp. Date: 7/12/07 20 AAC 25.170 -LOCATION CLEANUP: Approval Date: Pit's filled in? Yes Liners Removed or Buried? Debris Removed: Notes: Ww didn not land becouse the Cho er was low on fuel. We circled once. General condition of pad/location: Goad for air (Rough, Smooth, Contoured, Flat, Natural ) Notes: Type of area surrounding location: Tundra (Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand) Debris on surrounding area: Could not see an from air. Notes: Access road present? No Type road: Ice (Dirt, Gravel, Ice, Other) Condition: Condition of road: Notes: Cellar filled in? Yes Type of fill: Gravel Height above grade: Notes: Could not tell the hi ht from the air, but did see a mound. Type work needed at this location: I feel someone needs to o back and land here and look around. Thin s looked ood from the air. Ins ector: RECOMMENDED FOR APPROVAL OF ABANDONMEt Yes I Distribution: Reason: 1 ti~ ' Vf' S? oug--~eH-4'tle fZ~~tt.~' I~~l~ ~' ~~GC V - V~./CI QLVI c -Database c -Inspector Filial iilspectivil peliorrfied? Yes` Final Approval By: Title: No ~~ (If "No" See Reason ) ~ ~ ~ iV0 DATE: ,/ .~v~ A%c)~l~ 7 - i z-i: ~ :/" .~t ~. Sheet by L.G. 8/5/00 2007-0712 Loc_Clearance_RockFlour-2_bn.xls 7/16!2007 ~. • .~ -. --, ~,CEI~/ED Fairweather E&tP Services, In~ ~ ~ ,~ ~ ~ ~* MAY p '7 2001 2000 E. 88th Ave., Suite 200 DATE May 4, 2007 Anchorage, Alaska 99507 (~8t~~g•(',OtT11TllSS1Ot1 CUSTOMER ID AOGCC 907-258-3446 ~e brian.brigandi(a~fairweather.co SHIP TO Mr. John Norman, Chair BILL TO Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 _ Anchorage, Alaska 99501 ~ /~ ~ // / 907-793-1225 U (E~(~ ITEM# DESCRIPTION QUANTITY 22 Rock Flour #3 - BH -Star Resistivity Imaging -CBIL logs 1.00 23 Rock Flour #3 - BH -RCI short logs 1.00 24 Rock Flour #3 - BH -RCI tong logs 1.00 25 Rock Flour #2 - BH -HDIL/XMAC/ZDL/CN/GR/CALI logs t.00 26 Rock Flour #2 - BH -Digital Spectralog 1.00 27 Rock Flour #2 - BH - Multipole Array Acoustilog -Gamma Ray Log 1.00 28 Rock Flour #2 - BH -Magnetic Resonance Explorer Log 1.00 29 Rock Flour #2 - BH -HDIL/GR/CALI logs 1.00 30 Rock Flour #2 - BH -ZDL/CN/GR/CALI logs 1.00 31 Rock Flour #2 - BH -Hexagonal Diplog -CBIL logs 1.00 32 Rock Flour #2 - BH -RCI short logs 1.00 33 Rock Flour #2 - BH -RCI tong logs 1.00 34 Rock Flour #2 - BH - Sidewall Corgun 1.00 Please contact Brian Brigandi at [907-343-0319] with any questions or comments. r i -- ~ ~ ~ I ~i ~- ~~ i I. i~ ~,~ :~.,., Fairweather E£tP Services, Inc. 2000 E. 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 brian.brigandi(a~fairweather.co SHIP TO Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 907-793-1225 DATE May 4, 2007 CUSTOMER ID AOGCC BILL TO ITEM # DESCRIPTION QUANTITY 1 Rock Flour #3 -SLB -GeoVision Resistivity Service -TVD 1.00 2 Rock Flour #2 -SLB -ARC Er RAB Resistivity Log - MD 1.00 3 Rock Flour #2 -SLB -ARC tt RAB Resistivity Log -TVD 1.00 4 Maggiore #1 -SLB -ADN Vision Quadrants Recorded Mode Log - MD 1.00 5 Maggiore #1 -SLB -Vision Services Composite Recorded Mode Log -TVD 1.00 6 Maggiore #1 -SLB -GeoVision Resistivity Service -TVD 1.00 ~ Maggiore #1 -SLB -Vision Services Composite Recorded Mode Log - MD 1.00 $ Maggiore #1 -SLB -ADN Vision Quadrants Recorded Mode Log -TVD 1.00 9 . Rock Flour #2 -Epoch -Formation Log MD 1.00 14 Rock Flour #3 -Epoch -Formation Log MD 1.00 11 Maggiore #1 -Epoch -Formation Log MD 1.00 12 Maggiore #1 - BH -Res. Characterization Inst. Log - GR Log 1.00 13 Maggiore #1 - BH - Sidewall Corgun 1.00 14 Maggiore #1 - BH - 6-Arm Caliper Log, Gamma Ray Log 1.00 15 Maggiore #1 - BH -Magnetic Resonance Explorer Log 1.00 16 Rock Flour #3 - 8H -HDIL/XMAC/ZDL/CN/GR/CALI logs 1.00 17 Rock Flour #3 - BH -Digital Spectralog 1.00 18 Rock Flour #3 - BH - Multipole Array Acoustilog -Gamma Ray Log 1.00 19 Rock Flour #3 - BH -Magnetic Resonance Explorer Log 1.00 20 Rock Flour #3 - BH -HDIL/GR/CALI logs 1.00 21 Rock Flour #3 - BH -ZDL/CN/GR/CALI logs 1.00 Ptease contact Brian Brigandi at [907-343.0319] with any questions or comments. ~ ~ ~~ ~U 1201 Louisiana St Suite 3500 Houston, Texas 77002 -U.S.A. Phone (713} 393 6100 Fax (713} 393 6395 April 12, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7`~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report Eni Petroleum: Rock Flour #2 (PTD 206-16b) Dear Commissioner Norman, ~~ R~~~' Y ice' f°1~11 1 ~ C~~l Alaska Oil ~ Gas Conso Commission . Anchorage Eni Petroleum hereby submits its Well Completion Report for the work performed in drilling its Rack Flour #2 exploration well on the North Slope. Please find enclosed the following information for your files: 1) Form 10-407 Well Completion or Re-completion Report and Lag 2} Well As-Built Survey 3} Wellbore Schematic 4) Well Operations Summary 5) Photographic documentation of surface P&A 6) CD containing the mud log and all LWD, MWD and wireline logs run If you have any questions or require additional information, please contact me at (713) 393-b122 or Bill Penrose at (907) 258-3446. Sincerely, EN1 PETROLEUM David Dougall HSE Manager enclosures cc: Mattes Rivetti -Eni Bill Penrose -Fairweather ~~V~I V E~ STATE OF ALASKA ~ A ~;~ 1 2 2007 ALASKA OiL AND GAS CQNSERVATION COMMISSI©N WELL G4MPLETION t)R RECQMPLETION REPC?RTA~16h ~~i~rons. COmrnissiryn 1a. Weil Status: Oil ~ Gas ~ Plugged (~ Abandoned ~ Suspended' ^ zoaAG zs.~os 2aaac 26.11° GINJ^ WINJ® WDSPL^ WAG® Other^ No. of Completions: 1b. Weil class: Ai1ChOfage Development ^ Exptaratory~ Service ^ StratigraphicTest^ 2.Operator Name: Eni Petroleum 5. Date Cornp., Susp., or ~ Abend.: 3/16/2fl07 12. Pemmit to Drill Number: 208-166 ' 3. Address: 4201. Lousiana St. Suit 3500. Houston, TX, 77002 6. Date Spudded; 42/28/2006 '' 13. API Number: ,~ 50-029-23335-J~ . (y 4a. Location of Well (Governmental Section}: Surface: 4089' EEL, 4750' ESL, Sec 28, T11N, R11E, UM'`~ 7. Date TD Reached: 1/11/2W7 ~ 14. Well Name and Number: Rock Flour tf2~tfj ~.~- f Top of Productive Horizon: 4165' FWL, 542` FNL, Sec 28, T11 N, R11 E, UM 8. KB (ft above MSL): ~ Ground (ft MSt}: 7/ gp8~ 15. F'weld/Paot{s): ~.~ Expbratory Total Depth: 4161' FWL, 545' FNL, Sec 28, T41 N, R11 E, UM 9. Plug Back Depth(MD+TVD}: Surface R '/• 4b. Location of Well (State Base Plane Coord+nates, NAD 27}: Surface: x- 577861,2 ~ y- 5953995.72 ~ Zone- 4 10. Total Depth (MD + TVD}: ~ 4„332' MDIiVD ' 16, Property Designation; ADL 390695 TPI: x- 577836.53 y- 5,954,002.71 Zone- 4 Total Depth: x- 577832.11 y- 5,953,998.38 Zone- 4 11. SSSV Depth (MD + TVD}: NIA 17, Land Use Permit: NIA 18. Diretffional Survey: Yes No .r (Submit electronic and printed information per 20 AAC 25.050} 19. Water Depth, 'rf Offshore: NIA (ft MSL} 20. Thickness of Permafrost (TVD): 1,834' ~' 21. togs Obtained (list alt logs here and submit electronic and printed information per 20 AAC 25.071): Mud Log, MWD Directional, LWD GRIRes, WL:SGR/CN2DLtHDiUXNWC/GRIMRF_7CIGBIURCUHDIPNSPfSWG 22. CASING, LI NER AND CEMENTING RECORD CASING WT. PER . GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT ~ TOP BOTTOM TOP BOTTOM PULLED 2fl'" Surface 140' Surface 110' ~ 26" Grouted to surface None 13-318" 688 L-80 Surefce 2,005' Surface 2,005' ~ 17-112" Cmtd to surf w/ ti00 bbis Nane 23.Open to production ar injection? Yes ^ NoQ tf Yes, fist each 24. TUBING RECORD interval open {MD+TVD of Top & Bottom; Perforation Size and Number}: SIZE DEPTH SET (MD) PACKER SET.{PAD} NIA 25, ACID, FRA CTURE, CEMENT S4UEt=ZE, ETC. DEPTH INTERVAL (MD} AMOUNT AND KIND OF MATERIAL USED WA 26. PRODUCTION TEST Date First Production: Well not tested or produced. Method of Operation (Flowing, gas lift, etc.}: NIA Date of Test Hours Tested: Productbrt for Test Period Oil-Bbl: Gas-iIACF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~.•~ Oil-Bbl: Gas-PACE: Water-Bbl: Oil Gravity -API (COn•}: 27. CORE DATA Conventional Core(s) Acquired? Yes r^ - No 5idewall Cores Acquired? Yes ~ - No ^ ff Yes to either question, Nat forrrlations and intervals cored (MD+TVD of top and bottom of each}, and summarize lithology and presence of oil, gas or water (sutxt~t separate sheets with this fa~m, if needed}. Sutxnit detailed descriptions, ~re chips, photographs and laboratory anatyt~al results per 20 AAC 25.071. Three 4" O.D. conventional cores were taken in ttte fc~lowing intervals: Core #1 3,ti55 - 3,884', Core 82 3,884" - 3,928', Core fit3 4,085' - 4,096', Descriptions, chips, photographs and laboratory analyses will be submitted under separate cotter, Sldewail cores were shot and recovered .! over the interval 3,$23' to 4,177'. Laboratory analyses of the sidewall cores are contained on the Core Lab CD submitted with this Well Completion Report. Sae the attached mud log for the Iftltologies encountered in this wait. No gas or water were encountered. Qtl shows ~/ occurred throughout the stratigraphic column below the surface casing. See the electric logs and mud bg attached. /~-~+~+t~t' ~, ~.l ~T ~t~-g ~c `.y~~~ ~`b`~ a ^~ k~ ~ ,-~,~f '~ uran lUiUr rcewseau~wr ORIGINAL CONT R RSE SIDE ~A~' ~ 207 ,dv ~/•,Z• 0 7 ~. ~/~.~ ~~ ,v7 G • 28. GEOLOGIC MARKERS (List all fomaations and markers encountered}: 29. FORMATION TESTS NAME Ml? TVD Weli tested4 Yes ~ No Q ,r If yes, list intervals and formations tested, briefly sununariztng test results. Attach separate sheets to Permafrost -Top Surface Surface this form, ff needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base 1,866' 1,856' ` Schrader Bluff (NA Sand) 3,586' 3,590 Schrader Bluff {NB Sand) 3,632' 3,682' Schrader Bluff (OA Sand) 3,776' 3,776' Schrader Bluff (®B Sand} 3,927' 3,927` Formation at total depth: Schrader Bluff 30. List of Attachments: Weilbore schematic, Weli as-built di ram, Summary of o rations, Photos of P8A, CD's containtng logs. 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: BiM Penrose 258-3446 Printed Name: David Dougall Title: HSE Manager Signature: ~ cwt ~ ~~'' .a--~ Phor~; 713-393122 Date: ~~ '~~ ~"c'~ "~ INSTRUCTIONS ..a~'"r~T~~O~--~~ ~~~J~~C>~ General: This form is designed for submitting a rxxnptete and correct well completion report and bg on a# 17IPes of (ands and leases to Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report. when the dawnhole well design is changed. Item 1 a: Ctassification of Service wells: Gas Injection, Water Injection, Water-Aitematirx~-Gas Injection, Salt Water Disposal, Water Supply for 1 njedion, Observation, or Other. Multiple ~mpletion is defined as a well producing from more firan one pool wide production from each pool completely segregated. Each segregated pool is a completion. item 4b: TPI {Top of Produang Interval}. Item 8: The Keity Bushing and Ground Level elevations in feet above mean sea level, Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits {ex: 50-029-20123-00-00}. Item 20: Report true vertical thickness of permafrost in t3ox 20. Provide MD and TW for ~e top and base of pemrafrost in Box 28. Item 22; Attached supplemental records for this well should show the details of arty multiple stage cementing ark the location of the cementing toot. Item 23; tf this well is carnpleted 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 farm far 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 tnjec~ion, Gas Injection, Shut-in, or Other {explain}. Item 27; Provide a listing of intervals gored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provkie a listing of Intervals tested and the corresponding formatron, and a brief summary in this box. Submit detailed test and analytical laboratory Information required by 20 AAC 25,071. Form 1007 Revised 2!2007 Care Lab eeseevmx uNUnaAUnm ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska "Cizi „>c>rt is t~,z~,.~~ en ~?~.- ~:! ca~3 ~.~>rc ;;€ ; . _. stz~ts, staficis. 1[a ezitts <~r =t~ ~, .o_~;I;ac,r u!l. ,~el;xrc .{ i l?sers-;zri«iarsl <3ata. , xavic ~d:~€zle1~- by t.tzc i;lic:rat. T'fze can<:fusicsa ., tn;tireni,rs. f~ciuc:*ia,.,. 3 P 1 f I , asrE:i a iuicatty re~xferecf !.erein retleet. t~fze c' r:~iia<zti<zit, stud ~,tzt£f tesrfrr , <>t tlzes.. aterz~s, and ~~e.rese;nt t}ie hest.'ud«errzcnt vf`4astu Iatbizt'~::fa, ~~y..1t.~~ r<~f!anee uzt t.kae i~31~hr?rzttti~>n ei,;nlzaist;:d iii ~a P y t., P J • , .. czczn~,e~-€~€n~; a.fz~; fart "_, ~ or ~S~vciiietzvs. aa,ty u~fl, .,,and, s>r cirtlfn~g actav't~ is ~~t t.hc safe r~si~ czf'tlta clt: ni, .zaad C'czre t,af>tzratcyra,3„ n~~t ~cyt- e~i.end~ ~xor zt~af.e~ ar p ~,tara.n€p~ or re:}~-~ ea avia;~t~~,.;4rr uatn res~,c to • a :.~. T}tis ref ~ i f7as ta~e,n }~: ~, =~reci i:~~a- tiae cAx<~lrarive ar7cf eort2i<ient9al €z5e o1't.fze elieaat and ~~o at.her part:p~, PE7RC)LEtJ SE[~VIGES 6316 UYlf~f~C=Ef~N QUSTC)f~, TEXAS 77(740 (713) 328-1585 SAX !713) 328-2567 L::. _s~ Core Lab ACSEflVOIA ~PT7HI2ATT~H ENI Petroleum FILE NO. : HOU-070058 Rock Flour #2 DATE :January 29, 2007 Prudhoe Bay DRLG FLUID :Water Based Mud North Slope, Alaska ANALYSTS : MCG, TW CORES :Baker Hughes SIDEWALL CORE ANALYSIS SHOT REC DEPTH Kair POR Sco Stw PROB Ob Gb GAS Sciw NO. (in) CQI (ft) (mD)" (%) (%) (%) PROD (%) (%) DET (%) °API LITHOLOGY FLU 47 1.0 63 3823.0 255.0 26.6 15.6 55.4 Oil 4.2 7.7 2 42 Sd of-fg shy-sshy lam(2) sslty scalc dl gld strk 46 0.5 D2 3824.0 1870.0 31.2 3.7 68.2 Oil 1.1 8.8 2 35 Sd f-mg vsshy sslty scalc gld yl-spts 45 0.5 C2 3825.0 945.0 29.4 3.8 78.4 Oil 1.1 5.2 0 35 Sd f-mg vsshy slty vscalc yl mott 44 0.5 C2 3826.0 580.0 27.7 8.1 65.8 Oil 2.3 7.2 0 37 Sd f-mg sshy slty scalc yl mott-spt 43 0.8 63 3827.0 290.0 25.3 0.6 71.1 Oil 0.2 7.1 0 41 Sd fg sshy slty scalc no 42 1.3 A4 3831.0 8.0 21.1 0.7 76.5 (6) 0.2 4.8 0 68 Sd vfg vshy lam(4) slty vscalc yl strk 40 1.5 B4 3833.0 595.0 27.5 18.4 57.9 Oil 5.1 6.5 0 37 Sd fg sshy sslty gld molt 39 1.8 64 3834.0 515.0 26.9 11.8 49.7 Oil 3.2 10.4 0 36 Sd fg sshy sslty gld molt 38 1.5 64 3835.0 615.0 28.0 7.8 63.4 Oil 2.2 8.0 1 35 Sd fg sshy slty yl spt 37 2.0 C4 3836.0 375.0 26.2 9.6 66.8 Oil 2.5 6.2 0 39 Sd fg sshy slty yl spt 36 1.0 B3 3856.0 0 Mudcake 35 1.3 A4 3857.0 0 Mudcake 34 1.3 A4 3858.0 7.3 21.2 0.0 81.8 (6) 0.0 3.9 0 69 Slt vshy vscalc no 33 1.5 A4 3859.0 0 Shale 32 1.5 A4 3860.0 6.2 19.6 0.0 80.6 (6) 0.0 3.8 0 66 Slt vshy calc no 31 1.3 A4 3861.0 30.0 22.1 0.0 60.9 Gas 0.0 8.6 0 66 Sd of-mg shy-vshy w/ occ peb no 30 2.0 A4 3862.0 0 Shale 29 1.0 63 3863.0 85.0 20.8 0.9 71.0 Gas 0.2 5.9 0 53 Sd of-cg shy w/peb calc mott yl 28 0.8 B3 3864.0 755.0 29.4 0.0 76.6 Gas 0.0 6.9 1 43 Sd fg sshy slty no 27 1.3 A4 3865.0 9.5 21.8 0.8 82.1 (6) 0.2 3.7 0 67 Sd of-slt vshy vscalc gld-yl strk 26 1.0 B3 3866.0 210.0 26.7 0.0 78.0 Gas 0.0 5.9 0 51 Sd vfg shy-sshy sslty scalc no 25 1.8 A4 3867.0 85.0 24.7 0.0 69.7 Gas 0.0 7.5 0 59 Sd vfg shy lam(2) slty no 24 1.0 B3 3868.0 8.6 22.0 0.0 76.3 (6) 0.0 5.2 2 68 Sd slt-vfg shy slty no 23 0.8 D3 3869.0 6.1 20.8 0.8 77.9 (6) 0.2 4.4 1 68 Sd vfg vshy slty yl strk 22 1.0 B3 3870.0 0 Mudcake 21 1.5 A4 3871.0 35.0 23.1 0.0 77.9 Gas 0.0 5.1 13 65 Sd vfg shy sslty no 20 1.3 A4 3872.0 9.3 20.7 0.0 89.6 (6) 0.0 2.1 0 66 Sd vfg shy-vshy slty no 19 1.5 A4 3873.0 8.2 20.4 0.0 81.5 (6) 0.0 3.8 0 67 Sd vfg shy lam(4) slty no Page 1 of 16 C©re i:ab AESEAVNR OPTIMIZATIIIN ENI Petroleum FILE NO. : HOU-070058 Rock Flour #2 DATE :January 29, 2007 Prudhoe Bay DRLG FLUID :Water Based Mud North Slope, Alaska ANALYSTS : MCG, TW CORES :Baker Hughes SIDEWALL CORE ANALYSIS SHOT REC DEPTH Kair POR Sco Stw PROS Ob Gb GAS Sciw NO. (in) COI (ft) (mD)" (%) (%) (%) PROD (%) (%) DET (%) °API LITHOLOGY FLU 18 0.8 D3 3874.0 0 Mudcake w/ Sd 17 1.5 A4 3875.0 7.8 20.9 0.0 87.9 (6) 0.0 2.5 0 67 Sd vfg shy-vshy slty no 16 1.3 A4 3876.0 5.3 20.6 0.0 81.9 (6) 0.0 3.7 0 70 Sd of-slt shy lam(3) slty no 15 1.3 A4 3883.0 6.4 19.5 0.0 83.1 (6) 0.0 3.3 0 66 Sd of-fg shy lam(4) slty no 14 1.3 A4 3884.0 5.8 19.8 0.0 79.3 (6) 0.0 4.1 0 68 Sd vfg vshy slty no 13 1.3 A4 3885.0 4.6 20.8 0.0 86.3 (6) 0.0 2.8 0 71 Sd of-slt shy no 12 1.3 A4 3886.0 7.7 21.7 0.0 81.2 (6) 0.0 4.1 0 69 Sd of-slt shy no 11 1.3 A4 3887.0 6.5 20.2 0.0 85.7 (6) 0.0 2.9 0 68 Sd of-slt shy no 10 NR 3888.0 No Recovery 9 1.5 A4 3889.0 4.2 19.1 0.0 81.2 (6) 0.0 3.6 0 70 Sd of-slt shy no 8 1.3 A4 3890.0 5.1 20.8 0.0 80.0 (6) 0.0 4.2 0 70 Sd of-slt shy no 7 1.3 A4 3891.0 6.7 21.4 0.0 88.8 (6) 0.0 2.4 1 70 Sd of-slt shy no 6 1.5 A4 3892.0 8.4 22.2 0.0 88.1 (6) 0.0 2.6 0 70 Sd of-slt shy lam(2,3) no 5 NR 3893.0 No Recovery 4 1.3 A4 3894.0 7.0 22.1 0.0 81.2 (6) 0.0 4.2 2 71 Sd of-slt shy no 3 1.3 A4 3895.0 5.5 21.7 8.1 74.9 (6) 1.8 3.7 1 71 Sd of-slt vshy w/ sd lam fg gld strk 2 1.3 A4 3896.0 625.0 28.5 10.5 70.0 Oil 3.0 5.5 1 36 Sd f-mg shy sslty gld strk 1 1.3 A4 3897.0 2 Mudcake w/ sd m-fg 50 NR 3899.0 No Recovery 49 1.0 B3 3900.0 1650.0 34.9 34.0 35.8 Oil 11.9 10.5 0 38 15 Sd fg vsshy gld 48 1.8 A4 3901.0 9.1 22.2 3.0 76.2 (6) 0.7 4.6 0 69 Sd fg vshy lam(4) slty talc yl gld-strk 47 1.5 A4 3902.0 950.0 30.4 22.4 43.3 Oil 6.8 10.4 0 35 Sd fg sshy sslty gld 46 1.0 63 3903.0 1020.0 32.9 37.1 31.5 Oil 12.2 10.3 0 36 Sd fg sshy sslty gld 45 1.3 A4 3904.0 810.0 31.7 35.2 41.4 Oil 11.1 7.4 0 37 Sd fg sshy gld 44 1.3 A4 3905.0 325.0 26.0 25.8 53.9 Oil 6.7 5.3 0 41 Sd fg shy sslty gld 43 1:0 B3 3906.0 670.0 28.5 29.2 40.7 Oil 8.3 8.6 0 36 Sd fg shy w/sh lam(1) gld 42 1.3 A4 3907.0 185.0 25.3 12.4 68.4 Oil 3.1 4.8 0 44 Sd fg shy lam(3) slty gld strk 41 1.3 A4 3908.0 715.0 29.1 10.9 49.9 Oil 3.2 11.4 0 36 Sd fg sshy sslty gld 40 1.0 63 3909.0 8.6 21.4 3.9 84.4 (6) 0.8 2.5 0 68 Sd vfg shy lam(1) slty vft Page 2 of 16 Core Lab x~unvola oenmar,nox ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska IDEWALL ORE ANALYSIS FILE NO. DATE DRLG FLUID ANALYSTS CORES : HOU-070058 :January 29, 2007 :Water Based Mud : MCG, TW :Baker Hughes SHOT REC DEPTH Kair POR Sco Stw PROB Ob Gb GAS Sciw NO. (in) C01 (ft) (mD)" (%) (%) (%) PROD (%) (%) DET (%) °API LITHOLOGY FLU 39 1.0 B3 3910.0 20.0 22.7 1.8 75.3 Oil 0.4 5.2 0 63 Sd vfg sshy lam(2) slty vft 38 1.3 A4 3911.0 45.0 23.4 2.9 73.1 Oil 0.7 5.6 0 57 Sd vfg shy sslty gld strk 37 1.3 A4 3912.0 0 Mudcake 36 1.3 A4 3913.0 8.2 20.9 0.0 80.3 (6) 0.0 4.1 0 67 Slt vshy lam(4) no 35 1.3 A4 3914.0 375.0 24.4 7.4 72.6 Oil 1.8 4.9 0 37 Sd vfg sshy-shy slty vft 34 1.5 A4 3915.0 155.0 22.8 5.3 68.3 Oil 1.2 6.0 0 42 Sd of-fg shy slty lam(4) vft 33 1.3 B4 3916.0 7.9 21.1 0.0 78.2 (6) 0.0 4.6 0 69 Slt vshy lam(2) no 32 1.3 B4 3948.0 6.5 21.9 7.0 74.4 (6) 1.5 4.1 2 70 Sd of-slt shy slty gld strk 31 NR 3949.0 No Recovery 30 1.5 A4 3950.0 7.3 20.8 5.0 71.8 (6) 1.0 4.8 0 67 Sd of-slt shy slty gld strk 29 1.5 A4 3951.0 25.0 23.3 11.2 62.0 Oil 2.6 6.2 1 62 24 Sd vfg shy slty gld 28 1.5 B4 3952.0 20.0 22.6 11.6 68.4 Oil 2.6 4.5 1 63 Sd vfg shy slty gld strk 27 1.0 63 3953.0 8.5 22.2 3.1 75.4 (6) 0.7 4.8 1 70 Sd vfg vshy slty gld strk 26 1.3 B4 3954.0 15.0 22.8 17.1 61.2 Oil 3.9 5.0 0 65 24 Sd vfg shy slty dl gld mott 25 1.3 C4 3955.0 6.6 21.5 3.2 74.6 (6) 0.7 4.8 2 70 Sd vfg shy lam(4) slty gld strk 24 1.5 A4 3956.0 7.8 22.1 6.7 84.4 (6) 1.5 2.0 2 71 Sd vfg vshy slty gld molt 23 1.5 A4 3957.0 4.3 21.1 0.0 82.5 (6) 0.0 3.7 0 72 Sd vfg vshy slty no 22 1.8 A4 3958.0 2.9 20.5 0.0 83.2 (6) 0.0 3.4 0 74 Sd of-slt vshy slty scalc no 21 NR 3959.0 No Recovery 20 1.3 64 3960.0 30.0 23.5 13.0 67.1 Oil 3.1 4.7 1 61 24 Sd vfg shy-vshy slty gld 19 1.3 D4 3961.0 1 Mudcake 18 1.3 64 3962.0 18.0 22.9 5.8 66.8 Oil 1.3 6.3 2 65 Sd of-slt shy-vshy gld 17 1.0 B3 3963.0 12.0 22.5 18.8 58.7 Oil 4.2 5.1 3 66 24 Sd of-slt shy-vshy gld 16 1.0 B3 3964.0 15.0 22.8 15.9 53.3 Oil 3.6 7.0 2 65 Sd of-slt shy-vshy gld strk 15 1.0 B3 3965.0 1 Mudcake 14 1.0 D3 3966.0 4.9 21.3 7.5 75.1 (6) 1.6 3.7 1 72 Sd of-slt vshy gld spt 13 1.3 64 3967.0 5.1 20.8 3.3 73.7 (6) 0.7 4.8 1 70 Sd of-slt vshy gld strk Page 3 of 16 .;;~ Core Lab FlESENY6IH OPSfHiZA7[ON. ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska IDEWALL ORE ANALYSIS FILE NO. DATE DRLG FLUID ANALYSTS CORES : HOU-070058 :January 29, 2007 :Water Based Mud : MCG, TW :Baker Hughes SHOT REC DEPTH Kair POR Sco Stw PROS Ob Gb GAS Sciw NO. (in) COI (ft) (mD)" (%) (%) (%) PROD (%) (%) DET (%) °API LITHOLOGY FLU 12 2.0 A4 3998.0 8.2 21.9 1.8 77.1 (6) 0.4 4.6 2 68 Sd of-slt vshy lam(4) slty gld-yl strk 11 1.5 A4 4052.0 0 Shale 10 NR 4053.0 No Recovery 9 1.5 A4 4058.0 0 Shale 8 NR 4059.0 No Recovery 7 0.8 C3 4060.0 0 Mudcake 6 1.3 C4 4061.0 1 Mudcake 5 1.0 B3 4062.0 165.0 25.3 11.4 65.9 Oil 2.9 5.7 1 46 Sd vfg shy slty gld strk 4 1.5 A4 4063.0 230.0 25.7 23.6 53.8 Oil 6.1 5.8 0 43 16 Sd vfg shy slty gld 3 1.5 A4 4064.0 85.0 23.8 9.1 66.0 Oil 2.2 5.9 1 51 Sd vfg shy slty gld strk 2 1.3 B4 4065.0 110.0 24.4 23.5 58.1 Oil 5.7 4.5 0 49 Sd vfg shy slty gld 1 NR 4066.0 No Recovery 50 1.5 A4 4067.0 255.0 26.4 14.9 70.2 Oil 3.9 3.9 0 42 Sd vfg sshy sslty gld 49 1.0 B3 4068.0 465.0 28.2 7.5 71.9 Oil 2.1 5.8 0 40 20 Sd of-fg shy sslty scalc gld 48 1.0 C3 4069.0 295.0 25.1 9.4 66.2 Oil 2.4 6.1 0 41 Sd vfg sshy sslty dl gld 47 1.0 B3 4070.0 380.0 27.4 8.4 71.2 Oil 2.3 5.6 1 40 Sd of-fg shy sslty calc gld 46 1.3 B4 4071.0 55.0 22.8 12.6 54.3 Oil 2.9 7.6 0 53 Sd vfg shy sslty dl gld 45 1.3 A4 4072.0 80.0 23.4 4.9 66.5 Oil 1.2 6.7 0 51 Sd of-fg shy sslty scalc dl gld 44 1.0 D3 4073.0 75.0 23.3 5.2 74.4 Oil 1.2 4.8 0 52 Sd vfg shy slty dl gld 43 1.3 B4 4074.0 90.0 24.0 6.2 72.9 Oil 1.5 5.0 0 49 Sd vfg shy slty dl gld 42 NR 4075.0 No Recovery 41 NR 4076.0 No Recovery 40 NR 4077.0 No Recovery 39 NR 4078.0 No Recovery 38 1.0 B3 4079.0 15.0 22.3 7.9 69.3 Oil 1.8 5.1 0 65 Sd vfg shy slty scalc ft gld 37 1.3 B4 4080.0 20.0 22.4 6.9 74.0 Oil 1.5 4.3 0 63 20 Sd vfg vshy-shy slty scalc ft gld 36 NR 4081.0 No Recovery 35 1.3 A4 4082.0 100.0 23.6 5.1 71.1 Oil 1.2 5.6 0 47 Sd vfg shy slty vft gld Page 4 of 16 ~ ~ ~ Core Lah nesenvo~~ nenniaanoH ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska IDEWALL ORE ANALYSIS FILE NO. DATE DRLG FLUID ANALYSTS CORES : HOU-070058 :January 29, 2007 :Water Based Mud : MCG, TW :Baker Hughes SHOT REC DEPTH Kair POR Sco Stw PROB Ob Gb GAS Sciw NO. (in) CQI (ft) (mD)* (%) (%) (%) PROD (%) (%) DET (%) °API LITHOLOGY FLU 34 1.5 D4 4083.0 9.3 22.0 2.7 78.4 (6) 0.6 4.2 1 67 Sd vfg shy-vshy vshy vft 33 1.5 B4 4084.0 20.0 22.7 6.6 71.8 Oil 1.5 4.9 0 63 Sd vfg shy vshy vft 32 1.3 64 4085.0 12.0 22.5 10.4 69.9 Oil 2.3 4.4 1 66 Sd of-slt shy lam(4) scale gld strk 31 1.3 64 4086.0 3.8 21.0 1.2 79.8 (6) 0.3 4.0 0 73 Sd of-slt shy-vshy vft 30 1.3 64 4087.0 4.6 21.5 1.4 79.0 (6) 0.3 4.2 0 72 Sd of-slt shy-vshy scale vft 29 1.0 B3 4088.0 16.0 22.4 5.0 73.7 Oil 1.1 4.8 0 65 Slt vshy w/ sd lam gld strk 28 1.3 B4 4120.0 0 Mudcake 27 1.3 B4 4122.0 750.0 32.1 13.3 70.8 Oil 4.3 5.1 1 38 31 Sd of-fg sshy sshy scale gld 26 1.3 A4 4123.0 685.0 28.9 10.8 67.7 Oil 3.1 6.2 1 36 Sd of-fg sshy slty gld 25 1.0 B3 4124.0 900.0 32.9 5.6 76.1 Oil 1.8 6.0 0 37 18 Sd of-fg vsshy sshy scale gld 24 1.0 63 4125.0 195.0 25.5 5.8 67.4 Oil 1.5 6.8 0 44 Sd vfg sshy slty scale gld 23 1.3 A4 4126.0 450.0 27.6 10.6 67.2 Oil 2.9 6.2 1 39 20 Sd of-slt shy slty gld 22 1.0 B3 4127.0 225.0 25.6 7.2 72.3 Oil 1.8 5.3 1 43 Sd vfg shy slty scale gld 21 1.3 64 4128.0 635.0 29.1 6.4 66.4 Oil 1.9 7.9 1 37 Sd of-fg sshy slty scale gld 20 1.5 A4 4129.0 165.0 25.8 11.2 67.7 Oil 2.9 5.5 2 46 20 Sd vfg sshy slty scale gld 19 1.3 A4 4130.0 245.0 25.9 8.3 66.8 Oil 2.2 6.4 0 43 Sd vfg sshy slty scale gld 18 1.5 B4 4131.0 285.0 26.5 9.3 71.0 Oil 2.5 5.2 0 42 Sd of-fg shy slty scale dl gld 17 1.5 A4 4132.0 135.0 24.2 5.8 67.2 Oil 1.4 6.5 0 47 Sd vfg shy slty scale dl gld 16 1.3 A4 4133.0 95.0 23.6 4.8 70.9 Oil 1.1 5.7 0 49 Sd vfg shy slty scale dl gld 15 1.3 A4 4134.0 125.0 24.3 6.0 72.6 Oil 1.5 5.2 1 47 Sd vfg shy slty scale dl gld 14 1.3 B4 4135.0 100.0 24.6 12.9 54.7 Oil 3.2 8.0 0 49 16 Sd vfg shy slty dl gld 13 1.0 63 4136.0 210.0 26.8 11.5 70.4 Oil 3.1 4.8 1 44 Sd of-fg shy slty dl gld 12 1.3 D4 4137.0 20.0 22.4 5.1 62.3 Oil 1.1 7.3 0 63 Sd vfg shy lam(3) vshy gld strk 11 1.3 A4 4138.0 40.0 22.6 6.2 70.1 Oil 1.4 5.3 0 55 Sd vfg shy slty scale dl gld 10 1.3 64 4139.0 90.0 23.6 5.2 71.9 Oil 1:2 5.4 0 49 Sd vfg shy vshy dl gld 9 1.0 63 4140.0 105.0 24.8 7.6 70.7 Oil 1.9 5.4 1 49 Sd vfg shy vshy dl gld 8 1.0 B3 4165.0 310.0 27.1 15.6 62.1 Oil 4.2 6.0 0 41 20 Sd of-fg shy slty gld Page 5 of 16 Core Lab Af5£flVOifl aPi1M7tAiI0N ENI Petroleum FILE NO. : HOU-070058 Rock Flour #2 DATE :January 29, 2007 Prudhoe Bay DRLG FLUID :Water Based Mud North Slope, Alaska ANALYSTS : MCG, TW CORES :Baker Hughes SIDEWALL CORE ANALYSIS SHOT REC DEPTH Kair POR Sco Stw PROB Ob Gb GAS Sciw NO. (In) COI (ft) (mD)' (%) (%) (%) PROD (%) (%) DET (%) °API LITHOLOGY FLU 7 1.0 B3 4171.0 435.0 28.1 14.3 61.2 Oil 4.0 6.9 0 40 Sd of-fg shy slty gld 6 1.3 B4 4172.0 160.0 25.8 16.3 55.1 Oil 4.2 7.4 0 46 16 Sd vfg shy slty gld 5 1.5 B4 4173.0 410.0 27.2 10.2 62.8 Oil 2.8 7.3 1 39 Sd of-fg shy slty gld 4 1.3 A4 4174.0 440.0 27.7 10.7 74.2 Oil 3.0 4.2 0 39 Sd of-fg shy slty gld 3 1.5 A4 4175.0 110.0 23.6 9.3 64.7 Oil 2.2 6.1 0 47 Sd vfg shy slty gld 2 1.3 B4 4176.0 65.0 23.1 6.5 73.2 Oil 1.5 4.7 0 53 Sd vfg shy slty gld 1 1.3 64 4177.0 9.8 22.2 5.4 73.4 (6) 1.2 4.7 0 69 Sd of-slt vshy slty gld strk • (6) denotes low permeability. Page 6 of 16 Core Lab flLSCAY0IP OPTIMIZi.if9N ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska FILE NO. : HOU-070058 DATE ;January 29, 2007 DRLG FLUID :Water Based Mud ANALYSTS : MCG, TW CORES :Baker Hughes PARTSIZ sM ANALYSIS SHOT DEPTH Kair POR SAND % SILT % CLAY Vsh Cs MEAN NO. (ft) (mD)" (%) GRVL VCRS CRS MED FIN VFIN CRS MED FINE VFIN (%) (%) (m`/cc) (µ) LITHOLOGY 47 3823.0 255.0 26.6 0.0 0.0 0.0 0.7 23.8 19.8 6.7 10.6 12.5 11.6 14.3 49 46 3824.0 1870.0 31.2 0.0 0.0 2.2 36.1 38.7 5.5 2.0 3.3 3.7 4.2 4.2 16 45 3825.0 945.0 29.4 0.0 0.0 3.8 40.1 24.9 1.9 3.4 3.1 5.2 7.3 10.3 26 44 3826.0 580.0 27.7 0.0 0.0 4.2 34.8 23.2 2.1 3.3 4.8 7.3 8.8 11.5 32 43 3827.0 290.0 25.3 0.0 0.0 0.0 15.2 27.1 10.1 3.8 5.6 8.2 11.5 18.5 44 42 3831.0 8.0 21.1 0.0 0.0 0.0 0.0 0.0 0.6 3.1 7.5 13.9 18.0 56.9 96 40 3833.0 595.0 27.5 0.0 0.0 0.0 12.7 34.8 19.9 6.9 6.8 8.3 5.1 5.4 26 39 3834.0 515.0 26.9 0.0 0.0 0.0 11.9 33.9 19.2 6.8 7.8 7.1 6.0 7.3 28 38 3835.0 615.0 28.0 0.0 0.0 0.0 3.9 40.7 25.2 3.9 3.1 5.3 7.4 10.5 26 37 3836.0 375.0 26.2 0.0 0.0 0.0 11.3 33.9 19.3 6.3 8.0 7.4 6.3 7.6 29 36 3856.0 35 3857.0 34 3858.0 7.3 21.2 0.0 0.0 0.0 0.0 0.0 0.7 5.6 20.0 11.0 26.0 36.7 94 33 3859.0 32 3860.0 6.2 19.6 0.0 0.0 0.0 0.0 0.0 1.8 5.6 16.0 6.4 28.1 42.0 93 31 3861.0 30.0 22.1 0.0 0.0 3.0 18.9 16.2 14.1 15.9 9.6 7.8 7.0 7.5 32 30 3862.0 29 3863.0 85.0 20.8 4.0 4.3 13.7 33.3 23.9 5.7 3.9 3.4 2.8 2.4 2.5 11 28 3864.0 755.0 29.4 0.0 0.0 0.0 22.2 40.5 11.6 1.6 3.8 6.9 6.3 6.9 24 27 3865.0 9.5 21.8 0.0 0.0 0.0 0.0 0.0 1.5 4.4 9.4 24.5 27.0 33.2 94 26 3866.0 210.0 26.7 0.0 0.0 0.0 0.9 19.0 32.2 12.7 7.4 10.0 8.7 9.1 35 25 3867.0 85.0 24.7 0.0 0.0 0.0 0.0 5.2 23.3 21.2 12.6 12.4 11.4 13.9 50 24 3868.0 8.6 22.0 0.0 0.0 0.0 0.0 0.4 10.8 16.0 9.7 16.3 22.0 24.9 73 23 3869.0 6.1 20.8 0.0 0.0 0.0 0.0 1.5 14.2 14.5 2.9 6.4 5.9 54.5 70 22 3870.0 21 3871.0 35.0 23.1 0.0 0.0 0.0 0.0 4.5 32.2 21.0 4.8 11.5 11.4 14.6 42 20 3872.0 9.3 20.7 0.0 0.0 0.0 0.0 1.9 18.1 25.8 16.6 11.7 11.4 14.6 54 19 3873.0 8.2 20.4 0.0 0.0 0.0 0.0 0.7 10.0 8.0 11.5 22.4 23.3 24.1 81 0.83 65 Sd of-fg shy-sshy lam(2) sslty scale 0.26 217 Sd f-mg vsshy sslty scale 0.55 179 Sd f-mg vsshy slty vscalc 0.62 165 Sd f-mg sshy slty scale 0.96 102 Sd fg sshy slty scale 3.17 4 Sd vfg vshy lam(4) slty vscalc 0.41 111 Sd fg sshy sslty 0.45 107 Sd fg sshy sslty 0.57 96 Sd fg sshy slty 0.47 104 Sd fg sshy slty Mudcake Mudcake 1.56 10 Slt vshy vscalc Shale 1.69 9 Slt vshy talc 0.49 123 Sd of-mg shy-vshy wi occ peb Shale 0.18 309 Sd of-cg shy w/peb talc 0.45 141 Sd fg sshy slty 1.81 7 Sd of-slt vshy vscalc 0.57 63 Sd vfg shy-sshy sslty scale 0.83 38 Sd vfg shy lam(2) slty 1.33 19 Sd slt-vfg shy slty 3.22 23 Sd vfg vshy slty Mudcake 0.90 41 Sd vfg shy sslty 0.87 31 Sd vfg shy-vshy slty 1.35 12 Sd vfg shy lam(4) slty Page 7 of 16 Core lab AESiflYOrii OP4IHIZAiIOtl ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska PARTSIZ sM ANALYSIS FILE NO. : HOU-070058 DATE :January 29, 2007 DRLG FLUID :Water Based Mud ANALYSTS : MCG, TW CORES :Baker Hughes SHOT DEPTH Kair POR SAND % SILT % CLAY Vsh Cs MEAN NO. (ft) (mD)" (%) GRVL VCRS CRS MED FIN VFIN CRS MED FINE VFIN (%) (%) (mL/cc) (µ) LITHOLOGY 18 3874.0 Mudcake w/ Sd 17 3875.0 7.8 20.9 0.0 0.0 0.0 0.0 4.2 18.4 10.3 6.4 14.8 20.8 25.2 67 1.29 30 Sd vfg shy-vshy slty 16 3876.0 5.3 20.6 0.0 0.0 0.0 0.0 0.5 6.1 8.7 12.1 16.8 23.3 32.5 85 1.65 11 Sd of-slt shy lam(3) slty 15 3883.0 6.4 19.5 0.0 0.0 0.0 7.5 8.9 2.6 5.0 11.3 12.2 22.2 30.4 76 1.40 16 Sd of-fg shy lam(4) slty 14 3884.0 5.8 19.8 0.0 0.0 0.0 1.3 6.8 9.7 7.8 7.9 15.9 20.9 29.6 74 1.53 18 Sd vfg vshy slty 13 3885.0 4.6 20.8 0.0 0.0 0.0 0.0 3.6 16.3 10.9 6.8 8.4 22.4 31.5 69 1.40 27 Sd of-slt shy 12 3886.0 7.7 21.7 0.0 0.0 0.0 0.2 2.7 8.4 6.3 3.9 21.6 21.5 35.3 82 2.06 8 Sd of-slt shy 11 3887.0 6.5 20.2 0.0 0.0 0.0 0.0 0.1 8.0 11.0 5.1 17.3 19.3 39.2 81 2.23 8 Sd of-slt shy 10 3888.0 No Recovery 9 3889.0 4.2 19.1 0.0 0.0 0.0 0.0 1.1 8.5 7.9 6.4 23.1 22.4 30.7 83 1.79 9 Sd of-slt shy 8 3890.0 5.1 20.8 0.0 0.0 0.0 0.0 0.9 11.0 7.2 4.6 17.8 24.3 34.2 81 1.80 9 Sd of-slt shy 7 3891.0 6.7 21.4 0.0 0.0 0.0 0.0 0.2 7.9 10.3 7.2 13.5 21.5 39.3 82 2.00 10 Sd of-slt shy 6 3892.0 8.4 22.2 0.0 0.0 0.0 0.0 0.4 10.5 15.9 8.2 19.3 17.4 28.4 73 1.72 19 Sd of-slt shy lam(2,3) 5 3893.0 No Recovery 4 3894.0 7.0 22.1 0.0 0.0 0.0 0.0 0.0 1.9 5.0 8.4 18.5 26.9 39.3 93 1.96 6 Sd of-slt shy 3 3895.0 5.5 21.7 0.0 0.0 0.0 0.0 0.0 1.3 4.0 7.1 27.2 24.2 36.2 95 2.17 6 Sd of-slt vshy w/ sd lam fg 2 3896.0 625.0 28.5 0.0 0.0 1.8 31.5 33.2 5.1 1.6 2.6 4.9 7.8 11.4 27 0.59 153 Sd f-mg shy sshy 1 3897.0 Mudcake w/ sd m-fg 50 3899.0 No Recovery 49 3900.0 1650.0 34.9 0.0 0.0 0.0 10.4 45.8 25.8 2.1 4.3 4.4 3.6 3.7 16 0.26 140 Sd fg vsshy 48 3901.0 9.1 22.2 0.0 0.0 0.0 0.0 1.4 5.0 3.2 4.1 26.2 24.0 36.1 90 2.16 6 Sd fg vshy lam(4) slty calc 47 3902.0 950.0 30.4 0.0 0.0 0.0 7.2 54.0 15.5 2.7 3.4 4.8 5.9 6.4 21 0.37 134 Sd fg sshy sshy 46 3903.0 1020.0 32.9 0.0 0.0 0.0 14.7 43.8 16.1 5.1 4.5 4.4 4.7 6.7 20 0.38 134 Sd fg sshy sshy 45 3904.0 810.0 31.7 0.0 0.0 0.0 4.9 34.8 29.9 7.5 6.2 6.6 5.2 4.9 23 0.34 101 Sd fg sshy 44 3905.0 325.0 26.0 0.0 0.0 0.0 2.1 23.1 28.1 11.8 8.9 9.1 7.8 9.1 35 0.57 70 Sd fg shy sshy 43 3906.0 670.0 28.5 0.0 0.0 0.0 6.2 29.6 27.8 10.6 6.3 7.2 6.3 5.9 26 0.40 92 Sd fg shy w/sh lam(1) 42 3907.0 185.0 25.3 0.0 0.0 0.0 0.8 11.2 25.7 20.6 11.1 10.3 9.6 10.5 42 0.66 48 Sd fg shy lam(3) slty 41 3908.0 715.0 29.1 0.0 0.0 0.0 17.2 38.0 17.5 3.7 4.5 6.2 6.1 6.7 23 0.43 130 Sd fg sshy sshy 40 3909.0 8.6 21.4 0.0 0.0 0.0 0.0 0.2 17.1 29.6 15.9 11.7 11.9 13.5 53 0.83 30 Sd vfg shy lam(1) slty Page 8 of 16 Core 1_ab AESEPYOIfl OPTIHI2ATI~N ENI Petroleum FILE NO. : HOU-070058 Rock F lour #2 DATE :January 29, 2007 Prudho e Bay DRLG FLUID :Water Based Mud North Slope, Alaska ANALYSTS : MCG, TW CORES :Baker Hughes PARTSIZ sM ANA LYSIS SHOT DEPTH Kair POR SAND % SILT % CLAY Vsh Cs MEAN NO. (ft) (mD)' (%) GRVL VCRS CRS MED FIN VFIN CRS MED FINE VFIN (%) (%) (m1/cc) (µ) LITHOLOGY 39 3910.0 20.0 22.7 0.0 0.0 0.0 0.0 3.5 23.4 25.1 13.3 12.1 10.8 11.6 48 0.74 37 Sd vfg sshy lam(2) slty 38 3911.0 45.0 23.4 0.0 0.0 0.0 0.0 4.2 26.7 24.4 11.1 11.4 10.6 11.7 45 0.73 40 Sd vfg shy sslty 37 3912.0 Mudcake 36 3913.0 8.2 20.9 0.0 0.0 0.0 0.0 0.0 0.7 4.6 11.0 20.6 26.7 36.4 95 1.87 7 Slt vshy lam(4) 35 3914.0 375.0 24.4 0.0 0.0 0.5 17.6 23.9 14.7 11.3 6.0 6.8 9.0 10.2 32 0.58 111 Sd vfg sshy-shy slty 34 3915.0 155.0 22.8 0.0 0.0 0.0 1.0 11.1 27.2 20.0 10.8 10.6 9.4 9.9 41 0.63 50 Sd of-fg shy slty lam(4) 33 3916.0 7.9 21.1 0.0 0.0 0.0 0.0 0.0 1.4 8.9 15.5 29.7 22.6 21.8 90 1.43 11 Slt vshy lam(2) 32 394$.0 6.5 21.9 0.0 0.0 0.0 0.0 0.0 9.3 25.3 20.6 14.8 14.0 16.0 65 0.96 23 Sd of-slt shy slty 31 3949.0 No Recovery 30 3950.0 7.3 20.8 0.0 0.0 0.0 0.0 0.0 5.9 23.8 ~ 25.9 16.0 13.0 15.4 70 0.95 21 Sd of-slt shy slty 29 3951.0 25.0 23.3 0.0 0.0 0.0 0.0 1.2 19.5 26.5 14.9 12.6 12.1 13.3 53 0.82 32 Sd vfg shy slty 28 3952.0 20.0 22.6 0.0 0.0 0.0 0.0 0.8 17.6 27.6 15.9 12.6 12.1 13.4 54 0.83 31 Sd vfg shy slty 27 3953.0 8.5 22.2 0.0 0.0 0.0 0.0 0.1 10.1 23.7 21.4 16.4 13.6 14.6 66 0.92 23 Sd vfg vshy slty 26 3954.0 15.0 22.8 0.0 0.0 0.0 0.0 0.5 13.2 26.0 19.1 13.9 12.8 14.6 60 0.89 26 Sd vfg shy slty 25 3955.0 6.6 21.5 0.0 0.0 0.0 0.0 0.8 12.0 20.7 18.2 17.1 15.1 16.2 67 0.98 24 Sd vfg shy lam(4) slty 24 3956.0 7.8 22.1 0.0 0.0 0.0 0.0 0.1 11.1 27.6 20.2 13.3 12.$ 14.9 61 0.90 25 Sd vfg vshy slty 23 3957.0 4.3 21.1 0.0 0.0 0.0 0.0 0.0 3.8 15.2 24.5 22.2 17.0 17.3 81 1.06 16 Sd vfg vshy slty 22 3958.0 2.9 20.5 0.0 0.0 0.0 0.0 0.0 1.3 6.5 10.8 27.9 23.2 30.3 92 1.86 8 Sd of-slt vshy slty scalc 21 3959.0 No Recovery 20 3960.0 30.0 23.5 0.0 0.0 0.0 0.0 1.0 20.4 28.6 13.7 11.5 11.8 13.0 50 0.79 33 Sd vfg shy-vshy slty 19 3961.0 Mudcake 18 3962.0 18.0 22.9 0.0 0.0 0.0 0.0 0.3 14.3 26.7 18.0 13.7 12.9 14.0 59 0.86 28 Sd of-slt shy-vshy 17 3963.0 12.0 22.5 0.0 0.0 0.0 0.0 0.0 6.3 27.4 26.8 14.4 11.3 13.8 66 0.87 23 Sd of-slt shy-vshy 16 3964.0 15.0 22.8 0.0 0.0 0.0 0.0 0.1 11.1 25.7 20.5 14.7 13.1 14.9 63 0.91 25 Sd of-slt shy-vshy 15 3965.0 Mudcake 14 3966.0 4.9 21.3 0.0 0.0 0.0 0.0 0.0 0.0 3.7 20.8 28.2 22.5 24.8 96 1.46 10 Sd of-slt vshy 13 3967.0 5.1 20.8 0.0 0.0 0.0 0.0 1.0 10.5 17.1 16.2 18.9 17.7 18.6 71 1.11 21 Sd of-slt vshy Page 9 of 16 ~~~ Care Laki NESPNYOIH UPSIHiZXT(ON ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska PARTSIZ sM ANALYSIS FILE NO. : HOU-070058 DATE :January 29, 2007 DRLG FLUID :Water Based Mud ANALYSTS : MCG, TW CORES :Baker Hughes SHOT DEPTH Kair POR SAND % SILT % CLAY Vsh Cs MEAN NO. (ft) (mD)' (%) GRVL VCRS CRS MED FIN VFIN CRS MED FINE VFIN (%) (%) (m`/cc) (µ) LITHOLOGY 12 3998.0 8.2 21.9 0.0 0.0 0.0 1.2 3.1 5.1 6.6 9.8 29.1 23.4 21.6 84 1.42 11 Sd of-slt vshy lam(4) slty 11 4052.0 Shale 10 4053.0 No Recovery 9 4058.0 Shale 8 4059.0 No Recovery 7 4060.0 Mudcake 6 4061.0 Mudcake 5 4062.0 165.0 25.3 0.0 0.0 0.0 0.4 17.8 31.7 14.6 7.9 8.6 8.6 10.3 35 0.61 60 Sd vfg shy slty 4 4063.0 230.0 25.7 0.0 0.0 0.0 0.2 17.8 34.0 12.9 6.9 9.8 8.7 9.6 35 0.59 61 Sd vfg shy slty 3 4064.0 85.0 23.8 0.0 0.0 0.0 0.0 12.6 30.0 13.1 7.9 11.9 11.2 13.4 44 0.78 51 Sd vfg shy slty 2 4065.0 110.0 24.4 0.0 0.0 0.0 0.0 13.0 32.6 14.7 7.5 11.2 10.3 10.8 40 0.66 53 Sd vfg shy slty 1 4066.0 No Recovery 50 4067.0 255.0 26.4 0.0 0.0 0.0 0.0 17.0 36.2 13.1 6.5 9.8 8.6 8.8 34 0.55 61 Sd vfg sshy sslty 49 4068.0 465.0 28.2 0.0 0.0 0.0 0.3 20.9 36.8 11.2 6.0 9.4 7.9 7.6 31 0.50 67 Sd of-fg shy sslty scalc 48 4069.0 295.0 25.1 0.0 0.0 0.0 0.0 16.3 38.4 13.7 5.9 9.6 8.2 8.1 32 0.52 61 Sd vfg sshy sslty 47 4070.0 380.0 27.4 0.0 0.0 0.0 0.2 19.7 37.0 11.8 6.1 9.4 8.0 7.8 31 0.51 65 Sd of-fg shy sslty calc 46 4071.0 55.0 22.8 0.0 0.0 0.0 0.0 3.6 24.7 23.0 11.8 12.6 11.9 12.4 49 0.77 38 Sd vfg shy sshy 45 4072.0 80.0 23.4 0.0 0.0 0.0 0.0 5.7 27.6 21.4 10.1 12.1 11.4 11.7 45 0.72 42 Sd of-fg shy sshy scalc 44 4073.0 75.0 23.3 0.0 0.0 0.0 0.0 4.2 26.2 23.9 11.3 11.8 11.2 11.5 46 0.72 40 Sd vfg shy slty 43 4074.0 90.0 24.0 0.0 0.0 0.0 0.0 7.4 30.4 19.8 9.0 11.6 10.7 11.2 42 0.69 46 Sd vfg shy slty 42 4075.0 No Recovery 41 4076.0 No Recovery 40 4077.0 No Recovery 39 4078.0 No Recovery 38 4079.0 15.0 22.3 0.0 0.0 0.0 0.0 0.0 10.5 27.1 20.7 13.7 13.3 14.7 62 0.89 25 Sd vfg shy slty scalc 37 4080.0 20.0 22.4 0.0 0.0 0.0 0.0 0.0 11.2 30.7 20.7 12.2 12.5 12.6 58 0.80 26 Sd vfg vshy-shy slty scalc 36 4081.0 No Recovery 35 4082.0 100.0 23.6 0.0 0.0 0.0 0.0 5.6 28.4 24.6 9.9 10.9 10.5 10.2 41 0.65 42 Sd vfg shy slty Page 10 of 16 :I. ~~. Care Lab flLSEflVOIR Of?IN72A2(aN ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska PARTSIZ sM ANALYSIS FILE NO. : HOU-070058 DATE :January 29, 2007 DRLG FLUID :Water Based Mud ANALYSTS : MCG, TW CORES :Baker Hughes SHOT NO. DEPTH (ft) Kair (mD)' POR (°!°) GRVL VCRS CRS SAND % MED FIN VF1N CRS SILT % MED FINE VFIN CLAY (%) Vsh (%) Cs (m`/cc) MEAN (µ) LITHOLOGY 34 4083.0 9.3 22.0 0.0 0.0 0.0 0.0 0.0 8.1 27.1 22.4 14.0 13.6 14.7 65 0.90 23 Sd vfg shy-vshy vslty 33 4084.0 20.0 22.7 0.0 0.0 0.0 0.0 0.1 15.5 30.3 16.1 12.1 12.9 13.1 54 0.82 29 Sd vfg shy vslty 32 4085.0 12.0 22.5 0.0 0.0 0.0 0.0 0.0 0.2 6.3 10.4 29.6 .26.5 27.0 94 1.65 8 Sd of-slt shy lam(4) scalc 31 4086.0 3.8 21.0 0.0 0.0 0.0 0.0 0.0 3.0 5.0 6.1 30.8 31.9 23.1 92 1.44 8 Sd of-slt shy-vshy 30 4087.0 4.6 21.5 0.0 0.0 0.0 0.0 0.4 4.2 6.1 8.4 31.1 28.8 21.0 89 1.36 9 Sd of-slt shy-vshy scalc 29 4088.0 16.0 22.4 0.0 0.0 0.0 0.0 1.1 14.9 21.4 15.5 16.4 15.6 15.2 63 0.93 27 Slt vshy w/ sd lam 28 4120.0 Mudcake 27 4122.0 750.0 32.1 0.0 0.0 0.0 0.3 17.9 35.6 15.0 6.4 8.9 7.6 8.3 31 0.54 63 Sd of-fg sshy sslty scalc 26 4123.0 685.0 28.9 0.0 0.0 0.0 0.0 15.3 37.4 16.7 6.6 9.2 7.8 7.0 31 0.48. 61 Sd of-fg sshy slty 25 4124.0 900.0 32.9 0.0 0.0 0.0 0.6 24.8 38.0 10.4 5.1 7.8 6.5 6.7 26 0.45 75 Sd of-fg vshy sshy scalc 24 4125.0 195.0 25.5 0.0 0.0 0.0 0.0 6.1 30.5 22.4 8.7 11.2 10.9 10.2 41 0.65 44 Sd vfg sshy slty scalc 23 4126.0 450.0 27.6 0.0 0.0 0.0 0.0 11.9 37.1 19.1 6.5 9.6 8.4 7.5 32 0.51 56 Sd of-slt shy slty 22 4127.0 225.0 25.6 0.0 0.0 0.0 0.0 9.8 35.0 19.2 7.3 10.6 9.3 8.7 36 0.57 51 Sd vfg shy slty scalc 21 4128.0 635.0 29.1 0.0 0.0 0.0 0.0 17.1 36.2 15.2 6.3 9.4 8.2 7.5 31 0.51 62 Sd of-fg sshy slty scalc 20 4129.0 165.0 25.8 0.0 0.0 0.0 0.0 9.3 32.0 19.1 8.7 11.0 9.9 9.8 39 0.63 49 Sd vfg sshy slty scalc 19 4130.0 245.0 25.9 0.0 0.0 0.0 0.0 9.3 33.7 19.8 7.8 10.7 9.7 9.1 37 0.59 50 Sd vfg sshy slty scalc 18 4131.0 285.0 26.5 0.0 0.0 0.0 0.0 10.3 34.7 19.2 7.4 10.3 9.4 8.7 36 0.57 52 Sd of-fg shy slty scalc 17 4132.0 135.0 24.2 0.0 0.0 0.0 0.0 7.8 32.2 20.8 8.3 11.0 10.2 9.7 39 0.62 47 Sd vfg shy slty scalc 16 4133.0 95.0 23.6 0.0 0.0 0.0 0.0 7.7 32.6 20.6 8.2 11.2 10.2 9.4 39 0.61 47 Sd vfg shy slty scalc 15 4134.0 125.0 24.3 0.0 0.0 0.0 0.0 10.3 34.4 18.4 7.4 10.8 9.7 9.1 37 0.59 51 Sd vfg shy slty scalc 14 4135.0 100.0 24.6 0.0 0.0 0.0 0.0 8.7 32.1 19.5 8.3 11.3 10.5 9.7 40 0.62 48 Sd vfg shy slty 13 4136.0 210.0 26.8 0.0 0.0 0.0 0.0 10.0 34.0 19.5 7.8 10.4 9.3 9.0 37 0.58 51 Sd of-fg shy slty 12 4137.0 20.0 22.4 0.0 0.0 0.0 0.0 0.8 12.4 18.2 14.3 17.8 17.4 19.1 69 1.13 23 Sd vfg shy lam(3) vshy 11 4138.0 40.0 22.6 0.0 0.0 0.0 0.0 2.7 24.0 24.5 11.1 12.8 12.8 12.0 49 0.76 36 Sd vfg shy slty scalc 10 4139.0 90.0 23.6 0.0 0.0 0.0 0.0 6.5 30.9 21.8 8.9 11.6 10.7 9.7 41 0.63 45 Sd vfg shy vshy 9 4140.0 105.0 24.8 0.0 0.0 0.0 0.0 6.6 31.6 21.0 8.4 11.6 10.8 10.0 41 0.64 46 Sd vfg shy vshy 8 4165.0 310.0 27.1 0.0 0.0 0.0 0.0 11.7 35.4 18.0 6.8 10.6 9.3 8.2 35 0.55 54 Sd of-fg shy slty Page 11 of 16 s. Core Lab XES~NYOIN flPiINIZAt ION ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska PARTSIZ s"' ANALYSIS FILE NO. : HOU-070058 DATE :January 29, 2007 DRLG FLUID :Water Based Mud ANALYSTS : MCG, TW CORES :Baker Hughes SHOT DEPTH Kair POR SAND % SILT % CLAY Vsh Cs MEAN NO. (ft) (mD)" (%) GRVL VCRS CRS MED FIN VFIN CRS MED FINE VFIN (%) (%) (m`icc) (µ) LITHOLOGY 7 4171.0 435.0 28.1 0.0 0.0 0.0 0.0 12.0 37.5 17.9 6.3 9.8 8.5 8.0 33 0.53 56 Sd of-fg shy slty 6 4172.0 160.0 25.8 0.0 0.0 0.0 0.0 8.2 30.5 18.6 8.8 12.3 11.2 10.3 43 0.66 47 Sd vfg shy slty 5 4173.0 410.0 27.2 0.0 0.0 0.0 0.0 13.6 36.2 16.2 6.6 10.1 8.8 8.4 34 0.55 57 Sd of-fg shy slty 4 4174.0 440.0 27.7 0.0 0.0 0.0 0.1 16.2 37.4 14.5 6.3 9.7 8.2 7.6 32 0.50 61 Sd of-fg shy slty 3 4175.0 110.0 23.6 0.0 0.0 0.0 0.0 6.5 31.3 21.0 8.2 11.8 11.1 10.2 41 0.65 45 Sd vfg shy slty 2 4176.0 65.0 23.1 0.0 0.0 0.0 0.0 4.4 27.6 22.9 9.9 12.3 11.9 11.1 45 0.70 41 Sd vfg shy slty 1 4177.0 9.8 22.2 0.0 0.0 0.0 0.0 1.9 18.1 23.0 14.4 14.7 13.9 14.0 57 0.86 31 Sd of-slt vshy slty Page 12 of 16 ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska ~. Core Lab AGSrPV01A aPiJNIZAtIOH LAMSPEC sM ANALYSIS FILE NO. : HOU-070058 DATE :January 29, 2007 DRLG FLUID :Water Based Mud ANALYSTS : MCG, TW CORES :Baker Hughes SMPL. DEPTH Kair POR LamSpec SAND % SILT % CLAY Vsh Cs MEAN NO. (ft) (mD)* (%) Perm CRS MED FIN VFIN CRS MED FINE VFIN (%) (%) (m`/cc) (µ) LITHOLOGY 47 3823.0 255.0 26.6 700.0 0.0 3.2 35.8 33.5 6.9 7.6 4.9 3.9 4.3 21 0.31 104 Sd of-fg shy-sshy lam(2) sslty scalc 27 3865.0 9.5 21.8 30.0 0.0 0.0 5.8 21.9 20.3 14.3 18.4 11.4 7.9 52 0.67 38 Sd of-slt vshy vscalc 25 3867.0 85.0 24.7 100.0 0.0 0.0 7.6 25.3 21.4 12.7 14.8 9.8 8.5 46 0.65 43 Sd vfg shy lam(2) slty 19 3873.0 8.2 20.4 20.0 0.0 0.0 4.5 17.3 23.0 16.0 16.2 11.8 11.3 55 0.79 33 Sd vfg shy lam(4) slty 16 3876.0 5.3 20.6 40.0 0.0 0.0 4.0 19.1 27.3 16.5 15.4 9.7 8.0 50 0.66 35 Sd of-slt shy lam(3) slty 3 3895.0 5.5 21.7 140.0 0.0 1.9 18.9 30.6 17.0 10.4 8.3 5.9 6.9 32 0.47 68 Sd of-slt vshy w/ sd lam fg 2 3896.0 625.0 28.5 660.0 5.1 29.9 28.7 9.2 6.7 7.4 6.2 3.2 3.7 20 0.29 176 Sd f-mg shy sslty 48 3901.0 9.1 22.2 300.0 0.0 3.1 33.7 32.2 6.6 6.8 8.5 4.6 4.5 24 0.36 93 Sd fg vshy lam(4) slty talc 42 3907.0 185.0 25.3 280.0 0.0 0.5 15.1 28.2 17.8 10.9 13.1 7.9 6.5 38 0.54 56 Sd fg shy lam(3) slty 38 3911.0 45.0 23.4 60.0 0.0 0.0 8.2 28.4 21.1 11.2 11.7 9.8 9.6 42 0.62 46 Sd vfg shy sslty 25 3955.0 6.6 21.5 20.0 0.0 0.0 2.9 25.4 25.5 13.9 12.1 10.0 10.1 46 0.66 39 Sd vfg shy lam(4) slty 16 3964.0 15.0 22.8 25.0 0.0 0.0 0.1 13.2 29.3 20.9 13.4 11.4 11.8 57 0.76 28 Sd of-slt shy-vshy 13 3967.0 5.1 20.8 20.0 0.0 0.0 2.6 19.4 24.9 16.6 13.4 11.0 12.1 53 0.74 33 Sd of-slt vshy 12 3998.0 8.2 21.9 12.0 0.0 0.0 0.0 1.0 18.4 22.3 28.1 17.4 12.8 81 1.02 16 Sd of-slt vshy lam(4) slty 32 4085.0 12.0 22.5 30.0 0.0 0.0 0.0 6.8 26.1 23.7 15.5 14.2 13.8 67 0.85 22 Sd of-slt shy lam(4) scalc 12 4137.0 20.0 22.4 35.0 0.0 0.0 0.3 12.8 26.3 20.6 14.8 10.5 14.7 61 0.88 27 Sd vfg shy lam(3) vslty 1 4177.0 9.8 22.2 45.0 0.0 0.0 1.6 22.7 27.2 15.3 11.6 10.0 11.6 48 0.72 36 Sd of-slt vshy slty Lamspec Perm is the permeability of only the sand portion of the laminated sample. Laser optics particle size analysis is used to determine the percent sand, percent silt, percent clay, percent shale by volume (Vsh), surface area (Cs), and mean grain size. These measured parameters are factors in the determination of permeability of the sand laminations. ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska f Core Lal] PESENVLLIA UY7INIZATIDN Viscosity Measurements Spl Depth Viscosity Oil Density No. (ft) °API (cP) (glcc) 45 3904.0 7 2244 (2) 47 4070.0 20 (1) (2) 27 4122.0 31 868 (2) Footnotes File No : HOU-070058 Date: February 6, 2007 Analysts: MS Viscosity measured at 50 deg C API gravity determined by refractive index of retorted oil sample • (1) :Denotes insufficient oil extracted from sample for sheer stress viscosity measurement. (2) :Denotes insufficient oil extracted from sample for oil density measurement by pycnometer. Core Lab AESCAY0111 ~Pi1HiZATfiIN ENI Petroleum Rock Flour #2 Prudhoe Bay North Slope, Alaska SIDEWALL CORE ANALYSIS -CORE QUALITY INDEX FILE NO.: : HOU-070058 DATE : :January 29, 2007 DRLG FLUID :Water Based Mud ANALYSTS : : MCG, TW CORES :Baker Hughes Core Quality RECOVERY EFFICIENCY CORE QUALITY 100% -_~._..._...___..._._.....____._....____._....r..__....., Total cores attempted = 146 A Excellent 61 46% Total cores recovered = 133 B Good 57 43% 60% C Fair 7 5% a0% - -- Recovery Efficiency = 91 % D Poor 8 6% F Muddy/Insufficient 0 0% 20% - ---- 0% T A B C D F Core Recovery 100% ........__..__.._._ _~ __.~ _..._.__..____.......~.__.___~,., CORE BULLET INFO CORE RECOVERY SIZE ~ 80% -__-- - -~ Bullet diameter: 4 Full recovery (> 1") 95 65% 60% ------ ----- Bullet type: 3 Good recovery (>0.5" - 1 ") 35 24% Retaining wire length: 2 Fair recovery (0.25" - .5") 3 2% 40% Retaining wire type; 1 Poor recovery (<0.25") 0 0% 20% _- Charge: NR No recovery 13 9% 0% .. 4 3 2 1 NR Note: Core Quality Index (CQI) is a visual rescription of core grain recovery based upon two measures: 1) Core quality -Affected by mud invasion, shattering of grains, ability to use core for additional tests. 2) Core recover size -Amount of core recovered. • Page 15 of 16 ENI Petroleum FILE NO. : HOU-070058 Rock Flour #2 Core Lab DATE :Jan 29, 2007 Prudhoe Bay A~SeA~ro~AOP~~n,~~T~~k DRLG FLUID :Water Based Mud North Slope, Alaska ANALYSTS : MCG, TW CORES :Baker Hughes DESCRIPTION CODE KEY AND ABBREVIATIONS INTERLAMsm THIN BED SAMPLE DESCRIPTION LITHOLOGY FLUORESCENCE INTENSITY Anhy Anhydrite ev even bt bright Cgl Conglomerate stk streaks(ed) ft faint Dol Dolomite spt spots(ed) dl dull Glauc Glauconite mott mottled vft very faint H Halite Lig Lignite COLOR MODIFIERS Ls Limestone b blue u unconsolidated Pyr Pyrite b-w blue-white vs very slightly Sd Sand bz bronze s slightly Sh Shale gld gold m moderately Slt Silt w white mw moderately well Sf Shell Fragments y yellow v very w well GRAIN SIZE OTHER vfg very fine grain calc calcareous ha high angle fg fine grain cln clean hd hard mg medium grain Garb carbonaceous lam laminated(ion) cg coarse grain cem cementation mic micaceous con consolidated ms mudshot dns dense shy shaley flu fluorescence slty silty foss fossiliferous tr trace frc fractured(s) vug vuggy fl flushed vt vertical PRODUCTION CODES OTHER ABBREVIATIONS Gas gas Por porosity, Oil oil Gb gas saturation, % bulk volume Cond condensate Ob oil saturation, % bulk volume Water water Sco core oil saturation, % pore volume (1) altered core Stw total water saturation, % pore volume (2) exposed core Sciw critical water saturation, % pore volume (3) insufficient sample Vsh volume of shale, % bulk volume (4) contaminated core Cs surface area (m`/cc) (5) Mean mean grain size, microns (6) low permeability FOOTNOTES permeability values determined empirically *` Sciw values after Gran berry, R.J. and Keela n, D.K., 1977 "` samples interpreted without knowledge of depth or intervals TYPE 1 TYPE 2 _ „~r~,y 1/ / J ~ \ ~~ _~ ~ - 1 u~~ i. ~ SHALE LAMINATIONS < 1 mm SHALE LAMINATIONS 1-5 mm TYPE 3 TYPE 4 .................. ~~~ :~s SHALE LAMINATIONS 5-10 mm SHALE LAMINATIONS > 10 mm SCHLUMBERGER Survey report Client .................... Field ..................... Well ...................... API number ................ Engineer .................. Rig ...................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS............ ENI Petroleum Rock Flour Rock Flour 2 500292333570 P. Harris Nabors 27e Alaska ethods------------ Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Depth GL above permanent.......: 70.80 ft KB above permanent.......: 104.40 ft DF above permanent.......: 104.40 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target: 0.00 degrees 12-Jan-2007 18:52:30 Page 1 of 3 Spud date ................: 12-27-07 Last survey date.........: 12-Jan-07 Total accepted surveys...: 52 MD of first survey.......: 0.00 ft MD of last survey........: 4332.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date............: 29-Dec-2006 Magnetic field strength..: 1152.47 HCNT Magnetic dec (+E/W-)...... 23.76 degrees Magnetic dip .............: 80.84 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G ............... H ............... Dip ............. of G............ of H..... ...... of Dip.......... Criteria --------- 1002.68 meal 1152.47 HCNT 80.84 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.76 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.76 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 12-Jan-2007 18:52:30 Page 2 of 3 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- - (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 -------- 0.00 -------- 0.00 -------- 0.00 - ------ 0.00 ------- 0.00 -------- 0.00 ----- 0.00 ----- TIP ------ None 2 104.10 0.22 114.66 104.10 104.10 -0.08 -0.08 0.18 0.20 114.66 0.21 MWD_M None 3 192.02 0.35 114.66 87.92 192.02 -0.27 -0.27 0.58 0.64 114.66 0.15 MWD_M None 4 228.12 0.06 114.66 36.10 228.12 -0.32 -0.32 0.70 0.77 114.66 0..80 MWD_M None 5 281.69 0.17 318.78 53.57 281.69 -0.27 -0.27 0.67 0.72 112.08 0.42 MWD M None 6 373.06 0.16 239.63 91.37 373.06 -0.23 -0.23 0.47 0.53 116.48 0.23 MWD_M None 7 462.25 0.15 260.83 89.19 462.25 -0.32 -0.32 0.25 0.40 141.91 0.06 MWD_M None 8 553.95 0.22 295.13 91.70 553.95 -0.26 -0.26 -0.03 0.26 186.67 0.14 MWD M None 9 645.27 0.38 308.85 91.32 645.27 0.00 0.00 -0.42 0.42 270.58 0.19 _ MWD_M None 10 737.89 0.63 307.37 92.62 737.88 0.51 0.51 -1.07 1.18 295.33 0.27 MWD M None it 830.49 0.62 311.64 92.60 830.48 1.15 1.15 -1.85 2.18 301.85 0.05 MWD_M None 12 922.49 0.51 297.16 92.00 922.47 1.67 1.67 -2.58 3.07 302.80 0.20 MWD_M None 13 1018.53 0.54 297.31 96.04 1018.51 2.07 2.07 -3.37 3.95 301.56 0.03 MWD_M None 14 1111.33 0.66 288.72 92.80 1111.30 2.44 2.44 -4.26 4.91 299.80 0.16 MWD_M None 15 1205.81 0.87 309.92 94.48 1205.77 3.08 3.08 -5.33 6.15 300.00 0.37 MWD M None 16 1301.18 0.88 301.04 95.37 1301.13 3.92 3.92 -6.51 7.60 301.04 0.14 MWD M None 17 1399.35 0.91 299.44 98.17 1399.29 4.69 4.69 -7.83 9.13 300.90 0.04 _ MWD_M None 18 1497.09 0.38 324.13 97.74 1497.02 5.33 5.33 -8.70 10.21 301.51 0.60 MWD M None 19 1590.42 0.31 310.50 93.33 1590.35 5.75 5.75 -9.07 10.74 302.36 0.12 _ MWD M None 20 1687.58 0.32 277.74 97.16 1687.51 5.96 5.96 -9.54 11.25 301.97 0.18 _ MWD M None 21 1783.67 0.30 269.24 96.09 1783.60 5.99 5.99 -10.06 11.71 300.77 0.05 MWD M None 22 1876.45 0.35 273.42 92.78 1876.38 6.00 6.00 -10.59 12.17 299.55 0.06 _ MWD M None 23 1946.59 0.26 267.10 70.14 1946.52 6.01 6.01 -10.96 12.50 298.73 0.14 _ MWD_M None 24 2079.54 0.55 296.98 132.95 2079.46 6.28 6.28 -11.83 13.39 297.97 0.26 MWD None 25 2147.28 0.54 299.88 67.74 2147.20 6.59 6.59 -12.39 14.04 297.99 0.04 MWD None 26 2175.08 0.46 290.53 27.80 2175.00 6.69 6.69 -12.61 14.28 297.95 0.41 MWD None 27 2270.21 0.52 279.92 95.13 2270.13 6.90 6.90 -13.40 15.07 297.25 0.11 MWD None 28 2366.91 0.41 289.01 96.70 2366.82 7.09 7.09 -14.15 15.83 296.60 0.14 MWD None 29 2463.95 0.21 287.39 97.04 2463.86 7.25 7.25 -14.65 16.35 296.34 0.21 MWD None 30 2560.78 0.37 301.41 96.83 2560.69 7.47 7.47 -15.09 16.84 296.34 0.18 MWD None • SCHLUMBERGER Survey Report 12-Jan-2007 18:52:30 Page 3 of 3 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (f t) -------- (ft) -------- (ft) -------- (ft) -------- (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 31 -------- 2654.52 ------ 0.59 ------- 296.62 ------ 93.74 -------- 2654.43 -------- 7.84 -------- 7.84 -------- -15.78 ------- 17.62 -------- 296.44 ----- 0.24 ----- MWD ------ None 32 2752.56 0.60 291.03 98.04 2752.46 8.26 8.26 -16.71 18.64 296.29 0.06 MWD None 33 2844.96 0.64 289.06 92.40 2844.86 8.60 8.60 -17.65 19.63 295.97 0.05 MWD None 34 2939.43 0.80 290.72 94.47 2939.32 9.00 9.00 -18.76 20.81 295.63 0.17 MWD None 35 3034.64 0.64 288.41 95.21 3034.52 9.41 9.41 -19.89 22.00 295.31 0.17 MWD None 36 3129.09 0.63 274.82 94.45 3128.97 9.62 9.62 -20.91 23.01 294.70 0.16 MWD None 37 3224.32 0.56 263.56 95.23 3224.19 9.61 9.61 -21.89 23.91 293.70 0.14 MWD None 38 3319.63 0.32 240.77 95.31 3319.50 9.43 9.43 -22.59 24.48 292.65 0.31 MWD None 39 3414.97 0.53 212.30 95.34 3414.84 8.92 8.92 -23.06 24.72 291.16 0.31 MWD None 40 3509.26 0.66 222.77 94.29 3509.12 8.16 8.16 -23.66 25.02 289.02 0.18 MWD None 41 3602.38 0.73 227.56 93.12 3602.23 7.36 7.36 -24.46 25.54 286.75 0.10 MWD None 42 3695.72 0.73 222.25 93.34 3695.57 6.52 6.52 -25.30 26.12 284.45 0.07 MWD None 43 3788.95 0.78 217.01 93.23 3788.79 5.57 5.57 -26.08 26.67 282.06 0.09 MWD None 44 3822.69 0.72 211.44 33.74 3822.52 5.21 5.21 -26.33 26.84 281.19 0.28 MWD None 45 3882.49 0.63 224.73 59.80 3882.32 4.66 4.66 -26.76 27.16 279.87 0.30 MWD None 46 3977.43 0.49 225.36 94.94 3977.26 4.00 4.00 -27.41 27.70 278.30 0.15 MWD None 47 4042.71 0.57 236.16 65.28 4042.53 3.62 3.62 -27.88 28.11 277.40 0.20 MWD None 48 4072.84 0.45 222.05 30.13 4072.66 3.45 3.45 -28.08 28.29 277.01 0.57 MWD None 49 4166.53 0.36 239.89 93.69 4166.35 3.03 3.03 -28.58 28.74 276.05 0.16 MWD None 50 4259.60 0.06 350.75 93.07 4259.42 2.93 2.93 -28.85 28.99 275.80 0.41 MWD None 51 4302.62 0.17 314.46 43.02 4302.44 3.00 3.00 -28.89 29.05 275.93 0.29 MWD None 52 +..4332.00 0.17 314.46 29.38 4331.82 3.06 3.06 -28.96 29.12 276.03 0.00 PROD None u [(c)2007 IDEAL ID12 OC O1] NOTES 1. DATE OF SURVEY: JAN. 4-5, 2007. 2. REF. FIELD BOOK: M107-01 PGS.4-10. 3. COORDINATES ARE ALASKA STATE PLANE ZONE 4, NAD 27. 4. GEODETIC POSITIONS ARE NAD 27. 5. PAD AVERAGE SCALE FACTOR: 0.999907827. 6. HORIZONTAL AND VERTICAL CONTROL IS BASED ON NGS OPUS-CORS SOLUTIONS USING DSL1, PU01 AND EDOC CORS STATIONS WITH ELEVATION REDUCED TO ORTHOMETRIC ELEVATION USING GEOID99 MODEL. LEGEND ~- WELL AS-STAKE / A5-BUILT 0 SURVEY CONTROL --EDGE OF ICE ROADS AND PADS oSKIDS AND STRUCTURES ~ DRAINAGE PATTERN ROCK FLOUR ? ~, _, '- .-'' ~~ RP 400 ` ` --~- ''~-,.- `~`. NABORS R[G 27-E ~ ~ ~ ~_ _ -- MI0605~2F~'~, ` ,~ ~~ 70 -N- ~~. _, I -' - ' W/LINER CUTTING TANK DIESEL FUEL TANK ~ ~~RP 200,' & CHEMICAL TANK ~ ~, 0 W/LINER ~ ~\ ~:'~ _, _ .;s a - _ [Ct; PAD ~ 4VE. PA~ EL. 1' ---- ~.- ~ 4' ~ lµ f ` ~ - ~, ~~ .o ~ _ } .~~~ ~ ~! t '.~ ? _ a ti ~~i A : t ~, ~ ,X__ VICINITY MAP - TANK SK]D N.T.S. -GENERATOR HEA TERS W%L[NER DUMPSTER '` ~~ EXTRA CAMP ~ ACS CONVEX ; , ~ ' + `, ~~ ' SNOW MELTER ~ '. ~ '~ ~y , ~_ ~ ~ _ ' < i ~ ~~ W/LINER - `, -LAKE ~ K - ~'~ ' y~q SOU - ~ ,, - __, ~ ' ~~~ ~~ ` ' - _-,~ ,`.~ .~ w ~ ~ _ 0 ~`~~ ~~~ `_~ __ ICE ~~ i ~ ~~ °"~ ~ ~ ~ RDA To ~~~ '~~`,~ I --- ~ _ W ,_ ATE ' • ~ ~'!'~ ~ R SOU ,~ \~` ~ ~' '~ " ' ' ~ `~ ~' `"- -- MI06050 A RCE . e OILY WASTE DUMPSTER ~ 1 ~' ' '- ~~'~ ,-- 70 , , _~ .. STEEL STORAGE ---~ ` -- ___ ~e - --- TOOL SKID ----- __~-----;__'-_-_=-----_ - ____, ELECTRICAL SKID ~ ,` __- ~~-'-~-----_~-~ =----- -__ ~~ ~,_ - SHOP ~ 68 ,r' GENERATOR WELD SKID ~ ~ ~ GENERATION & FUEL TANK -' WATER TREATMENT LOCATED WITHIN PROTRACTED SECTION 28, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSIT]ON(D.DD) BOX ELEV. OFFSETS RF 2 Y=5,953,995.72 N= N/A 70'17'03.987" 70.284441' 70 8 4730' FSL - X= 577 861.20 E= N A 149'22'11.570" 149.369881' ' 4089' FEL F. Robert ~"~~ MiN~ E N 1 oats, ~~~~ PETROLEUM ALASKA Fixso7EN101-0o ENI PETROLEUM ,AAA N0. ~~~ ~~~o ROCK FLOUR #2 °~~°~~ PAD-RIG AS-BUILT SHEEP: OF 1 ROCK HOUR #2 [PNl As Plugged & Abandoned 20" conductor Bridge plug at 250' set @ 110' ~ ~ RKB w/permafrost cement to surface 9.4 ppg mud 1,850' ~ 13-3/8", 68#, L-80, BTC surf csg set at f~ 2,005' f 2,955' - 2,965' 3,010' - 3,018' 3,159' - 3,173' 3,330' - 3,340' 10-5/8" open hole filled w/ cement 3,370' - 3,380' Hydrocarbon- w/ 3 stages bearing Intervals 3,580' - 3,590' 3,640' - 3,670' 3,684' - 3,692' 3,710' - 3,716' 3,746' - 3,760' 3,778' - 3,793' ~` TD @ 4,332' MD/ TVD 3,892' - 3,912' wjp 12/13/07 • • OPERATIONS SUMMARY Eni Petroleum Rock Flour #2 December 22, 2006 a~~ ~~~~ ~"`~~ Move Nabors Rig ~ subbase onto pad. Lay out liner over rig footprint. Move pipe shed, pits, generators, pump room, camp and camp generators onto pad. Spot subbase over conductor. Move motor complex onto pad and spot pits. December 23, 2006 Continue rigging up: Spot matting boards and liner. Spot pits, motors, pipe shed and satellite camp. Run power cables and hook up service lines. Spot pump house and hook up interconnects between rig modules. December 24, 2006 Continue rigging up: Spot and rig up pipe shed heaters. Berm around rig. Complete transfer of equipment from stack location to drill pad. Repair faulty fuel pump on #2 boiler. Spot bulk fuel tank. Complete rig berms. Complete interconnects between rig modules. Function test top drive, drawworks and rotary table. Cut off conductor pipe and commence installation of starting flange. Rig up satellite camp generator. December 25, 2006 Rig accepted 00:00 hrs, 12/25/06. Install pipe skate rail, service drawworks, connect suction line. Weld on wellhead and conductor. Prep mud pits for mud. N/LT diverter system. Take on 331 bbls spud mud, load pipe in pipe shed. December 26, 2006 N/LJ diverter system and flare line. P/LT 5" DP while rigging up service companies. December 27, 2006 MW 8.5 ppg Vis 200 sec P/Ll 5" DP while rigging up service companies. Install rotary table drip pan, install mouse hole. P/LT and M/iJ BHA. Function test diverter -witnessed by AOGCC rep. M/U additional BHA. Pressure test surface equipment. P/U and orient MWD. RIH, tag bottom at 110' RKB. Fill hole with water, check for leaks, displace hole w/ 8.8 ppg, 250 vis spud mud. Unable to operate mud pump #2. POH w/ one stand HWDP and trouble shoot mud pump. December 28, 2006 MW 9.1 ppg Vis 250 sec -~ Trouble shoot electrical problem with mud pump #2. Drill from 110' to 262' . Trouble shoot MWD decoding problems. Change out mud pressure sensor. Drill to 351' to bury BHA. POH three stands. P/L1 16" stb, ream back to bottom (20' of fill). Drill from 351' to 1,061'. • i Inclination Surveys: 0.64° at 738' 0.63 ° at 830' 0.52° at 922' December 29, 2006 MW 9.2 ppg Vis 130 sec Drill 16" hole from 1,061' to 2,015'. C&C hole, short trip to conductor shoe, RIH. Hole in good shape. C&C for running casing, POH. Inclination Surveys: 0.30° at 1,784' 0.35° at 1,876' 0.26° at 1,947' 0.26° at 2,015' December 30, 2006 MW 9.2 ppg Vis 60 sec L/D BHA, clean rig floor, prepare to run casing. Run 51 joints of 13-3/8", 68#, L-80, BTC casing. C&C for cementing. Test lines to 2,500 psi. Pump 50 bbls spacer, drop bottom plug, pump 590 sx Arcticset Lite (465 bbls, 10.7 ppg) and 210 sx Arcticset I tail (35 bbls, 15.7 ppg). Drop top plug, displace with mud. Bump plug, check floats - OK. Clean cellar, flush diverter, blow down cement line. December 31, 2006 MW 9.2 ppg Vis 60 sec WOC. Filter cement returns for delivery to disposal facility, clean pits, R/D casing running equipment. N/D diverter, cut & prep surface casing, N/U wellhead. January 1, 2007 MW 9.2 ppg Vis 60 sec Pressure test wellhead. N/L7 BOPE, bell nipple and flowline. Pressure test BOPE to 250 / 5,000 psi. Thaw frozen lines and equipment. January 2, 2007 MW 9.4 ppg Vis 102 sec Thaw frozen lines. P/LT and M/LT 12-1/4" cleanout BHA. RIH to 1,837', pressure test casing to 3,000 psi for 30 minutes - OK. RIH to FC at 1,918'. Drill FC, cmt, FS and 20' of new formation to 2,035'. Pull bit into shoe and conduct LOT to 12.3 ppg EMW. Displace 9.3 ppg spud mud from well with 9.5 ppg FloPro system. Obtain slow pump rates and POH. January 3, 2007 MW 9.4 ppg Vis 100 sec POH w/ cleanout BHA and L/D same. M/LT 10-5/8" drilling BHA and RIH. Drill from 2,035' to 2,130. Disassemble pump to clean pieces of rubber cement wiper plugs from valves. Dri112,130' to 2,212' . Clean additional rubber from pumps. Inclination Surveys: 0.26° at 2,035' 0.56° at 2,136' 0.57° at 2,136' January 4, 2007 MW 9.4 ppg Vis 90 sec Continue removing rubber from pump valves. Drill 2,212' to 2,995'. Help respond to --m- mud and cuttings spill outside cuttings berm. Inclination Surveys: 0.60° at 2,753' 0.64° at 2,845' 0.80° at 2,939' January 5, 2007 MW 9.4 ppg Vis 120 sec Drill 10-5/8" vertical hole from 2,295' to 3,855'. CBU and short trip to casing shoe. Inclination Surveys: 0.73° at 3,602' 0.73° at 3,696' 0.78° at 3,789' January 6, 2007 MW 9.4 Vis 120 sec Cut and slip drilling line, POH. M/U coring assembly and RIH. Wash to bottom, core from 3,855' to 3,858'. January 7, 2007 MW 9.4 ppg Vis 65 sec Core from 3,858' to 3,884'. Activate core catcher and POH slowly to allow core to de- gas. L/D core (23'), M/iJ and rack back new coring assembly. Prepare for BOP test. Inclination Surveys: 0.7b° at 3,855' 0.80° at 3,858' January 8, 2007 MW 9.4 ppg Vis 70 sec Test BOPE to 250/3,500 psi. Test witnessed by AOGCC representative. RIH w/ coring assembly. Cut core from 3,884' to 3,928'. Activate core catcher and POH slowly to allow core to de-gas. January 9, 2007 MW 9.4 ppg Vis 58 sec POH slowly with core. L/D core (44'), M/U 10-5/8" drilling assembly and RIH. Drill from 3,928' to 3,985'. January 10, 2007 MW 9.4 ppg Vis 70 sec Drill from 3,985' to 4,085'. CBU and POH, L/D BHA. P/U coring BHA #3, RIH. Core from 4,085' to 4,096'. Core barrel jammed. Activate core catcher and POH slowly to allow core to de-gas. Inclination Surveys: 0.49° at 3,977' 0.57° at 4,043' 0.57° at 4,085' January 11, 2007 MW 9.4 ppg Vis 66 sec POH w/ Core #3. L/D core. P/U drilling BHA and RIH. Drill from 4,096' to 4,332' TD. CBU and POH. Inclination Surveys: 0.06° at 4,260' 0.17° at 4,303' 0.17° at 4,332' January 12, 2007 MW 9.5 ppg Vis 70 sec Finish OOH. L/D BHA. Rig up for wireline logging operations. RIH w/ logging tools, log from 4,332' to 2,005' w/ spectral GR, compensated neutron, Z-density, HDIL, XMAC. L/D wireline tools. Prepare RCI logging tools. P/U straddle pkr and RCI logging tool. M/U on 5" DP. RIH to 1,925'. January 13, 2007 MW 9.5 ppg Vis 70 sec Continue RIH to 3,668'. Install side-entry sub, pump down wet connect. RIH to 3,894'. Tie in and commence obtaining fm pressures between 3,894' and 4,118' January 14, 2007 MW 9.5 ppg Vis 73 sec Take formation fluid samples w/ RCI tool. January 15, 2007 MW 9.5 ppg Vis 73 sec Take formation fluid samples w/ RCI tool. POOH from 4,070' to 3,671'. R/D wireline and side-entry sub. POOH, L/D RCI tool. Test BOPE to 250 / 3,500 psi. R/U wireline and RIH w/ GR/MREX tools. January 16, 2007 MW 9.4 ppg Vis 60 sec Log open hole w/ GR/MREX tools. POOH, M/U GR/CBII,/HDIP and RIH. Log open hole - HDIP pad failure. POOH, change out pad on HDIP, RIH. Log open hole. POOH, L/D logging tools, M/U RCI tools on DP. RIH to 3,661'. M/U side-entry sub and pump wet connect. RIH to 3,905', set straddle packer and begin taking fm fluid samples. January 17, 2007 MW 9.4 ppg Vis 62 sec Take formation fluid samples w/ RCI tool. POH to 3,658', disconnect wireline and remove side-entry sub. POOH and L/D RCI tools. R/U wireline and M/U VSP .logging tools. RIH, run VSP. January 18, 2007 MW 9.4 ppg Vis 53 sec Finish logging w/ VSP tools. POOH, L/D VSP tools. P/U sidewall coring tools and RIH w/ Gun #1. Fire 50 shots, POOH. L/D Gun #1 - 1 shot left in hole, 4 empty. M/tJ Gun #2 and RIH. Fire 50 shots, POOH. L/D Gun #2 - 4 shots left in hole, 1 empty. M/U Gun #3 and RIH. Fire 50 shots, POOH. L/D Gun #3 -only 28 shots fired, 3 shots left in hole. M/LT Gun #3B and RIH. Fire 18 shots, POOH. L/D Gun #3B -all shots fired and recovered. R/D wireline, M/U cleanout BHA. RIH. January 19, 2007 MW 9.4 ppg Vis 54 sec Finish RIH to TD. CBU and POH, laying down DP. L/D BHA, L/D DP out of derrick. P/LT 66 joints of 2-7/8" tbg for cement stinger and RIH with it on DP. RIH to TD and CBU. January 20, 2007 ~ MW 9.5 ppg Vis 52 sec Pump 113 bbls of 15.8 ppg cement slurry. Displace w/ 54 bbls mud. POH to, 3,375' and CBU. POH and L/D 30 jts DP while WOC. RIH w/ DP from derrick to 3,386'. WOC. Pump 110 bbls of 15.8 ppg cement slurry. Displace w/ 38 bbls mud. POH to 2,528' and CBU. POH and L/D DP to 1,660'. RIH w/ DP from derrick to 2,533'. WOC. Pump 115 ~ ~ bbls of 17.0 ppg cement slurry. Displace w/ 23 bbls mud. POH to 1,675'. CBU. POH, L/D DP and cementing stinger. January 21, 2007 MW 9.5 ppg Vis 52 sec Finish L/D cementing stinger. RIH and POH, L/D DP. Pressure test 13-3/8" casing shoe plug to 1,000 psi for 15 min. -good test, witnessed by AOGCC rep. RIH w/ EZSV on DP to 250'. Set EZSV and weight test w/ 15K lbs. POH, L/D setting tool. RIH w/ DP to 250' Pump 35 bbls Arcticset I at 15.8 ppg. L/D DP, mix and dump 3 bbls Arcticset I in wellbore to top off surface cement plug. R/D cementers, blow down line, wash out stack and L/D mousehole.N/D BOP stack and clean out tbg hgr profile and csg spool profile. Install packoff in wellhead. January 22, 2007 Install tbg hgr and dry hole tree. Test to 1,000 psi. Offload mud and clean pits and cuttings tank. Prepare for rig move. Rig released at 2400 hrs, 1/22/07. March 16, 2007 Use backhoe to dig down around casing stub. Cut off all casings 5' below tundra level. AOGCC rep verified cement to surface inside 9-5/8" casing and in 9-5/8" x 13-3/8" annulus. Welded on marker plate. Backfilled hole, leaving mound over it. • ~.~ .~ J / ~ . i r:, ' ~:. '~ ~'~:'!~ ~;_ ~~ E ~. ;. ~~ ~, ~ ~ s~ . MEMORANDUM State of Alaska ~~~~~ ~z~~~'7 TO: Jim Regg, P. I. Supervisor FROM: Jeff Jones Petroleum Inspector Alaska Oil and Gas Conservation Commission DATE: March 16-17, 2007 SUBJECT: Surface Abandonment Rock Flour #2 ENI PTD #206-166 March 16-17, 2007: I traveled to ENI's Rock Flour #2 well location to inspect the casing cut off and surface abandonment of this well. I verified that all casing strings had been cut off at least 5 feet below original grade and all were filled with cement. During the inspection I noted that an improper API number was bead welded to the marker plate and I instructed ENI representative Satch Bowe to correct the information on the plate. I returned to this location on 3/17/07 and verified the correct information was welded to the marker plate. At that time a 20" diameter, 1"thick marker plate was seal welded to the outermost conductor with the required information bead welded to it. Summary: I inspected the surface cement plug, casing cut off depth, and the P&A marker plate on ENI's Rock Flour #2 well and verified that all were in compliance with AOGCC regulation 20 AAC 25.120. Attachments: Photos (2) P-A ENI Rock Flour #2 3-17-07.jpg P-A ENI Rock Flour #2 3-17-07.jpg X Unclassified Classified Unclassified with Document Removed ~ • • ~®c!<C ~I®ur ~#~ ~EN~ Petr®leum) surface ~iaand®nrne~t a~spect9®ra photos from Jeff Jones, AOGCC IVlarch 17, 2007 Casing cut-off; cement to surface Marker plate Re: Rock Flour #3 Well Completion Report ~ ~: Subject: Re: Rock Flour~3 Well Completion Report prom: Thomas Maunder <tom maunder~admin.state.ak.us> Date: Tue, 20 Feb 2007 15:16:29 -0900 "I'o: Qill Pcnros~ <-hill~~~i fair,veather.cotn> Bill, Plan to send in the report within 30 days of finalizing the P&As. Tom Maunder, PE AOGCC Bill Penrose wrote, On 2/20/2007 3:10 PM: Tom, AOGCC regulations require the filing of a Well Completion Report within 30 days of the suspension or P&A of a well. Eni's Rock Flour #2 was suspended on January 22, so its Well Completion Report is due on February 21. However, Eni recently received from the Commission an approved Sundry Application to finalize the P&A of this well and we plan to perform the P&A of both Rock Flour #2 and Rock Flour #3 (P&A Sundry already approved) in the next one to two weeks. In the interest of reducing paperwork and effort on everyone's part, I suggest the deadline for the Rock Flour #2 Well Completion Report be extended to March 7 (a two-week extension) so that the report can include the complete P&A of the ', well instead of one report for the suspension and one immediately following for the P&A. Please let me know what you think. Regards, Bill Penrose Vice President / Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 1 of 1 2/20/2007 3:33 PM S,9R~40i ~ALIAI, GOl/ERAlOR David Dougall HSE Manager ENI Petroleum 1201 Louisiana, St Suite 3500 Houston, TX 77002 Re: Exploratory, Rock Flour #2 (PH) Sundry Number: 307-062 Dear Mr. Dougall: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness- any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ,. , DATED this ~~7 day of February, 2007 Encl. -~~ 21~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 R~C~11/~D ~t~ Fps x ~ zaa7 Alaska Oil & Gas Cans. Commission 1.7ype of Request: Abandon ~ ' Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ QnCIt0~8r Alter using ^ Repair well ^ Plug Perforations ^ Stimulate ^ Tune Extension ^ Change approved program[] Puil Tubing ^ Perforate New Pool ^ Re-enter Suspended Weil [] 2.Operator Name: 4. Current Well Class: 5. Permit to Drift Number. ENt Petmlaum Inc. Development ^ Exploratory a 206-166 - 3. Address: 5tratigraphlc ^ Service ® 6. API Number: _ ~ 1241 Lousiana, St. Suit 3504, Houston, TX, 77442 50-029 28335 - nL . / 7. If perforating, cidsest approach in pool(s) opened by this operation to nearest f!. Well Name and Number: property line where ownership or landownership changes: ~~~p(~( Rode Flour #2 , J~ .D7 ' -' "'D Spacing F_xoeption Required? Yes ^ No a Y / j,, S. Property Designation: 10. KB Elevation (ft): 11. FiektiPool(s): At)L 380695. 32.25' E)C IOt'at0 ~~• PItE3ENT WELL CONDtTtON SUMMARY Total Depth MD {ft}: Total Depth TVD (ft): Effective Depth MD {tt}: Effective Depth M7 (ft): Plums {measured}: Junk (measured): 4300' • 4300' 4,300' 4,340' None Nane Casing t.ength Size MD ND Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2,005' 13-318" 2005' 2,445' 5,420 psi 2,260 psi intemtediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tutting Size: Tubing Grade: Tubing MD (ft): Na Na Na Na Na Packers and SSSV Type: Na Packers and SSSV MD (ft}: Na 13. Attachments: Desa#ption Summary of Proposal ^ f4. Well Class after proposed work.: Detailed Operations Program ^ BOP Sketch ^ Explora~ry ^ Development ^ Service ^ 15. Estimated Date for 2121107 16. Weti Status afNr proposed work: Cornmencting Operations: Oil ^ Gas ^ Plugged ^ Abandoned [~ 17. Verbal ApprovaC Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 1 B. I hereby certify that the foregoing is true and sx>rreat to the best of my knowledge. Contact BIII Penr~e 258.3446 Printed Name David Dougatl Title HSE Manager Signature Phone Date ,/ a~.~ : ,. : ~. 713-3836122 ~C ~"" 9' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ~ BOP Test ^ Mechanical integrity Test ^ Locat~n Ctean3nce Other: t~.Or~C.t ~. a~ EC_~ O ~ ~ C _ ~Q~~~'~~ ~ vJ \~ ~S5 ~V~ C~ ~` ~OC' ~ ~ ~ v~cc ~w\~~~ , P ~~0 5 s ~~~~~ ~ -vim o~ ~~~~ ol~~ 6v ' v.~` l Subsequent Form Required: \~~ APPROVED BY Approved by: COMMtSSiONER 7HE COMMlSS14N D te ~~SrQ/~ a : .v7 ~`1 Form 10-403 Revised 4t3/2 V t~ ~ ~ .,- , Submi# in upligte Y ~ _ '~ xs., ~7 • s EPtI February 14, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7`h Ave., Suite 100 Anchorage, Alaska 99501 U R~~~'~~ FEB 1 ~ 2QQ~ Alaska Oil ~ Gas Cons.. O~misswn Anchorage RE: Sundry Application to Plug and Abandon Eni Petroleum: Rock Flour #2 (PTD # 206-166) Dear Mr. Norman, .~ Eni Petroleum proposes to permanently abandon its Rock Flour #2 well. The work is planned to take place approximately February 21. ~' Rock Flour #2 is currently in Suspended status with all the hydrocarbon-bearing intervals isolated, the surface casing shoe isolated from the open hole and a surface plug set in place. The suspension work was performed under the authority of AOGCC Sundry Approval No. 307-025. The wellhead has been removed from this well, also with the concurrence of the Commission. See the attached wellbore diagram for the current condition of the well. The abandonment of Rock Flour #2 will be accomplished by excavating around the well r to approximately seven feet below the tundra surface, cutting off all of the casings at least five feet below tundra level, ensuring cement exists in all casings and annuli, welding on a marker plate and burying the well. An abandonment procedure is attached. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ENI PETROLEUM .~ ~ _- Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: David Dougall -Eni Petroleum Eni Petroleum Rock Flour #2 Abandonment Procedure • 1. Notify the AOGCC North Slope inspector with 24 hours notice of abandonment activities to afford them the opportunity to witness them. 2. Use a backhoe to excavate around the well to a depth of at least 7' below tundra level. 3. Cut off all well casings at least 5' below tundra level. 4. Ensure inner casing and annulus contain cement at the surface. If they do not, top off with fresh cement. 5. Weld onto the outermost casing string a 1/a" thick, 20" diameter circular steel plate containing the following information bead-welded onto it. Eni Petroleum, Inc. PTD No. 206-166 Rock Flour #2 50-029-23335-00 6. Bury the capped well with the previously excavated material. Obtain and use extra gravel, if necessary, to ensure the fill over the well is mounded at least three feet above pad level to account for settling when the fill thaws in the summer. 7. Clean up all visible waste on location and demobilize personnel and equipment. _'~_ ROCK FLOUR #2 [ D .01 ~ Proposed P & A ~Z' `~ 20" conductor Bridge plug at 250' set @ 110' ~- RKB w/ permafrost cement to surface 9.4 ppg mud 1,850' 13-3/8", 68#, L-80, BTC surf csg set at t~ 2,005' 2,955' - 2,965' 3,010' - 3,018' 3,159' - 3,173' 3,330' - 3,340' 10-5/8" open hole filled w/ cement 3,370' - 3,380' Hydrocarbon- w/ 3 stages 3,580' - 3,590' bearing Intervals 3,640' - 3,670' 3,684' - 3,692' 3,710' - 3,716' 3,746' - 3,760' 3,778' - 3,793' TD @ 4,332' MD/ TVD 3,892' - 3,912' w wjp 12/13/07 Re: Wellhead Removal - Eni Rock Flour #2 • Subject: Re: Wellhead Removal - Eni Rock Flour #2 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 07 Feb 2007 07:05:52 -0900 To; Bill Penrose <bill@fairweather.com> Bill, Thanks for the information regarding your plans. I agree that with the well cemented, there should not be a problem removing the wellhead to use on the other well. Good luck with the continued operations. Tom Maunder, PE AOGCC Bill Penrose wrote, On 2/6/2007 7:50 AM: Tom, Eni Petroleum proposes to remove the wellhead from suspended well Rock Flour #2 for use in drilling the Maggiore #1. After the log results from Maggiore #1 are known, the wellhead will either be reinstalled on Rock Flour #2 for further operations in that well or Rock Flour #2 will be permanently plugged and abandoned per regulations. Attached find the as-suspended wellbore diagram for Rock Flour #2. It indicates that the open hole has been filled with cement, the last casing shoe is isolated from the open hole with cement (verified with a 1,000 psi pressure test), a bridge plug is set at 250' RKB and the wellbore is filled with cement from the bridge plug to the surface. Also, all annuli are filled with cement to the surface. It is Eni's opinion tha-t this suspension ensures that removal of the wellhead will present no well control or safety concerns.. Please let me know if the Commission concurs. Thanks and regards, Bill Penrose Vice President / Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 ~~ ~L© ~~ i of 1 6/21/2007 930 AM ~+ ROCK FLOUR #2 [PHl ~ As-Suspended 20" conductor Bridge plug at 250' set @ 110' ~ --- ~{B ~,~,/ permafrost cement to surface 9.4 ppg mud 1,700' 13-3/8", 68#, L-80, (Top OH cement plug BTC surf csg set at Tested to 1,000 psi) ~'-ter 2,005' 2,955' - 2,965' 3,010' - 3,018' 3,159' - 3,173' 3,330' - 3,340' 10-5/8" open hole filled w/ cement 3,370' - 3,380' Hydrocarbon- w/ 3 stages 3,580' - 3,590' bearing Intervals 3,640' - 3,670' 3,684' - 3,692' 3,710' - 3,? 16' 3,746' - 3,760' 3,778' - 3,793' TD @ 4,332' NID/ TVD 3,892' - 3,912' wjp 02/6/07 ` ~ --* ~~ January 26, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7`h Ave., Suite 100 Anchorage, Alaska 99501 u . ~~: ~. k~ ~e~ ~~ ~~s~.., a,;7(rtS~it~i Atl~h~r~g~ RE: Weekly Report of Operations Eni Petroleum: Rock Flour #2 (PTD # 206-166) Dear Mr. Norman, This is a report of Eni Petroleum's well operations on Rock Flour #2 for the period January 12 through January 18, 2007, inclusive. January 19, 2007 Finish RIH to TD. CBU and POH, laying down DP. L/D BHA, L/D DP out of derrick. P/LT 66 joints of 2-7/8" tbg for cement stinger and RIH with it on DP. RIH to TD and CBU. January 20, 2007 Pump 113 bbls of 15.8 ppg cement slurry. Displace w/ 54 bbls mud. POH to, 3,375' and CBU. POH and L/D 30 jts DP while WOC. RIH w/ DP from derrick to 3,386'. WOC. Pump 110 bbls of 15.8 ppg cement slurry. Displace w/ 38 bbls mud. POH to 2,528' and CBU. POH and L/D DP to 1,660'. RIH w/ DP from derrick to 2,533'. WOC. Pump 115 bbls of 17.0 ppg cement slurry. Displace w/ 23 bbls mud. POH to 1,675'. CBU. POH, L/D DP and cementing stinger. Januay 21, 2007 Finish L/D cementing stinger. RIH and POH, L/D DP. Pressure test 13-3/8" casing shoe plug to 1,000 psi for 15 min. -good test, witnessed by AOGCC rep. RIH w/ EZSV on DP to 250'. Set EZSV and weight test w/ 15K lbs. POH, L/D setting tool. RIH w/ DP to 250' Pump 35 bbls Arcticset I at 15.8 ppg. L/D DP, mix and dump 3 bbls Arcticset I in wellbore to top off surface cement plug. R/D cementers, blow down line, wash out stack and L/D mousehole.N/D BOP stack and clean out tbg hgr profile and csg spool profile. Install packoff in wellhead. January 22, 2007 Install tbg hgr and dry hole tree. Test to 1,000 psi. Offload mud and clean pits and cuttings tank. Prepare for rig move. Rig released at 2400 hrs, 1/22/07. FINAL REPORT. • • Mr. John Norman Page 2 If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ENI PET OLEUM ,,~ ~. Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: David Dougall - Eni Petroleum ~ r MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~ ~Z~a~ DATE: January 21, 2007 P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector SUBJECT: Plug & Abandonement Rock Flour #2 ./ ENI Exploration PTD# 206-166 CONFIDENTIAL Section: Lease No.: ADL390695 Operator Rep.: Jack Keaner Township: Range: Meridian: Drilling Rig: Nabors 27E Rig Elevation: Total Depth: 4332 Casina/Tubin a Data: Conductor: 20" O.D. Shoe@ 110' Surface: 13 3/8" O.D. Shoe@ 2005' Intermediate: O.D. Shoe@ Production: O.D. Shoe@ Liner: O.D. Shoe@ Tubing: O.D. Tail@ Casing Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet type Plug Tvpe Plust Founded en Bottom Top of Cement Mud Weight Pressure (bottom upl - ---- -- of Cement Depth Verified? above plug Test Applied O en Hole Bottom 4332 1850 no es Tvpe Plua Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface I traveled to the ENI Rock Flour #2 location to witness the pressure test of the open hole cement plug in this well. A cement plug had been spotted in three stages from TD (4332) to an estimated top of cement at 1850',filling the open hole from TD to 155' inside the the surface casing. A successful pressure test 1000 psi was performed per the aproved Sundry. Rev.:5/28/00 by L.R.G. Open Hole Plug Rock Flour.xls 1/2g/2007 • ~ni January 19, 2007 ,SAN ~ 3 1Ci~w7 Afaska OiV ~ ~` s G~ 3~. •~n :se~~~~~ Mr. John Norman, Chair ~~` ~~, ~~ Alaska Oil and Gas Conservation Commission 333 West 7`h Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Eni Petroleum: Rock Flour #2 (PTD # 206-166) Dear Mr. Norman, • This is a report of Eni Petroleum's well operations on Rock Flour #2 for the period January 12 through January 18, 2007, inclusive. January 12, 2007 Finish OOH. L/D BHA. Rig up for wireline logging operations. RIH w/ logging tools, log from 4,332' to 2,005' w/ spectral GR, compensated neutron, Z-density, HDII,, XMAC. L/D wireline tools. Prepare RCI logging tools. P/U straddle pkr and RCI logging tool. M/LT on 5" DP. RIH to 1,925'. January 13, 2007 Continue RIH to 3,668'. Install side-entry sub, pump down wet connect. RIH to 3,894'. Tie in and commence obtaining fm pressures between 3,894' and 4,118' January 14, 2007 Take formation fluid samples w/ RCI tool. January 15, 2007 Take formation fluid samples w/ RCI tool. POOH from 4,070' to 3,671'. R/D wireline and side-entry sub. POOH, L/D RCI tool. Test BOPE to 250 / 3,500 psi. R/U wireline and RIH w/ GR/MREX tools. January 16, 2007 Log open hole w/ GR/MREX tools. POOH, M/iJ GR/CBIL/HDIP and RIH. Log open hole - HDIP pad failure. POOH, change out pad on HDIP, RIH. Log open hole. POOH, L/D logging tools, M/U RCI tools on DP. RIH to 3,661'. M/U side-entry sub and pump wet connect. RIH to 3,905', set straddle packer and begin taking fm fluid samples. • Mr. John Norman Page 2 January 17, 2007 Take formation fluid samples w/ RCI tool. POH to 3,658', disconnect wireline and remove side-entry sub. POOH and L/D RCI tools. R/U wireline and M/U VSP logging tools. RIH, run VSP. January 18, 2007 Finish logging w/ VSP tools. POOH, L/D VSP tools. P/U sidewall coring tools and RIH w/ Gun #1. Fire 50 shots, POOH. L/D Gun #1 - 1 shot left in hole, 4 empty. M/LT Gun #2 and RIH. Fire 50 shots, POOH. L/D Gun #2 - 4 shots left in hole, 1 empty. M/LT Gun #3 and RIH. Fire 50 shots, POOH. L/D Gun #3 -only 28 shots fired, 3 shots left in hole. M/U Gun #3B and RIH. Fire 18 shots, POOH. L/D Gun #3B -all shots fired and recovered. R/D wireline, M/LJ cleanout BHA. RIH. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ENI PET OLEUM Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: David Dougall - Eni Petroleum ~I.A~~-A OII. ~D GAS COlYSERQATIOlY CO1rII-IISSIOI~T David Dougall HSE Manager ENI Petroleum 1201 Louisiana, St Suite 3500 Houston, TX 77002 Re: Exploratory, Rock Flour #2 (PH) Sundry Number: 307-025 Dear Mr. Dougall: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PiiONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED this.~day of January, 2007 Encl. ~0 Co ~! !o ! • =-~~E~ ~a ~ ~ ~ 2007 ~i'11 January 18, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7`~ Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application to Suspend Eni Petroleum: Rock Flour #2 (PTD # 206-166) Dear Mr. Norman, 9a ~ ; , ' .~~s Cnns. C~xnmissi®n Eni Petroleum proposes to suspend its Rock Flour #2 well and move to the Rock Flour #3 drilling location. After drilling Rock Flour #3 and depending on the results there, the Rock Flour #2 well will either be permanently plugged and abandoned or the original plan will be resumed to drill a lateral in that well. Whichever course of action is taken, the well will be permanently plugged and abandoned during this winter season. The hydrocarbon-bearing intervals requiring isolation per AOGCC regulations are indicated on the enclosed wellbore schematic. The wireline logs from this well will be reviewed with your staff for their concurrence on these intervals and our plan to abandon them. The suspension of Rock Flour #2 will be accomplished by entirely filling the open hole with cement with the top of the cement being 150' into the last casing shoe. Then a surface cement plug will be set and the wellhead left on the well. - If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ENI PET EUM ~/9 .e. Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: David Dougall -Eni Petroleum STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI ON ,'Q~'~ ~ ~Q~7 APPLICATI©N FOR SUNDRY APPROVAL ~~~~ 20 AAC 2s_2so W f , 1. Type of Request: Abandon ^ Suspend Operational shutdown ^ Perforate ^ Waive ~~t C~ Other n Alter casing ^ Repair well ^ Ptug Perforations ^ Stimulate ^ Time Extensio Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-meter Suspended Welt ^ 2.Opsratar Name: 4. Current Well Class: 5. Percnit to Drill Number. ENI Petroleum inc. Deve~pment ^ Exploratory ^ 206-166 3. Address: Stratigraphic ^ Servir~ ® 6. API Number: 1201 Loustana, St Suit 3500, Houston, TX, 77002 50-029 23935-70 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Weil Name and Number: property tine where ownership or landownership changes: Spacing Faco3ption Required? Yes ^ No Q Rock. Flour #2 (Pit} 9. Property Designation: 10. KB Elevation (ft}: 11. Fieid/Pool{s}: ADL 3906Q5 ' 32.25' F_x IoratO 12' PRESENT WELL CONDITION SUMMARY Total Depth MD {ft): Toth Depth TVD (ft): Effective Depth MD (ft}: Effective Depth TVD (ft}: Plugs (measured): Junk {measured}` 4300' 4300' 4,300` 4,300' None None Casing Length Size MD TVD Burst Cogalsse Structural Conductor 80' 20" 80' 80' SurFace 2,005' 13.3!8" 2005' 2,005' 5,020 psi 2,260 psi Intemtediate Production Liner Perforation Depth MD (fk): Perforation Depth TVD (ft}: Tubing Slie: Tubing Grade; Tubing MD (ft}: Na Na Na Na Na Packers and SSSV Type: Na Packers. and SSSV MD (ft}: Ma 13; Attachments: Desalption Summary of Proposal Q 14. Welt Chris after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ $er»ce ^ 15. Estimated Date for 16. WeH Status after proposed work: Commencing Operations: /~~ ~'~'° ~ Oil ^ Gas ^ Plugged QQ ~ Abandoned ^ 17. Verbal Approval: Date: ~ t~~°`Q~ Commission Re resentative: ~ ~ WAG ^ GINJ ^ N WDSPL ^ r~C ~~ p ~ S~ ~ ~' v" 1 ~ 18. I hereby certify that the foregoing is true and corrrect b the test of my knowledge. Contact BiII Penr~e 258-3446 Printed Name David t)ougaN Title HSE Manager Signature ~ Phone Date ' ~' ' ' ~ : 713-383~3i22 // ,/'~ ~+ COMMISSION USE ONLY Conditions of approval: Notify Commission so tha# a representative. may witness Sundry Number: ~ ~ ~ ~~ Plug Integrity BOP Test ^ Meeharrlcat Integrity Test ^ Location Clearance ^ ter: ~0~~~7 .~~SQ~~-~~-- ~~- a~Qa~~~-~.~ ~v~~-~-~SS CGS„~S-~~~, 1~ ©~ ~ s ss~.r~ -~, -~ ~ ~ ~ ,, S cov~~c ~~ ~~ p~o~~ ~S ~ c~ ~~ S ~ ~ (~ Subsequent Form Required: y~ ~ ~~~ ~ '!- W~ ~.( APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 14-403 Revised 06!2006 / ~, ~~~ ~~~ ~ ~ ~~~~ Submit ~ Duplicate ~~~~~~AL ~~© • • Eni Petroleum Rock Flour #2 Plug Back Procedure 1. RIH washdown last 2 stands and tag TD with care and minimal weight, TD expected at 4,332' and pick up 10' to 4323'. 2. Circulate and condition mud 3. Pump 5- 10 barrels of water ahead, 4. Stage 1: Pump 105 bbl cement slurry mixed as follows: 508 sacks Class G cement + 0.4% D167 + 0.3% D65 + 0.3% S1 + 0.2% D46 + 5.09 gal/sx water, working time 3:40 hours. (1.16 cf/sk, 15.8 ppg) 5. Pump 1-2 bbls of water behind. Pull up to 3,500' and circulate out cement above that depth. Prepare to pump Stage 2. 6. Stage 2: With OEDP set at 3,500', pump 100 bbl cement slurry mixed as follows: 484 sacks Class G cement + 0.4% D167 + 0.3% D65 + 0.3% S1 + 0.2% D46 + 5.09 gal/sx water, working time 3:40 hours. (1.16 cf/sk, 15.8 ppg) 7. Pump 1-2 bbls of water behind. Pull up to 2,700' and circulate out cement above that depth. Prepare to pump Stage 3. 8. Stage 3: With OEDP set at 2,700', pump 110 bbls of cement slurry for a casing shoe plug extending from 2300' to 1900' mixed as follows: 618 sacks Class G + 1.0% D65 + 1.0% S 1 + 0.2% D46 + 3.86 gal/sx water. Working time: 4:00 hours (1.0 cf/sk, 17.0 ppg) 9. Pump 1-2 bbls of water behind. Pull up to 1,850' and circulate out cement above that depth. POH and lay down all but 200' of drill pipe in preparation for rig move. ( \ ~~F-~sS `~Ttc"~5~--~Ci~S~Q 't-Q 10. P/LT a 13-3/8" drillable bridge plug on DP and RIH. Set the bridge plug at 250' J ~ ~o©©~~ ~~~ ~i~' ~ • 11. With the drill pipe just above the bridge plug, circulate in 33 bbls of ARCTICSET I (0.93 cf/sk, 15.7 ppg) cement slurry for a surface plug. 12. POH with drill pipe and lay it down. Ensure cement fills the 13-3/8" casing to the surface after all drill pipe is pulled from hole. 13. Install a tubing hanger in the wellhead. Install a backpressure valve in the tubing hanger. d 14. N/D BOPE and N/U a dry hole tree. Test dry hole tree to 5,000 psi and release rig. • • ' + ROCK (LOUR #2 [PNl Proposed Suspension 20" conductor set @ 110' - Bridge plug at 250' ~- RKB w/ permafrost cement to surface 1,850' 10-5/8" open hole filled w/ cement w/ 3 stages TD @ 4,332' MD/ TVD 13-3/8", 68#, L-80, BTC surf csg set at ~ 2,005' 2,955' - 2,965' 3,010' - 3,018' 3,159' - 3,173' 3,330' - 3,340' 3,370' - 3,380' 3,580' - 3,590' 3,640' - 3,670' 3,684' - 3,692' 3,710' - 3,716' 3,746' - 3,760' 3,778' - 3,793' 3,892' - 3,912' Hydrocarbon- bearing Intervals bjb 01/18/07 Rock Flour #2 (206-166) Subject: Rock Flour #2 (206-166) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 18 Jan 2007 16:33:00 -0900 To: Biil Penrose <bill@fairweather.com> Bill, Thanks for bringing by the information. We have By copy of this email, you have "verbal approval" Good luck. So long as there are no problems (ie there is no requirement to tag them. Contact the witness the pressure test of the plug casing. Call or message with any questions. Tom Maunder, PE AOGCC completed our review of your plans. to proceed. lost circulation) setting the plugs, Inspector for an opportunity to 1 of 1 6/21/2007 9:12 AM • E~ti • ~~N ~ ~ 2C,Ol Alaska 1Jii ~ Cias Cons. Commission Anchorage January 12, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7`h Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Eni Petroleum: Rock Flour #2 (PTD # 206-166) Dear Mr. Norman, This is a report of Eni Petroleum's well operations on Rock Flour #2 for the period January 5 through January 11, 2007, inclusive. January 5, 2007 Drill 10-5/8" vertical hole from 2,295' to 3,855'. CBU and short trip to casing shoe. January 6, 2007 Cut and slip drilling line, POH. M/iJ coring assembly and RIH. Wash to bottom, core from 3,855' to 3,858'. January 7, 2007 Core from 3,858' to 3,884'. Activate core catcher and POH slowly to allow core to de- gas. L/D core (23'), M/U and rack back new coring assembly. Prepare for BOP test. January 8, 2007 Test BOPE to 250/3,500 psi. Test witnessed by AOGCC representative. RIH w/ coring assembly. Cut core from 3,884' to 3,928'. Activate core catcher and POH slowly to allow core to de-gas. January 9, 2007 POH slowly with core. L/D core (44'), M/LT 10-5/8" drilling assembly and RIH. Drill from 3,928' to 3,985'. January 10, 2007 Drill from 3,985' to 4,085'. CBU and POH, L/D BHA. P/U coring BHA #3, RIH. Core from 4,085' to 4,096'. Core barrel jammed. Activate core catcher and POH slowly to allow core to de-gas. • Mr. John Norman Page 2 • January 11, 2007 POH w/ Core #3. L/D core. P/U drilling BHA and RIH. Drill from 4,096' to 4,332' TD. CBU and POH. If you have any questions. or require additional information, please contact me at 258- 3446. Sincerely, For ENI PETROLEUM ~~` Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: David Dougall - Eni Petroleum RE: Eni Weekly Drilling Report 1 of 2 Subject: RE: Eni Weekly Drilling Report From: BiII Penrose <bill@fairweather.com> Date: Tue, 09 Jan 2007 09:06:20 -0900 To: Thomas Maunder <tom maunder@admin.state.ak.us> They were supposed to, but they didn't report that level of detail. The Co. Man who was on duty at the time is now on days off. Bill Penrose Vice President / Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, January 08, 2007 10:01 AM To: Bill Penrose Subject: Re: Eni Weekly Drilling Report Thanks Bill. Must be good drilling practices and mud. Did they reciprocate the surface pipe? Tom Bill Penrose wrote, On 1/8/2007 9:47 AM: Tom We got back almost 300 bbls of cement on the 13-3/8" casing job. Equates to a gauge hole which surprised us a little. The formation test was a LOT. I've attached the graph. Regards, Bill Penrose Vice President / Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, January 08, 2007 7:51 AM To: Bill Penrose Subject: Re: Eni Weekly Drilling Report Thanks for the report Bill. A couple of questions. 1. How much cement was circulated on the surface job? 2. Was the formation test below the shoe a LOT or FIT. If you have the graph, I'd appreciate if you could send it. Thanks in advance. Tom Maunder, PE AOGCC Bill Penrose wrote, On 1/5/2007 4:47 PM: Tom, ~~~~ ~~ ~ ~~~, 6/21/200'7 8:57 AM RE: Eni Weekly Drilling Report ~ ~ Please see the attached weekly drilling report. Have a good weekend! Regards, Bill Penrose Vice President / Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 2 of 2 6/21/2007 8:58 AM i PRESSURE INTEGRITY TEST ~ NO. 1 DATE Jan 02 2~ OPERATOR ENI WELL NAME 6 NO. RF #2 AREA Alaska CWNTRV USA STATE Alaska RIG NAME Nabor 27E Arctic Ri ELEV. RKB ABOVE MS 30 ABOVE CHF rt ABOVE MUDL. rt CSG. SIZE 13 318 WT. GRADE SHOE DEPTH (MO) 2,005 rt TOTAL VER. DEPTH 2,005 rt MUD PROP WT. 9.3 VIS PV VP API WL GELS 1Y70 PUMP CALIBRATION SBL55TROKE® BPM TYPE PUMP Rig Pumps LEST RATE 1/2 BPM TYPE TEST CSG CSG SHOE 7Y OPEN HOLE LOT 2N OPEN HOLE PM 7D OF TEST 2,035 TvD MUD PUMPED 1.00 BBL MUD FLOWBACK 1.00 BBL PRED. fRAC GRADE PPG Epirelw~ MW WapM ®SMOE 12.324 PPG DEPTH let SAND BELOW CSG DRLR (IW) FT ELEC. LOG FT TVD MAX PRES. OBSVD 320 PSI PR LIMB PPG TEST TEAM: McDade/Hunt mn Nz. PYeea. 103 Psl Min Hz Stress 10.27 PPG STKS 0 PSI 0 -- _ __ -_ 3500 ~- 0 5.00 320 345 < - 10.00 750 3400 15.00 1070 3350 3300 20 00 1490 3250 . 3200 25.00 1880 150 --- 30.00 2320 3 3100 50 -- 35.00 2790 30 i -- 38.00 3010 300o 2950 00 0 3010 2900 i _ . 5 1.00 3010 28 0 2.OC 80i1G 275 _- 3.00 3000 2700 - 2650 - 4.00 3000 0 5.00 3000 26 0 550 10 00 3000 2 2500 . 15.00 3000 2450 0 20.00 3000 240 2350 25 00 3000 2300 . 2250 30.00 3000 00 22 2150 2100 . - 2050 2000 - ;i 1950 900 1 1850 1800 1750 a 1700 1650 1600 --- - 1550 -- 1500 1450 - 1400 1350 _- 1300 - 1250 1200 1150 1100 1050 1000 950 900 - 850 800 750 700 650 - 600 550 500 450 400 350 300 250 200 150 - 100 - - 0 - - - 0 10 .00 20 .00 30. 00 38 .00 1. 00 3. 00 5. 00 15 .00 25 .00 B BLS /MIN UT ES PRESSURE INTEGRITY TEST ~ NO. 1 DATE Jan 02 20~ OPERATOR ENI NIELL NAME 6 NO. RF #2 AREA Alaska COUNTRT USA STATE Alaska RMa NAME Nabor 27E Arctic Ri ELEV. RKB ABOVE MS 30 ABOVE CHF n ABOVE MUDL n CSG. SIZE 13 318 WT. GRADE SHOE DEPTH (MD) 2,005 n TOTAL VER. DEPfH 2,005 n MUD PROP WT. 9.3 VLS w rP API NIL GELS ono PIMN CALlBRA710N BBLSISTROKEO ePM 7VPE PUMP Rig Pumps TEST RATE 1/2 BPM TYPE TEST CSG CSG SNOE 1MOPEN HOLE LOT ~ OPEN MOLE PM TD OF TEST 2,035 Tw MUD PUPPED 1.00 BBL Mln] FLOWBACK 1.00 BBL PRED. FRAC GRADE PPG EpivY~A Mud NMpIA ®SHOE 1 2.324 PPG DEPTH 1M SAND BELOW CSG DRIR (TVD) FT ELEC. LOG FT TVD MAX PRES. OBSVD 320 PSI PR LIMB PPG TEST TEAM: McDade/Hunt mil HZ. Praes. 103 PSI Min H2 Stress 10.27 PPc STKS PSI 0 0 500 - -- 1.00 40 - _. - - - - - -- - - - -- -- --- --- -- -- -- -- -- 2.00 60 3.00 100 4.00 130 5.00 180 6.00 230 450 7.00 280 8.00 320 9.00 350 10.00 380 0 00 380 400 _ ~ 00 250 2.00 205 3.00 200 4.00 5 00 190 150 350 -- . 6.00 120 7.00 105 ~ 8.00 103 9 00 100 10.00 100 300 ,_ _ 11.00 ~ l 12.00 13.00 I 14.00 15.00 250 a i 200 i 150 - 100 -- i 50 0 --i __, _ - r _ __ - _{ 0 2.00 4.00 6.00 8.00 10.00 1.00 3.00 5.00 7.00 9.00 11.00 13.00 15.00 BBLS /MINUTES • Eni January 5, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7a' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Eni Petroleum: Rock Flour #2 (PTD # 206-166) Dear Mr. Norman, • ~C`I~~ F~. ~~~iasKa u-~ a uas ~u~+s, Lu~~~~~~~s.,,:,,, Ancharage This is a report of Eni Petroleum's well operations on Rock Flour #2 for the period December 29, 2006 through January 4, 2007, inclusive. December 29, 2006 Drill 16" hole from 1,061' to 2,015'. C&C hole, short trip to conductor shoe, RIH. Hole in good shape. C&C for running casing, POH. December 30, 2006 L/D BHA, clean rig floor, prepare to run casing. Run 51 joints of 13-3/8", 68#, L-80, BTC casing. C&C for cementing. Test lines to 2,500 psi. Pump 50 bbls spacer, drop bottom plug, pump 590 sx Arcticset Lite (465 bbls, 10.7 ppg) and 210 sx Arcticset I tail (35 bbls, 15.7 ppg). Drop top plug, displace with mud. Bump plug, check floats - OIL Clean cellar, flush diverter, blow down cement line. , ~ ~~~ ~~ ~~ Q \~~~~ December 31, 2006 WOC. Filter cement returns for delivery to disposal facility, clean pits, R/D casing running equipment. N/D diverter, cut & prep surface casing, N/U wellhead. January 1, 2007 Pressure test wellhead. N/LT BOPE, bell nipple and flowline. Pressure test BOPE to 250 / 5,000 psi. Thaw frozen lines and equipment. January 2, 2007 Thaw frozen lines. P/U and M/LT 12-1/4" cleanout BHA. RIH to 1,837', pressure test casing to 3,000 psi for 30 minutes - OK. RIH to FC at 1,918'. Drill FC, cmt, FS and 20' of new formation to 2,035'. Pull bit into shoe and conduct LOT to 12.3 ppg EMW. Displace 9.3 ppg spud mud from well with 9.5 ppg F1oPro system. Obtain slow pump rates and POH. Mr. John Norman Page 2 • January 3, 2007 POH w/ cleanout BHA and L/D same. M/LT 10-5/8" drilling BHA and RIH. Drill from 2,035' to 2,130. Disassemble pump to clean pieces of rubber cement wiper plugs from valves. Dri112,130' to 2,212'. Clean additional rubber from pumps. January 4, 2007 Continue removing rubber from pump valves. Drill 2,212' to 2,995'. Help respond to mud and cuttings spill outside cuttings berm. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ENI PE OLEUM ~:. ~~. Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: David Dougall - Eni Petroleum. ~ • .~ _ .. 4~~~ Y$. ~ l~ ~ [~ 3 ~-' December ?~, 20pfi I~~lr. John_Norman, Chair Alaska Oil and Gas Conservation Commission 333 Nest 7`h A4-e., Suite 1010 Anchorage, Alaska y9_50l Rl;: ~Vicekly Report of Operatic~us Eni Petroleum: Roel~ Flour #2 (PTD # 206-166) Dear Mr. Narm~u~, This is a report of Eni Petroleum's well operations on Rock Flour #2 far the period December 22 through December 28, inclusive. December 22, 2006 Move Nabors Rig 17-E subbase onto pad. Lay out liner over rig footprint Move_pipe shed, pits, generators. pump roam, c~~rnp and camp generators onto pad. Spot subbase over conductor. Ma~~e motor catnplcx onto pad and spat pits. December 23 2006 Continue riggizrg up: Spur matting boards and liner. Spot pits, motors, pipe shed acid satellite camp. Ruh power cables sndhook up service lines. Spot pump house and hook up interconnects between rig rnaduies. December 24.2(HX Continue rigging up: Spot and rig up pipe shed heaters. Berm around rig. Carnplcte transfer of equipment from stack location to drill pad. Repair faulty fuel pump on #2 boiler. Spot hulk fuel tank. Complete rig berms. Complete interconnects betti~~een rig modules. Function test top drive, drawwarks androtary table. ~'ut off conductor pipe and comnlcnce installation of starting flange. Rig up satellite camp generator. December 2~. 2.006 Rig accepted 00:00 hrs, 12125106.< III~tall pipe skate rail, service. drawwarks, connect suction line. ~~?"eld an wellhead and conductor. Prep mud pits for mud. NI[J divertcr system. Take on 331bbls spud n1ud, load pipe in pipe shed. Decernbcr 26, 2006 NILT diverter system and flare line. MILT 5" DP while rigging up se«~ ice companies. • • Mr. Jahn Norman Page 2 December 27, 2006 P/U 5" DP while rigging up service companies. Install rotary table drip pan, install mouse hole. P/LI and. M/U $HA. Function test di~erter -witnessed.-by AQGCC rep. MIU additional BHla. Pressure test surface equipment. P/U and orient MWD. RiH, tag bottom at 11~' kKB. Fill bola with water, check for leaks, displace hale w/ 8.8 ppg, 250 vis spud mud. Unable to operate mud pump #2. POH wi one stand HWDY and trouble shoot mud pump. December 28, 200fa Trouble shoot electrical problem with Hurd pump #2, Drill from 110' to ?62'. Trouble shoot M'WD decoding problems. Change out mud pressure sensor. Dri11 to 351' to bury BHA.. POH three stands. P/U 16" stb, ream back to bottom (20' of fill). Drill from 351 to 1,06I'. ;d~ you have any duestions or require additional information, please contact meat 253- 3446. Sincerely, For ENT PETR(~L.EUI~I .~`" ~": ;,f" Bill Penrose Vice President I Drill ing Manager Fairweather E&P Servii;es, Inc. cc: David Dougall - Eni Petroleum Rock Flour #2 • i Subject: Rock Flour #2 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Mon, 18 Dec 2006 13:55:50 -0900 To: Bill Penrose <bill@fairweather.com> CC: Steve Davies <steve davies@adminstate.ak.us> Bill, To follow-up on your recent call. Steve Davies is still waiting on receipt of the forms he needs. With regard to setting conductor, I am surprised about the contractor's desire to see the permit. So far as I am aware, setting conductor does not require a PTD. Drilling operations, the subject of the permit, are defined at 20 AAC 25.990 (23) as "...penetrating the ground below the setting depth of structural or conductor casing ..." Once the paperwork Steve needs is received, the permit should issue shortly thereafter. Call or message me or Steve as appropriate with any questions. Tom Maunder, PE AOGCC ~~~ ~e1 1 of 1 6/21/2007 9:09 AM Re: Notice of Ownership Form Needed Promptly I • Subject: Re: Notice of Ownership Form Needed Promptly From: david.lawler@~nipetroleum.com Date: Thu, 14 Dec 2006 04:47:04 -0900 (AKST) To: Stephen Davies <steve davies@adminstate.ak.us> CC: bill@fairweather.com, Tom Maunder <tom maunder@admin.state.ak.us> Stephen: I will give you a call this morning. In addition to Rock Flour #2, I assume we will need the same form for the permits for the other wells we are drilling this season. The situation with each of the leases is identical, they were acquired by Armstrong and assigned 100% to Eni. Thanks. David A. Lawler (713) 393-6126 phone (713) 393-6208 fax Stephen Davies <steve davies@adm in.state.ak.us> To david.lawler@enipetroleum.com, 12/13/2006 05:11 bill@fairweather.com PM cc Tom Maunder <tom maunder@admin.state.ak.us> Subject Notice of Ownership Form Needed Promptly David, While reviewing ENI's permit to drill application for Rock Flour #2, I noted that ENI has not filed Notice of Ownership form for lease ADL 390695. Land records from the Alaska Department of Natural Resources (DNR) indicate that Armstrong bid on this lease in October 2004 was awarded the lease in May 2005. Armstrong subsequently transferred 100% working interest ownership in the lease to ENI, effective September 2005. The Alaska Oil and Gas Conservation Commission (Commission) does not require a Notice of Ownership form from the initial owners of a lease purchased at a DNR lease sale. However, the form is required from every subsequent owner of that lease. The Commission's Notice of Ownership form, Form 10-417, can be found on our web site at http:l/www.aogcc.alaska.gov/forms/formsindex.shtml. The Assignor (existing owner - in this case Armstrong) must sign the Notice of Ownership form, and the Commission must receive the signed original copy for our records, including documentation that the representative signing the form is indeed legally authorized to do so. The legal description provided on the form must include the number of the affected lease and a detailed description of all affected ~~ . ~.~~ ~,r ~~;;c~ 1 of 2 6/21/2007 8:47 AM ~ Re: Notice of Ownership Form Needed Promptly • • governmental sections, including any segmentation. Please note that the permit to drill for Rock Flour #2 cannot be approved until this form has been filed with, and approved by, the Commission. The Commission received a revised permit to drill application for Rock Flour #2 this morning. On that application, the approximate spud date has been moved forward to December 20th. If you have any questions, please call me at (907) 793-1224. Thank you, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (See attached file: steve davies.vcf) Content-Type: application/octet-stream steve davies.vcf - Content-Encoding: base64 2 of 2 6/21 /2007 8:47 AM Bill Penrose From: Bill Penrose Sent: Tuesday, December 12, 2006 2:44 PM To: 'Thomas Maunder' Subject: RE: Rock Flour #2 Tom, Answers to your questions and comments are submitted in red below each item in your original e-mail below. Generally, the discrepancies you note result from last minute directional planning changes that didn't make it into the application attachments. The depths have been made consistent and the cementing calculations have been re-run. I will hand-deliver a new drilling summary (modified with corrected depths), re-calculated cement, new .directional plan and a new signed Form 401. Regards, Bill Penrose Vice President / Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, December 05, 2006 9:28 AM To: Bill Penrose Cc: Steve Davies; Dave Roby Subject: Rock Flour #2 Bill, We are reviewing the PTD application and have some questions. 1. The pilot hole TD (4332') on the drawing does not agree with the pilot hole TD given elsewhere in the program (drilling procedure and mud program 4600'). The directional plan uses 4632' md. Would you reconcile please? The planned TD is 4,332' RKB as shown on the wellbore diagram. The drilling procedure has been modified. The mud program will remain .the. same regardless of the referenced TD. 2. While traditionally 17-1/2" hole has been drilled for 13-3/8" casing, most recent programs I have examined have drilled 16" hole for reduced waste production and cement volume. The mud program hole diagram (page 4) shows 16" surface hole. Would you please reconcile? We plan to drill a 16" hole. It's been changed on the 401 and the cementing program has been modified and is attached. 3. On the drawing, the pilot hole plugging plan shows 2 plugs with a 100' interval of mud between the plugs. Setting a continuous plug in 2 sections is a practice often done on the slope without problems. Tagging the top open hole plug as planned is appropriate. 12/12/2006 We very well may set one cont~us plug, but will have to wai~ see where the hydrocarbon-bearing zones come in on the logs. 4. A Sundry Application (Form 403) should be filed. so that the pilot hole plugging program may be reviewed and approved. Agreed. 5. On the pressure calculation page, a 10-5/8" hole section is listed. I presume this should read 12-1/4". The hole diagram in the mud program also lists a 10-5/8" hole diameter. The pilot hole below the shoe of the 13-3/8" casing will be 10-5/8". This is the size of the coring assembly we'll be using extensively, so we'll just drill the whole section that size. 6. The MASP pressure calculated on the pressure calculation page does not agree with the value given in block 17 on the 401 sheet. Using .468 psi/ft and the tvd given (4332') does not result in the BHP given in block 17. Would you please reconcile? The values given in Block 17 have been changed to reflect the calculations which have been. re-checked. 7. The 9-5/8" casing depth given on the 401 sheet and drawing (4740' md, 3832' tvd) does not agree with the depths given in step 13 of the drilling procedure (5150' md, 4000' tvd). The mud program does list 5150' md, 4000' tvd. Would you please reconcile? The drilling procedure has been modified to reflect the correct. depths as given on the 401 and diagram. The mud program reflects depths before their later slight modification. The. new depths don't affect the mud program. 8. The slotted liner setting depth given on the 401 sheet and drawing (8664' md, 3862' tvd) does not agree with the depths given in step 18/19 of the drilling procedure (8573' md, 4000' tvd). The mud program lists the latter depths while the directional drilling plan lists the former depths. Would you please reconcile? The drilling procedure has been modified to reflect the correct depths. This brings it into agreement with everything but the mud program which, again, remains valid regardless of the minor depth change. 9. Reconciling the depths of the 12-1/4" hole and 9-5/8" casing should also reconcile the planned tvd setting depth of the ESP given in step 20 (4000' tvd). The depth given in Step 20 has been adjusted to reflect. the 9-5/8" casing setting depth. 10. The cement calculation for the 9-5/8" casing uses 12-1/4" hole and a and of 5150' and a tvd of 4006'. Reconciling the hole size and depths (5 and 6 above) should clarify these volumes. It does and a modified cement calculation. is attached. I look forward to your responses. Call or message with any questions. Tom Maunder, PE AOGCC 12/12/2006 SARAH PAL/N, GOVERNOR 333 W. 7`h AVENtiE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 David Dougall HSE Manager ENI Petroleum 1201 Louisiana Street, Suite 3500 Houston, TX 77002 Re: Exploratory, Rock Flour #2 ENI Petroleum Permit No: 206-166 Surface Location: 513' FNL, 1208' FWL, Sec. 28, T 11 N, R 11 E, UM Bottomhole Location: 840' FNL, 1526' FWL, Sec. 33, T 11 N, R 11 E, UM Dear Mr. Dougall: Enclosed is the approved application for permit to drill the above referenced exploratory well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 (Rock Flour #2PH) and API number (50-029-23335-70) from records, data and logs acquired for well Rock Flour #2. When the pilot hole plugging plan is determined, ENI should file a Sundry Notice (Form 403) providing the determined formation information and planned plug depths. ENI Petroleum Rock Flour #2 Permit No: 206-166 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. 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). DATED this day of December, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. Mr. Bill Penrose -Fairweather Chairman STATE OF ALASKA ~ J AI~KA OIL AND GAS CONSERVATION COMMISSION \~ PERMIT TQ DRILL ~-`~ RECE~~/ED 20 AAC 2s.oos 1 a. Type of Work: 1 b. Currant Well Class: F_xplOra~ry ~ Development Oii ^ 1 c. Specify if well ~ proposed for. Drill Q Redriil ^ Stratigraphic Test ^ Service ^ Devebpment Gas ^ Cowed MerA~l~ ~~f11f~SI0D Re-entry ^ Multiple Zone. ^ Single Zorn ^ Shale Gas 2.Operator Name:. 5. Bond: Blanket ~ Single Well ^ 11. a am+s Number ENI Petroleum Bond No. RL§DB8662ti 2LQ ~,gbL7 Rock Flour #2 3. Address: 6. Proposed Depth: n• B• 12. Field/Pool(s): 1201 Lousiana, St. Suit 3500, Houston, TX, 77002 MD: 8,684 TVD: 3,662 , 4a, Location of Wetl (Govemmenta! Sect~rt); 7. Property Designation: Exploratory Surface: 513' FNL,1208' FWL, SEC 28, T11N, R11E ' ADL 390695 Tap of Productive Horizon: 8. Land t7se Permit: 13, Approximate Spud Date: 2054' FNL,1304'PtNL, SEC 28, T11N, R11E N1A 12/20/2007 Total Depth. 9. Acres in Property: 14. Distance to Nearest .840' FNL, 1526'FWL, SEC 33, T11N, R1iE 2560 Property: ~~ ego g~ ~j5 ~.~.[• 4b. Location of WeU (State Base Plane Coordinates}: NAD 27 10. KB Elevation T5. Distance to Nearest W /~. r Surface; x- 577861.2' y- 59 r398S.9' Zone- ASP-4 {Height above GL): 32.23 feet Wimin PSI: ~ ,$.^I'nli s , 1$. [3ev~ted weNs: Kickoff depth: 2100 feet 1 T. Maximum Anticipated Pressures in psig (see 20 AAC 25.1735} iZ • 13. p(, Maximum Hole Angle: 90 degrees Dohmho~: 2027 psi Surface: .pet -~~~ ~~ia 18. Caskrg Program: Specifications Top - Setking Depth - eoitcrm Cement Quant' , c.f. or sacks Hote Casing Weight Grade Coupling Length MD TVD MD T'VD (inckading stage data) ~~y t 20" 80" 0 0 80` - 80• ~ Grouted to surface i 1~°a 13-318" 68# L$0 $TC 2,032' 0 D 2,032 2,032 - 2,798 cufR to surf incl excess 12-114" • 9:i/8" - 47tME L-80 BTC-M 4,740 0 D 4,740 • 5,832 • 1.906 culft to surf incl excess. 8-112" • 3-112" - 9.5# L-80 B3C 3,664 4,500' 3.671 8,664 3,862 - Slotted Liner, no cerrmnt 19. PRESENT YYELL COND ITION SUMMARY (TO be oompieted for Redriu and Re-Entry Caperationsj Total Depth MD (ftk Total Depth TVD {ft}; Plugs (measured): Effect. Depttt MD (fk): Effed. Depth TVD (ft}: Jtmk {measured): Casing Length Size Cement Yalume MD TifD ConductoriStnactural Surface Entennediate Production Liner Perforaton Depth MO {ft): Perforation Depth TVD (ft}: 20. Attachments: Filing Fee Q BOP Sketch ^ DriNing Program ^ Time Y. Dept Plot ^ Shallow Hazard Ana~rsis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drd~g Fluid. Program a 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Bqi Penrose 258-3446 Printed Name Davtd Dougall Title HSE Mann Signature ~ " r - Phone 713.393922 Date / ,/ .3,~ Commisslan Use Orrfy Permit to Drill ~ Number Zc~ ~ - ~~ API Number: 5D vZ9^' 23335' bC~ Permit Ap Dat See river letter for other , - e: ~ requirements, Conditions of approval : if box is checked. coral! may not be used to expbre for, test, or produce coalbed methane, gas hydrates, or gas rrontained in shales:[ Other: $DO O ~ 5't i ~ ~~'~ c,` ~~Y rest Samples req"d: Yes No ® Mud log req'd: Yes[ No^ '35 btu ~ g ° ~ rar~~~. +~v ~'CSO'1 '1~5'•~ '~h ~~<•~~~ HzS measures: Yes[ No ^ Direc'tiogal svy naq'd: YesO' No^ PROVED BY THE COMMISSION DATE: Z ~LQ~~ ~ "COMMISSIONER Form 117~t01 R®vised 12!2005 1 / ~ ~ Su rn Dupli~Le -Ob • 1 1201 Louisiana St Suite 3500 Houston, Texas 77002 » Lt.SA Phone (7I3} 393 6100 Fax {713} 393 6395 DecelTtber 13, ~ Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~` Ave., Suite 1.00 Anchorage, Alaska 99501 RE: .Application far Permit to Drill: Rock Floor #2 Dear Mr. Norman, Eni Petroleum. hereby submits revised information pertaining to the subject application for Permit to Drill. These revisions and clarifications were requested by the Commission during its review of the original application. Enclosed please find the following: 1. Copy of an a-mail response to Commission questions subnutted earlier 2, New Form 401 Application for Permit to Drill 3. Revised summary drilling procedure 4. Revised cementing program 5. Revised directional drilling plan Good progress is being made on ice road eonstnzction and it is arlr~tieipated that we will be ready to spud the Rock Flour #2 well apptgoitireately December 20. if you have any questions or require additional information, please contact me at (713) 977-5799 or Bill Penrose at (907} 25$-3446. Sincerely, ENI PETROLEUM ~. David Dougali HSE Manager enclosures • cc: Matteo Rivetti - Eni Bill Penrose -Fairweather STATE E3F At.ASKA ALASKAQlI AND GAS CONSERYATK}M C.4MMISS4QN REKNIT T4 DRILL NOV 2 9 2006 Alaska Oil & Gas Cons. Ca /~ /1 /1/+ f-~. r n11411U1 OaG V !Y\VL J 1a. Type E?f Wait:. tb. Garrard YVell t2a~: Explora4ory ~ nt 01 ~ 1G. S~t~fy li wed! FS prpposed Got; i~iil [~ RedrAl [~ Stratgraphia Test ~ Service Q Ueuek~prnerat Qes ~ Goalbed lulelhane [] Gas Hydrates fie-entry Mutepie Zone ^ Sirgie Lana © ShaiB Gas (] 2.Operator Marne: 5. t3ond: Blanket ~ 8in~ Web ~ 11, We0 Markle 8nt! N ENt Petroleum Bond No. R6QfXX~B(oZ'7 Rock F #2 3. Address: 8. Proposed ~P~ ~ . ~ 12. 1201 Lotashrrel $t, Suit 35001 Fbuston. TX, 77002 MO: 6,664 ~ TVD: 3,862 ' 4a. Eacatkut of WeN {G4wekrMl-ente! 3eetiorkj: 7. Properlyr CJpnation; Rrarptoraatory Surface: 48S' FNL/1208' t-Wl., SEC Z8, T11N1 R11E '. ADt 960899 Top of f'roducttve tirximn: 6~ lJae Permit: 13. App~cxinrata Spud Crate: 1249' FWL, 23~'FML, SEC 28, T11N, R11@ A 1/712007 Total Depth: 9. Acres >n Property: 14. Distance to Nearest 96T FNLI 1352'FVVi„ SEC 3Z. T11N, 811E 2960 Property: 819' 4b. t.pcetion of Weil {State 8aso Ptarl+ Gsordlna~l: IIAD 2T 10. KB Etavstior- 13. Dist2nea to Neatest WeN Surcaae: x. 3771.3' • y- 58560x47.2' ~ Zono- ASP~4 (~~ aboue till: .2.29 W min m 19. [leviatod x+elis; Kkitoff depth: 210Q 17. Ar~pa Prassrtt~ in psig (sea 20 AAC 25A35) ~ ~(. tldaatkrttrm Hoia Angie: 80 depr+eee 8 Surface: 2178 psf . 18. Casing Pr+opram• Spadtka8one T . - - t3ottom Gerrrant t'a~ar-t0y, c.f. ar sacks t-tde Gastng Weayht GraQe Coupling LengO- MD tW MD TV[f finiaa erase dotal ra i®. PRESENT YYEtI CONDIT~N $El {T oornpleted for t2edkill and Re~rrtryr (onsl , Total aw (~}: T {ftk Pk~s Effect. C>BPOt A~ (ftk tMpfh TVt? (flk Junk pneasuredx zo. Attadunentsw Ana Fee .. aoP skater a ortl ~,p Proprsm p ~. oeptr, r (~ sneikrw Hazard anaiy~s ^ ~P~Y ~~ Div~tar Sketztr (~ SO®rbed Report ~ Orllrng Fktkl Program ~]' 20 AAC 25.050 requdrernekds 21. WarbaF Apprava: t.omrtrissbn tisfi~: [fate 22. I hereby oerUfy tflat rite fob ~ true and otxrert. Contact &i! Pda'osd 2S8.3d46 Printed Name f>aMd 8 Title HSE r ° C~ Phone 743 .'lS3+B22 E3atb ~' ~ : %~ ~,''';,:ac~ Conani:sion flee Qnlf/ p~ ~,~° .ZD - /G ~ ~+ N 9"0-' o Z9' Z3 33 -OG o ~r+~rat sea coyer ~roer for otv-ar ~~. GontNtions of : tf boar CS chsdced, may riot tle reed b explOrs lox, fast. Cr pro~roe POGbed rrkettrane, pas hydra, Or gas con~red bt af~fea: Oilrer: Samples req'd: Yes[v~ No^ Mtad b0 teq'd: Yee[]v' ~Q ' i1zS measures: Y®s[vr No^ Gkeogonal svy rrq"d: Yes' N4~] APPROVi"t3 8Y THE DATE: Farm 10.401 RevlSed 1212005 In F)apticate 12• ~'~~ ORIGINAL ~~(~/ylo~ • E11~ ~~~ 120} Louisiana, Suit¢ 3500 Houston, Texas 77002 Phone: 713-343-6100 Fax;713-393-6205 November 28, 2446 Mr. john. Norman, Chair Alaska Qil and Gas Conservation Commission 333 West 7th Ave., Suite I04 Anchorage, Alaska 99541. RE: Application for Permit to Drill: Rock Flour #2 Dear Mr. Norman, • ~~ ~~r RECEIVED NOV 2 9 2006 Alaska Oil & Gas Cons. Commission Anchorage Eni Petroleum hereby applies fora .Permit to Drill an onshore oil exploration-well south of the Kuparuk River Field on the North Slope.. Eni plans to use Nabors Rig 27-E to drill, core and evaluate a vertical pilot hole; then plug back and drill a lateral penetration in one of the productive horizons. Thee well will be production tested for several weeks using an electric submersible pump and then will be permanently plugged and. abandoned.. prior to the end of the winter drilling season. ~ Rock Flour #2 will be drilled from an ice pad situated on a 23-mile long ice road from which additional wells will be drilled. and evaluated while Rock Flour #2 is being.. tested. Waste drilling fluids and ground cuttings will be disposed of via the Pad 4 grind and inject facility operated by BP in the Prudhoe Bay Field. Please find attached. information as required by 20 AAC 25.QQS (a) and (c) for .your review. Pertinent infonnatic+n attached to this application includes the following: 1} Form 10-441 Application. for Permit to Drill 2) Fee of $140.44 payable to the State of Alaska 3) A plat showing the surface location of the well 4) Diagrams and descriptions of the BOP equipment to be used S) Proposed casing program 6) Proposed cementing program 7) Proposed drilling fluid program 8) Proposed drilling program 9) Shallow Hazards Evaluation 14) Abnormal :Formation Pressure Evaluation 11) Schematic of the proposed wellbore and completion 12) Directional drilling program • Mr. John. Norman Page 2 • 13} Eni does not .anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning en the rig at all times during drilling and completion. operations. 14} The following are Eni's designated contacts for reporting responsibilities to the Commission; 1 } Coxnpletian Report Bill Penrose, Drilling Engineer (zo ~aC Zs.o7o} (9a~} 258-3446 2} Geologic Data and Logs Charles Russell, Subsurface Manager (2a AAC 2S.Q71} (713} 393-6251 If you have any questions or require additional infarmatian, please contact me at (713) 977-5799 ar Bill Penrose at (9a7} 258-3446. Sincerely, ENI PETROLEUM David Dougall HSE Manager enclosures cc: Matteo Rivetti - Eni Bill Penrose -Fairweather • • '~ ROCK (LOUR #2 ~~~ Planned Well Design Note: Depths measured from ground level = 70' AMSL 20" conductor set @ +100' RKB = 32' Above Ground Level 2-7/8", 6.5#, L-80, BTC tubing w/ ESP control cable ESP assembly in tangent section just above pay interval ~ 3-1 /2" liner set in 8- I /2" hole (unless 7"contingency liner is run, in which case liner will be in 6- I/8" hole) 3-I/2", 9.3#, L-80, BTC slotted liner set @ TD (8,664'MD, 3,862'TVDj - ~. drilling 9-5/8", 47#, L-80, BTC-M mud casing set at end-of-build at 4,740'MD, 3,832'TVD 10-5/8" open hole w/ cement covering hydrocarbon intervals TD @ 4,332' MD/ TVD ~ 13-3/8", 68#, L-80, BTC surf csg set at 2,000' KOP at +2,100' '' N Sand 3,830' - 3,900' OA Sand 4,000' ~4, 00' - ~~ ~ ~o~.~ OB Sand 4,070' - 4, 110' wj p 1 1 / 10/06 ,, • A yjy '.., Sri ~, .ar i ~ i ~ ~ ~• ! ~ ~ • ~. ~A ~ ~ ~ 'y ~_ ~ • ~•:i- .. '' Rock Flour #2 ~, ~[; r ' • a r + , •_ _ - ~o ~' r Latitude - 70 17' 04" s ,~ y •r Longitude - 149 22' 11" • ~ ~ . ~ ,:~ ~' .. ~~~ ~ ,~~ ~: WGS 1927 ~z• ~ 1.:~. i p `.4 ~ ,: v •. .,p µ4~. ~ # 573 Fi~/y i ZJS F~Jt~ , i`3 - ~~~ /~t ''~"~;a ~ ~ ~i{ ~ _485 FiVL, 1208'FWL, Sec 28, T11 N, R11 E ~• i~"~ • r ' • • • ~ • - .tom' ` ~ ~, ~~' ~ ~ r r ~ ~ ~ ~ ~ • ~ "~ ~ y ~-Rock~Flour #2 f '~ •. i •1 y J ~• z e ~ ` .~' ""ff~~ h • . a~'~ ~,• ~ :~.a .. ~ ~ ~ ... .~, . r ~ `; ` ., '~ ~ ~. ..y ,.~ ~ ~ ,III` •~ r '` T • .:. s ~~ +~ .R _ ~ ~ id Legend Well Locations ~~ ~-°~--~• As-Staked Ice Road Rock Flour Prospect ~fl~~~fll~{~ Satellite Photo from August 3, 1999 Landsat-7 PanSharpened to 15m pixels ~¢ Projection: UTM Nad83 Zone6 ~nl Elnl ~tlroNe~lm Full Scene Geotiff c N ``e`' BvQ~ ~~a 00 o~. c~ p0 \~ e~~ G°~`~9y~ Notes: \ 1. Ice pad is 6" thick except under ~ rig components and in cuttings berm ~~ where it is 12" thick. 2. Ice road is 6" thick and 32' wide. 3. Pad is oriented such that prevailing winds keep rig and well emissions away from living quarters. All project ice pads to share this orientation. ~ni Pad Layout Project No. Checked By: 8/01 /2006 Sheet No. File: Ice Road i ENI Petroleum • Pressure Calculations, Drilling Area Risks and Waste Disposal Rock Flour #2 Maximum Anticipated Surface Pressure: 10-5/8" Hole Section The maximum anticipated pressure (MASP) for the 10-5/8" hole section in this sidetrack will be the lesser o£ a) the formation pore pressure (less a full gas column to the surface) at 4,332' TVD, orb) the fracture pressure at the 13-3/8" casing shoe at 2,032' TVD. Offsetting well information indicates that the pore pressure at TVD will be a maximum of 9.0 ppg (0.468 psi/ft) EMW. The formation strength data obtained in this area are two leak-off tests (12.5 ppg or 0.654 psi/ft) conducted in the Schrader Bluff. Calculations for (a) 10-5/8"" hole section MASP (pore pressure) = (4,332 ft) (0.468-0.11) = 1,SS 1 psi Calculations for (b) Fracture pressure at the 13-3/8" casing shoe at 2,032' TVD= (2,032) (0.654-0.11) =1,lOS psi -- Thus MASP in the 10-5/8" open hole section is 1,1 OS psi and the 5,000 psi BOPS system to be used will be adequate. Well Proximity Risks: The closest wellbore to this one is the plugged and abandoned Rock.Flour #1 located approximately 2.4 miles away so there is no anticipated interference expected between wellbores. Drilling Area Risks: The operator of the Rock Flour #1 well encountered gas and chloride influxes at 7,300'. Rock Flour #2 will be drilled to only 4,332' TVD so will not encounter that problem. Nevertheless, the drilling crew will be kept aware that mud weight increases maybe needed. There is a remote possibility of encountering with gas hydrates, though none of the offset wells did. If hydrates occur in this well, they will be treated with control drilling, increase of mud weight, cooling of the mud and addition of lecithin.. • r There is no anticipated risk of H2S in the area as indicated by the lack in any of the offsetting wells, However, as a precaution, the rig and mud logging units will have functioning H2S detectors. Disposal of Muds and Cuttings: All drill cuttings and waste drilling fluid will be disposed of in BP's grind and inject facility at Prudhoe Bay. ENI US Operating Company Inc. Rock Flour #2 Casino Properties and Design Verification Casing Performance Prpoerties Internal Collapse Tensile Strenght Design Safety Factor* Size Weight Grade Cnxn Yield Ressistanc Joint Body TVD MD T B C (in) (Ib/ft) (psi) (psi) (1000 Ibs) (ft RKB) (ft RKB) 13-3/8" 68# L-80 BTC 5020 2260 1556 2032 2032 13.2 13.4 2.07 9-5/8" 47# L-80 BTC 6870 4750 1086 4032 5150 4.9 7.72 1.79 * Tensile design safety factore are calculated using pipe weight less buoyancy. Burst design safety factors are calculated at the surface using zero backup on the outside and MASP on the inside. Collapse design safety factors are calculated at the casing shoe using maximum expected mud weight to be used at the shoe depth on the outside and the entire cased hole evacuated except a gas gradient on the inside. Casing Setting Depth Rationale 13-3/8" 2032.25' MD/2032.25' TVD 9-5/8" 5,150' MD/4,032.25' TVD Surface Casing to stablize shallow formations, provide an anchor for the BOP stack and provide shoe strength in the event of kick Intermediate casing needed to protect formations below the surface casing from the pressure created by the high drilling-fluid density. • 4' 3 7/C I \I ` ~- _- 9' 8 1/e' _-_____-_-_-_-___-_ - 3ro•~__ __ _ _____ _ ___. _______ 2' 6 1/e' _~ 3 5000/ GATE VALVE ' t' t0 5/e' 3 5000/ HCR VALVEp I{~ 2' KILL LINE s x' 9' a 1/e' LA' --'----------- o' to ~/e' CUSfONEIi FURNISHED -21 1/e' 2000/ NYORIL BOP/OIVERIER H FLG SURFACE DIVERTER PIPING CONFIGURATION PLAN VIEW 13 5/B' 5000/ HYDRA ANNULAR BOP BOLTED FLANGE SINGLE 13 5/B' 5000/ HYDRIL NPL PIPE RAN BOLTED FLANGE SINGLE 13 5/B' 5000/ HYDRIL NPL BLIND RAN ~ BOLTED FLANGE 4' 5000/ HCR VALVE I ~~ 4' CHOKE l1NE \ t' 5000/ GALE VALVE ~ BOLIm FLANGE SINGLE 13 5/B' 5000/ HYDRIL MPL PIPE RATA BOLTED FLANGE AOAPIER SPOOL-- HUB x FLANGE SURFACESURFACE DIVER~R CONFIGURATIONCONFIGURATION H:VLCADFILE\27E\BOP\27E0301C.DWG,12I07I01 01:02:51 PM cA1E AGSWODR 12/Oe/01 E JA RN. IIOOw1m ONEwRA SGf (te7 / CONFIGnAlI011 o9/a/ee e re iN cwrr~n c1AJlP m/wA:cllox ro eoum HAAa oz/91/n a ASB RNI ROiKED oNERIFA A9 PFA ocw /~ m/9xNe a owe u maw wsuE aPoVn • ieE u maw ~ ovE A,R'• ~ 9ESCwPnox ~N~wsAlmlm ~ c s'~'"eiet w~ m""o AAAAIIMeAl01/R~Oxw MehoraCa. Na~ka 99507 907-20.1 6000 A~ RIG 27E BOP STACK AND SURFACE DIVERTER BOP STACK ELEVATION • ~ ~~~t `... ~ ` . 1 __._, • • ENI Petroleum Rock Flour #2 Drilling Procedure 1. Prior to moving in drilling rig, excavate and install cellar then drill and cement 20" conductor to 80' below ground level. 2. Move in and rig up Nabors Rig # 27-E. Install diverter on 20" conductor and function test. l~~t~ ~OC.L-L~ i~H ~% 3. Drill 1 /2" hole to +2,000'. ~ 4. Run 13-3/8" 68#, L-80, BTC surface casing and cement to surface as per cementing program. 5. Install wellhead, land casing and N/L1, SK WP BOPE and test to 5000 psi. N ~k ~ y -~O~ LC_~ar •,.9 ~~ ~s s, 6. M/U 12-1/4" drilling assembly, clean out to float collar and test 13-3/8" casing to 2500psi. Drill out float collar, cement, float shoe and 10' of new hole. Conduct leak-off test. POH. 7. M/U 10-5/8" drilling assembly. RIH. 8. Drill 10-5/8" vertical hole to 4,332'TD, cutting 30' and 60' full-hole cores in intervals of interest. -, 9. At TD, condition the hole and run open-hole logs. 10. At the conclusion of logging, plug back the open hole with cement, isolating hydrocarbon-bearing intervals per AOGCC regulations. Verify OH plugs by tagging w/bit. , 1 11. Place a cement plug across the surface casing shoe extending from 1,900' to t 2,200'. POH and WOG 12. M/LT a 12-1 /4" straight hole drilling assembly and RIH. Drill out the cement plug in the 9-5/8" casing to 2,100'. POH. 13. M/LJ a 12-1/4" directional drilling assembly and RIH. Kick off the cement plug. POH. 14. M/U a 12-1/4' rotary steerable assembly and RIH. Directionally drill a 12-14" hole as specified in the directional program, landing out horizontally at 3,832' TVD, 4,740' MD. Condition the hole and POH. • • 15. Run 9-5/8", 47# (or 40#), L-80, BTC casing to TD and cement to surface per the cementing program. WOC. 16. M/LT an 8-1/2" drill-out assembly, RIH and tag the float collar. Pressure test casing to 3000psi .Drill out the shoe track and 10' of new hole. Condition mud and conduct aleak-off test. 17. Displace the water-base mud system in the hole and in the rig's surface system to oil-base mud. POH. 18. M/LT an 8-1/2" rotary steerable assembly and RIH. 19. Dri118-1/2" horizontal hole to 8,664' MD, 3,862' TVD. Condition Mud and POH. 20. Run 3-1/2" 9.3# L-80, EUE 8rd slotted liner to 8,664' MD, 3,862' TVD and hang off at 4,650' MD in the 9-5/8" intermediate casing. 21. Run a completion consisting of 2-7/8", 6.5#, L-80 EUE 8rd tubing w/ESP control cable and an electric submersible pump assembly located in the tangent section just above 3,800 TVD. 22. N/D BOPE, N/U tree, Test tree to SOOOpsi. Release drilling rig. 23. Rig up flowline, temporary testing facilities and ESP power unit. Place well on long term (approximately three week) test. 24. At the conclusion of testing, the well will be plugged and abandoned per AOGCC regulations, leaving ESP assembly and tubing in place. LCO~ cR~ \~ c~..~-~b.~~~~~5 Sc. `~ • Formation Evaluation Program Formation Evaluation While Drilling: Contractor: Schlumberger Oilfied Services FEWD tools: Vertical Hole: Casing /shoe: hole size: tool size: measurements 20.000" 16" 8.5" GR / Rt 13.375" 10.625" 8.5" GR/ Rt r tool: GR/ARC PWD GR /GVR to top of core point N sand At total depth make a mad pass over the entire open hole interval (for complete /continuous LWD log). Sidetrack Hole (landing section): Plug back to 2,100' MD & drill to landing point Casing /shoe: hole size: tool size: measurements: tool: 13.375 12.25" 8.5" GR/ Rt GR /GVR Mud motor power pack 1St run Rotary steerable /power drive Lateral Hole: (lateral hole) Casing /shoe: hole size: tool size: measurements 9.625" 8.5" 6.75" GR/ RUDensity Hole Sizes: 17.5", 10.625", 8.5" (in the lateral) Tool Sizes: 8.25" and 6.75" tool GR/ARC~ se periscope for geosteering Measurements: Gamma Ray / Resistivity (*ARC -,Resistivity at Bit, ** GVR - GeoVision old RAB tool) Wireline Logging: Contractor: Baker Atlas Log interval: from total depth of 4,300' TVD to the 13.375" casing shoe at 2,000' MD / TVD. Hole Size: 10.625" Services: would be a Grand Slam (Spectral Gamma Ray/CN/ZDL/HDIL/XMAC), GR/ CBIL / HDIP, GR /MREX, RCI, sidewall cores and velocity survey (VSP). ~- o oL Run 1: GSLAM (Spectral Gamma Ray/CN/ZDL/HDIL/XM~) ~~ /~ ~ . Run 2: GR/ CBIL /HDIP Run 3: GR /MREX - •~~ ~ tL•zd•a~ Run 4: RCI -Formation Pressures and Samples (see below) Run 5: VSP - (see below) Run 6: SWCs (50) ~~(~,~VE® Disclaimer: Order does not indicate priority of service. DEC 1 9 201]6 Formation Pressures and Samples Alaska Oil & Gas Cons. Commission ,( Anchora e Conveyanlce: Wireline a~'~' ~~-'G'"r''`~~ !"~ t?•2°-O~ 9 Straddle Pacer on PCL (Optional) Sample Tanks: 2mini-samplers (12 tanks) + 1 SPT II (2 tanks) Configuration: Standard tanks - 8 x 840 cc GRIGINAL Rock Fluor: RF #2 Geological Well Program Single Phase -- 6 x 450 cc Formation Pressures: approximately 25 in the N, OA & OB sands Formation Samples: Standard Single Phase SPT II Na 2 1 1 Nb 2 1 OA 2 1 1 OB 2 1 VSP - Interval: 4,300' MD - 2,000' MD every 50' levels (46) 2,000' MD - 100' MD every 100' levels (19) 12!19!2006 Note: Log quality standards, calibration requirements and log presentation documentation is provided in Appendix "A". * AOGCC format CD ROM and hardcopies has to be sent directly to AOGCC Mud Logging Services: Contractor: Epoch Well Services (a Nabors Co.) Services: Reduced Service Log interval: From 20" casing shoe at 100' MD / TVD to TD @ 4,300' MD / TVD Services: Operating Service Reduced Service 2 surface loggers senior alternately on duty Equipment/Sensor 1. Gas Detector~ir-~ S ~.e,.~.c~'s ~D 2. Degasser L rz'2"-O~ 3. Stand Pipe Presure 4. Pump Stroke 5. Hoak Load 6. Mud Pit Level 7. Hook Movements Operating Services Cutting Sampling Interval = 30' and every 10' in all ZOI 4 surface loggers with at least two senior alternately on duty All equipment and sensor required DECEIVED DEC 1 9 2006 Alaska Oil & Gas Cons. Commission Anchorage Real-time data monitoring: The Mudlogging data will be displayed in real time through the BHI Riglink * AOGCC .copies have to be sent directly as per instruction in Appendix "B" Z nplr! I /~ ._ Rock Fluor: RF #2 Geological Well Program Geochemical Samples: Isotubes: Frequency 100' MD to 2000' MD 500' 2000' MD to 4,300' MD Total Depth 30' (Increase amount in ZOI and Shows) Conventional Core: • Conventional Core Acquisition: BHI Conventional Coring Handling: Core Laboratories Conventional Coring Analysis: Core Laboratories ~2nsizoos Conventional Acquisition: Baker Hughes Inteq will acquire 170' of conventional core in four (4) runs. The Baker Hughes Inteq 6.5" x 60 x 4" hydrolift core system will be utilised. The core assembly will have an Antiwhirl PDC AXC 425 bit. Aluminum inner core tubes with check valves every foot are planned. Four 60' core barrels will be run for the 170' total core. Contengency will be made for an additional 60' core barrel. The N sand coring point will be determined from correlations. The OA and OB core point will be determined based on reservoir characterization from LWD logs. Core Point Selection: The Project Geologist and Subsurface Manager will be on location for the core point selection. Baker's real-time Gr / Rt LWD tool (with resistivity at the bit) will be used to determine the core point selection. Once the LWD GR/Rt encounter the top of the OA and OB target sands the drilling will cease in each case and the drilling assembly will be pulled out of hole for the Baker Hughes Inteq conventional coring assembly. The first 60' core in the N sand will be acquired, pulled out of hole, gamma rayed and laid down. Once the inner core barrel is laid down on the catwalk, Core Laboratories will make a surface gamma ray on the core. Meantime the next core barrel and coring assembly will be made up and tripped back in hole for the next core. The sequence will repeat for the OA and OB reservoirs. Core Handling: Core Lab personnel will be on location to freeze the core and cut into sections for loading into the core freezer boxes. The Core Lab personnel will stay with the freezer boxes until they reach the laboratory. ~E+GE1VE® DEC 1 9 2006 Alaska Oil & Gas Cons. Commission Anchorage 3 Rock Fluor: RF #2 ~ ~ 12/19/2006 Geological Well Program Formation Pressure Measurements and Sampling: Contractor: Baker Atlas (Wireline)- RCI (TBA) The N, OA, OB sands are the primary targets and the expected hydrocarbon type is oil. For Formation Evaluation and Flow Assurance purposes, RCI pressure measurements and fluid samples will be taken in the targets sand. Note: Formation Pressure and Sampling Procedures are provided in Appendix "E" Sidewall Coring Analysis Wireline Service: Baker Atlas Contractor: Core Lab A total of 50 Sidewall cores (SWCs) will be taken in 10.625" hole section ,where zones of interest will be encountered. Sidewall cores will be taken in a range of lithologies and reservoir fluids to characterize and calibrate log data with the reservoir. More than one run could be required to calibrate the pay sands, wet sands and shale intervals and perform seal analysis on the top and bottom reservoir seals. Paleontology (OPTIONAL) Rigsite Biostratigrapher: Contractor: Paleo Data Inc. Log interval: from 20" CSG shoe to TD 4,300' MD Services: Paleontological sample collection for Foramnifera and Nanno Plankton analysis. DECEIVED DEC 1 9 2006 Alaska Oil & Gas Cons. Commission Anchorage GRIGINAL • ENI Petroleum Rock Flour #2 Drilling Procedure • 1. Prior to moving in drilling rig, excavate and install cellar then dril 20" conductor to 80' below ground level. 2. Move in, rig up Nabors Rig # 27 E. Install diverter in 20" o conductor and function test. NoE~~~~ Q,c7C~LC~,~-~,,;~~.~SS . 3. Drill 17-1/2" hole to +2,000'. 4. Run 13-3/8" 68#, L-80, BTC surface casing andltement to surface as per cementing program. / 5. Install wellhead, land casing and N/LT, SK BOPE and test to 5000 psi. ~kil:~ ~ P.D U CL~orv:,~t res g 6. M/iJ 10-5/8" hole drilling asse 1~i(.~ an o t to float collar and test 13-3/8" casing to 2500psi. Drill out flo~` `Cy~l r, nt, float shoe. 10' of new hole. Conduct leak-off test. w ~ :~ ~ 7. Drill 10-5/8" vertical hole 09~'F~b. Cutting 30' and 60' full-hole cores in intervals of interest. va 8. At TD, condition the hol~and run open-hole logs. 9. At the conclusion of gging, plug back the open hole with cement, isolating hydrocarbon-beari intervals per AOGCC regulations. Verify OH plugs by tagging w/bit. 10. Place a ceme plug across the surface casing shoe extending from 1,900' to 2,200'. PO and WOC. 11. M/U a l -1/4" straight hole drilling assembly and RIH. Drill out the cement plug in the -5/8" casing to 2,100'. POH. 12. M a 12-1/4" directional drilling assembly and RIH. Kick off the cement plug. P H. l~! M/U a 12-1/4' rotary steerable assembly and RIH. Directionally drill a 12-14" ~ hole as specified in the directional program, landing out horizontally at 4,000' ' TVD, 5,150' MD. Condition the hole and POH. • • 14. Run 9-5/8", 47# (or 40#), L-80, BTC casing to TD and cement to surface per cementing program. WOC. 15. M/U an 8-1/2" drill-out assembly, RIH and tag the float collar. Pressur est casing to 3000psi .Drill out the shoe track and 10' of new hole. Co ition mud and conduct aleck-off test. 16. Displace the water-base mud system in the hole and in the 's surface system to oil-base mud. POH. 17. M/IJ an 8-1/2" rotary steerable assembly and RIH. 18. Dri118-1/2" horizontal hole to 8,573' MD, 4,0 'TVD. Condition Mud and POH. 19. Run 3-1/2" 9.3# L-80, EUE 8rd slotted 1' er to 8,573' MD, 4,000' TVD and hang off at 5,050' MD in the 9-5/8" interme late casing.. 20. Run a completion consisting of 2- /8", 6.5#, L-80 EUE 8rd tubing w/ESP control cable and an electric j ersib pumda assembly located in the tangent section just above 4,000 TVL? 1..,!! 21. N/D BOPE N tre /U e tree to/SOOOpsi. Release drilling rig. .~ ~ : M 22. Rig up flowline, t~~"rri ~~t~st~ig facilities and ESP power unit. Place well on long term (a xi ate hree week) test. 23. At the conclusi of testing, the well will be plugged and abandoned per AOGCC regulations, l ving ESP assembly and tubing in place. x-1,03 :"~~~~c~.~.or r~c~c~sseaey. • • WELL SITE SURVEY SHALLOW DRILLING HAZARDS EVALUATION PROPOSED ROCK FLOUR #2 ALASKA STATE LEASE 390695 NORTH SLOPE, ALASKA Summary The available CDP geophysical, velocity, and proximal well data have been examined and evaluated for shallow to intermediate depth drilling hazards. Data from offset wells suggest that natural gas hydrates are likely to be encountered in sands and gravels of the Sagavanirktok Formation (800 to 2600' TVD). Our well plan is designed with this potential hazard in mind. The proposed surface hole location will be 565 FNL & 1160' FWL of Section 28, Township 11 North by Range 11 East (x=1347730.96', y=25587784.26', NAD27, UTM Zone 6). For the lateral well the associated bottom hole location will be 653' FNL & 1320' FWL of section 33, Township 11 North by Range 11 East (x=1347683.064', y=25582364.103', NAD27, UTM Zone 6). Geology The proposed drill site is located in the coastal plain region. Throughout Quaternary and possibly late Tertiary time sedimentation. in this region has been dominated by the Colville River Delta. Superficial sediments include coarse sand, gravel, and boulder lag deposits of Quaternary age. The underlying Pleistocene section, the Gubik Formation, consists of channelized marine and nonmarine muds, sands, gravels, and low grade coals. Locally the entire Quaternary sequence is less than 900'thick. Underlying the Gubik Formation is the Sagavanirktok Formation, which ranges in age from Upper Cretaceous through Tertiary. The Sagavanirktok Formation consists of complexly interbedded marine and nonmarine shelf and delta plain deposits composed of .unconsolidated sand, shale, and conglomerate. Locally the Sagavanirktok Formation is approximately 2,000' thick and gently dips to the northeast at 1° to 2°. The Colville Group lies conformably below the Sagavanirktok Formation. Deposition of the Colville Group spans the interval of time between the Late Cretaceous through Lower Tertiary. This group is comprised of three formations in the prospect area. From youngest to oldest they are the Ugnu Formation, Schrader Bluff Formation, and the Colville Mudstone. The N and OA sandstone of the Schrader Bluff Formation are the targets of this well. The Schrader Bluff Formation contains significant reserves of viscous oil in the Milne, Orion, Polaris and West Sak fields. Oil was also found in surrounding wells. ~ • Geophysics The Rock Flour 3D survey, acquired by Western Geophysical Company and recently reprocessed for a PreSTM, and the wells in the drill site surrounding area were analyzed for potential shallow and intermediate depth drilling hazards (see enclosed seismic/well base map). Illustrated inline and crossline (both intersect the Rock Flour #2) are enclosed for your reference. Rock Flour #2 interval velocity/pressure profile was constructed by integrating all available offset logs, subsurface pressures and seismic data and is attached for reference. Potential Shallow Drilling Hazards Perma frnct The permafrost thickness is characterized by high-resistivity and high-velocity logs and it is easily recognized in the wells. In the onshore seismic the base of the permafrost is not associated with a unique strong reflector (like the Bottom Simulator Reflector in the offshore seismic) and it is not easily interpretable. The analyzed wells show a progressive deepening of the base of the permafrost in a north-east direction. USGS well data support this regional trend. Taking into account all the available wells, in the ENI acreages the base of the permafrost is comprised between 1400 and 1800 ft (TVDSS). We expect thabase of the permafrost in Rock Flour #2 at around 1700 ft (TVDSS). - Shallow Gas/Oil Accumulations There is no geophysical evidence for significant accumulation of shallow gas beneath the Rock Flour #2 location. No amplitude anomalies, velocity sag or frequency attenuation indicators are present from 3-D seismic covering the location. ~ As reported in literature, there is some chance of penetrating natural gas in the sands of the Sagavanirktok Formation. The enclosed map shows the regional extension of the gas hydrates and the free gas. Rock Flour #1 mudlogs detected gas show between 2550 and 2750 ft (TVDSS), Hemi Springs State between 2750 and 2900 ft. In the available 3D these gas levels are not associated with relevant seismic gas indicators. Minor elevated background gas levels within and below the permafrost interval are being planned for in the proposed Rock Flour #2 well. v The previously referenced vertical pressure profile, which incorporates all pertinent engineering, geological and geophysical data, served as the basis for design and development of all operational and safety plans for the Rock Flour #2 well. Summary We have not identified from seismic or offset well data any conditions beneath the Rock Flour #2 location which could pose a prohibitive shallow or intermediate depth drilling hazard to the planned drilling operations. Natural gas hydrates are likely in the sands and gravels of the Sagavanirktok Formation (800 to 2600 ft TVDSS) and the drilling plan has been adjusted accordingly. A copy of all pertinent data to shallow geological and drilling safety conditions has been supplied to operations and engineering personnel in the preparation of the Rock Flour #2 well design -and operational plan. • • WELL SITE SURVEY ABNORMAL FORMATION PRESSURE EVALUATION ROCK FLOUR 2 LOCATION ALASKA STATE LEASE 390695 NORTH SLOPE, ALASKA The available geophysical data and proximal offset well data to the Rock Flour #2 (565' FNL & 1160' FWL of Section 28, Township 11 North by Range 11 East (x=1347730.96', y=25587784.26', NAD27, UTM Zone 6) have been examined and evaluated for potentially overpressured strata. Examination and evaluation of these data suggest that formation pore pressure increases at a normal gradient with depth and abnormal pressure is not anticipated to the proposed total depth of 3800 ft SSTVD. For the lateral well the associated bottom hole location will be 653' FNL & 1320' FWL of section 33, Township 11 North by Range 11 East (x=1347683.064', y=25582364.103', NAD27, UTM Zone 6)). A seismic/well base map highlighting the area of 3-D coverage, 2D coverage; key seismic transect, key offset wells and the Rock Flour #2 well location is included for reference. Also included is a pressure versus depth plot generated for the Rock Flour #2 well from available geologic, petrophysical, engineering and geophysical information. The plot depicts increasing formation pressure along the "x" axis versus true vertical depth on the "y" axis. Examination of all velocity, density and MW data from the offset wells show a general increase of internal velocity and pressure with depth to the limit of penetrated formation below 3800' within the area.. Based on our analysis of the formations to be penetrated by the Rock Flour #2, no overpressure is anticipated above the proposed total depth of 3800' SSTVD. ~" This overpressure evaluation is supported by all available geophysical and petrophysical data. Those wells considered key offset for well planning purposes are highlighted on the aforementioned seismic/well base map. The total depth of these wells ranged from to 5900' to 10930' TVD. Rock Flour #1 and Hemi Spring State has been analyzed to define the compaction trend of the area. Rock Flour #1 reached a TVD of 9354' (11.2 ppm MW) while Hemi Spring State was drilled to 10931' TVD (10.0 ppg mw). Both these wells exhibit normal compactions trends (see attached depth vs pressure chart). As it is general practice to drill slightly overbalanced, in situ pore pressures are likely less than the observed mud weights. In summary, abnormal formation pressure is not anticipated beneath the proposed Rock Flour #2 well location. All operations and engineering personnel have been advised of the anticipated geological drilling conditions. • • ~1 1915 4 54045 5~J 575 ^533 9 599251 ia 150 1 0 9 , 1~0 , 1yJ 1}0 150 1~0 1 2 2 2 2~ 3 3 2 2 9 2 2 0 2 2 9 3 3 6b 3 3 6b 3 70 CDP 8 b ~ ~J ' 4 ~ ~b ~p i I 1 I ~ 56 ~ ~ ~ .J . JJ L ~. ~ ~ 9 009 9.900 0,95 ~:~'. + ~ , . ~ . _ , .. ~ ~ u~,di~iaw ,~~ ~ , 0.959 0.10 ~a. '"' ~.ou.: ~ ~ *` ~ ~ 0.159 19.15 _ 029 ~ :' " e~,~ '" ,k. __ ~ ,,, - _ _ ,w ~n.~ 0200 025 ~"' ~1~ . ~' +~ .,,q,,~.y"~.: ~ •sw.M:x „,,ate„ `"~ 0259 0,39 ~ "fir ~ ~~ °'° ~,.. ~ ~ _~ a ~ _ ,;::~?a ~ 0:340 0359 `~" ~'"'," '~" ° ,~ _ ~ ~- ~ ~~ - _ Expected 0 350 4.49 " +~ ~ a ,* . te. ~~`' Base of the permafrost °''0° 45 0 w~ - ., .~,m, 9,+59 . ., " - n ~~ ~ .~'~ µ 1.194 Ob0 .„. r^ ~ ~, ~ u~ w"° ,55 ~wrrr", te. - , M,~rw~,~.-,w~,~, ., ..~„~,. ~ .,~,....~ ~ ~~ u „~ - ., 554 0.69 '~=`-~~.. ~~err`r'.,~""~ ~4"" a. _. w,r~wr ~ '~ 9.690 9.659 "^'~r.~ ~ 'AR "~ - +~ -.. ~ *r`e~,~ P ~-~+~r~-~~11~ +~`~-+~~ . , `~ ~~,~~ __; ijp , 4.650 9.704 ~~ ~~` ~ ,~r~•y~„~ _ - : 0.700 9,750 >. ..,,,,y,,,, ~ „ -~ :.,~ "'~r.r. ~~~hrM1/ ~- 9.750 099 ,,,~ ~~`' ~+ ..nq -, ,, .~, 0900 095 ----- ~`,,,~~ ~. _ r ~'~"'~'~°' ~`' ~ . .~ ~' wwirwi r ''"~wA~ ~ro~y~ ~ 4950 9.9°0 -~u~, - ~.,- `, _....:Y_ 0900 ~ ., ~ -~ """' ", Top Schrader Bluff FM 4 950 0954 ~-« mm~ ._„ e .~_..~``^~,,~~~.~."`~~ ~ , ---,---~~..W`..`„~ N sandstone . 1,44 ; 1.OOo 1,050 - '~„n'- ~° ~ Top OA sandstone 1.954 „~ , ~ 1.,9 -` ..-' ~ ~~~"~""~"'""'" ~. w ~- _ Base OB sandstone a 1'9° 1.150 . ~ ~, t ~ . 1.159 120 ~- M :_ _, ~ ~_3.~rr ~~ ~ ~ 1244 ~ ' ~. 125 '" '"'" ~ ,° . ~: as, - _ -'_ 1250 .. - ` 1300 1300 .t:~ ~,.,. ;,' . 135 ~~, _a ~, ` ~~ ~~ ~+a ~ ~ 1350 1.404 :, _ ~ ~~~.. ~~ ~,w'~rwwNMww~, ~ 1.4°0 1A5 rakfbur3d ~"- ,, , ~, „ - 1.459 pp~~tm2_ada ILN 1185 ~ ~" .. " +n"'~ ` wrM~ 1520 >lme ~=,,~ ~ ~ -ww~~ =-~n~ wwwww _1`r~Q • • Rock Flour Area Sonic Velocity 0.00 5000.00 10000.00 15000.00 20000.00 25000.00 0 ------------- -._ _. _ . ~ .~ -_ _- ,-- _ ... _ ..._ 500 - - --_ . ------~- _ - _ ..__ - - _ ,_------___-- a ~_ _ _ _ ~ I ..:.. _ . 1000 ~ _,_,_ -- ,1__`_ _ -~ ._. -- z • RF1 & Hemisprings Pressure Data 0 ~ _-~ - -- -•- RF1 MW -~- RF1 PP ~ Hemisprings MW -~- Hemisprings PP ~ Colville High Regional Data -- - ~ - - 2000 4000 ~ 6000 t Q d D 8000 10000 12000 ~- 6.0 7.0 8.0 9.0 Pressure data ppg 10.0 11.0 12.0 • • DRILLING FLUIDS PROGRAM >~ ''"~ C~~ii~ ° °t~roll~~u~~n~n ESN Rock Flour #2 Exploration Well Name Signature Date Originator: Hal Martens Reviewed by: Jim Cucullu Customer Approval: Bill Penrose/ Amjad Chaudhry Version: 1.2 Date: November 8, 2006 Location North Slope Alaska Confidential 1 Date: Novemeber 8, 2006 • • Rock Flour #2 Project Summary Casing Size in Hole Size in Profile Measured Depth ft TVD ft Mud S stem Mud Weight 20 n/a 100 100 n/a n/a 13.375 16 2,000 2,000 Spud 8.6 - 9.5 n/a 10.625 Motherbore 4 600 4 600 FLOPRO 9.4 - 9.5 , , 9.625 10.625 Sidetrack 5,150 4,000 FLOPRO/LSND 9.4 - 9.5 3.5 5 8 Sidetrack 8 573 4 000 VersaPro 5 9 4 - 9 (liner) . , , . . Location North Slope Alaska Confidential 4 Date: Novemeber 8, 2006 • • ~~ `Rock Flour #Z Surface Interval Drilling Fluid System Spud Mud Key Products Gel, Caustic, telex, Pac Supreme, Duovis, Soda Ash, Bicarb, SCREEN KLEEN, DrillZone Solids Control Shakers, Mud Cleaner, Centrifuge Potential Problems: Running gravel, unconsolidated sand, clay Losses or wallcake build u 'in the U nu INTERVAL MUD PROPERTIES Depth MD (ft) Mud Wt. (ppg) Funnel Viscosity Yield Point (Ib/1QOftz) API Fluid Loss (ml/30min) Chlorides (mg/I), H 110 -1,600 8.6 - 9.2 250 35 - 45 nc - 6 <600 9.0 - 9.5 1,600 - 2,000 9.2 - 9.5 150 - 200 30 - 35 4 - 6 <600 9.0 - 9.5 Surface Interval Fluid Formulation Product Name Quantit Unit Size MI Gel 20 - 25 b Soda Ash 0.25 b to the makeu water Caustic Soda for Hof 9.5 Pac Su reme 0.25 b or as needed telex as needed for viscosit SCREEN KLEEN 1 - 2% while drillin o tional DrillZone 1 - 2% while drillin o tional Note: Makeup water and water used in the pits while drilling should be as cold. as possible. Location North Slope Alaska Confidential 6 Date: Novemeber 8, 2006 • Rock -Flour #2 Surface Interval Overview Surface to 2,000' MD Lithology through this zone is a composite of small gravel in the upper intervals with a grading downward to sand, clay, and some siltstone in the lower zones of this interval. Based upon work done on previous wells a modified M-I Gel/telex spud mud is recommended for the surface interval. Initial viscosities of 150 - 200 sec/qt should be used through the permafrost, which extends to a depth of 1,600' TVD. Expected pore pressures at the base of this interva! are expected to be at 8.3 - 9.1 ppg EMW. 9.625" surface casing will be set and the cement will be pumped in a single stage to surface to complete this interval. Surface Interval Drilling Concerns: - Large gravel sizes can cause hole-cleaning problems. If larger than normal gravel is encountered be prepared to increase funnel viscosity to 250 sec/qt. Have GELEX available for an immediate response to this issue. - Care should be taken in the event that an unexpected hydrate encounter occurs. If the hydrate issue is deemed to be a major problem, use the following guidelines to help minimize the effect that any hydrates may have to the drilling operation. - Sticky clays in the permafrost and also in the zone below the permafrost can slow ROP from bit and BHA balling. If needed add SCREEN KLEEN (at 1 - 2%) and Nut Plug m (as allowed by MWD tools) to minimize clay to metal sticking. Additions of DrillZone used in conjunction with the SCREEN KLEEN will help with shaker screen. blinding and will also enhance the effect of the SCREEN KLEEN. Consider pretreating the system with the SCREEN KLEEN and DrillZone with 1 % v/v of each. - Swabbing in the clays may also be a problem. Maintain or slightly increase mud weight (.1 ppg) and continue additions of SCREEN KLEEN at 15 to 30 gallons per hour and wiper runs through these intervals may be necessary to clear the wellbore of the problem clays. - To help insure good cement to surface after running the casing, condition mud to a funnel viscosity of +/_ 55 - 65 sec/qt (YP of 12 - 15) prior to cementing the casing. Have SAPP, Desco CF and water on hand to ensure the desired rheologies can be achieved. Use water sparingly to reduce the over all haul-off costs for this well. Location North Slope Alaska Confidential 8 Date: Novemeber 8, 2006 • • ~ - -- Rock-F!©ur#2 Production Drilling Interval -Pilot Hole Drilling Fluid System FLOPRO NT Drill-in Fluid Key Products KCI, FloVis, DualFlo, Greencide, Lubetex, Klagard, CaCOs, Solids Control Shakers, Mud cleaner, Centrifuge, and Magnets Potential Problems Lithologic instability near the wellbore. Torque and drag. Hole cleanin . PRODUCTION INTERVAL MUD PROPERTIES bepth MD (ft) -Mud Wt. (ppg) Plastic Viscosity (cp); Yield Point (11b/100ft2) API Fluid Loss (m1/30min) Chlorides (mg/l) pH 2,000 - 4,600 9.5 ~ 10 22 - 30 4 - 6 28,000 - 31,000 9.0 - 9.5 Production Interval Fluid Formulation (for new 9.5 ppg fluid) Product Name Amount Unit Size Water .790 bbl Biocide 0.2 ppb Duovis .75 -1.25 ppb Dual_FI_o 6 ppb Soda Ash 0.5 ppb KCI @ 13% 20.17 ppb S-200 (CaC03 for bridging) 49.37 . ppb KLAGARD (2%) -Optional 6 ppb Location North Slope Alaska Confidential 10 Date: Novemeber 8, 2006 • • Rock Flour. #2 Production Interval -Pilot Hole Objective The production interval will be drilled to a TD of 4,600' MD. Formation evaluation testing will be performed as per the program and will include sidewall cores, MDT, and E-logs. Production Interval -Pilot Hole Treatment Considerations - Lithology for this interval is expected to be typical of this region consisting of sand and siltstones that are commonly found on West Sak/Schrader Bluff intermediate/production intervals. - Ensure that the fluid properties are maintained to provide the best possible hole conditions. for the testing that will be performed on this interval. Maintain mud weights at 9.4 - 9.5 ppg and ensure that rheology is optimized. Monitor for any fluid losses and flow back closely. - Due to the short interval length, a dilution program to help minimize formation damage will not be needed. Klagard additions will be made to control the drill solids at <5% or an MBT of 5 ppb. It is important to maintain the drill ,solids content below 5% to reduce the possibility of any formation damage or interference with the MDT and sidewall core sampling that is programmed for this interval - Although lubricants are not expected to be needed for this well, No lubricants should be added to this fluid without careful consideration. Lubricants can adversely affect the results of the MDT and sidewall cores. - Fluid deliveries, fluid transfers, and cuttings disposal issues will be tracked on a daily basis. - Record product usage and effectiveness of any sweeps that are pumped. Location North Slope Alaska Confidential 12 Date: Novemeber 8, 2006 • • _- Rock Flour #2 Sidetrack Intermediate Drilling Interval Drilling Fluid System FLOPRO NT Drill-in Fluid Key Products KCI, FloVis, DualFlo, Greencide, Lubetex, Klagard, CaCOs, Solids Control Shakers, Mud cleaner, Centrifuge, and Magnets Potential. Problems. Lithologic instability near the wellbore. Torque and drag. Hole cleanin . SIDETRACK INTERMEDIATE INTERVAL MUD PROPERTIES Depth MD (ft) Mud Wt. (ppg) Plastic Viscosity (cp) Yield Point {Ib/100ftz) API Fluid Loss (rnU30min) Chlorides (mg/1) pH 2,700 - 5,150 9.5 ~ 10 22 - 30 4 - 6 28,000 - 31,000 9.0 - 9.5 Sidetrack Intermediate Interval Fluid Formulation (for new 9.5 ppg FloPro NT fluid) Product Name Amount Unit Size Water .790 bbl Biocide 0.2 ppb Duovis .75 - 1.25 ppb DuA~F~o 6 ppb Soda Ash 0.5 ppb KCI @ 13% 20.17 ppb S-200 (CaC03 for bridging) 49.37 ppb KLAGARD (2%) -Optional 6 ppb Location North Slope Alaska Confidential 16 Date: Novemeber 8, 2006 • • Rock Flour #2 Sidetrack Intermediate Interval Objective The Sidetrack Intermediate interval will be drilled to a TD of 5,150' MD. Testing and evaluation will be done as per the drilling program. A 9.625" casing string will be run to TD after completing this interval. Sidetrack Intermediate Interval Treatment Considerations - Make sure that any cement contamination is treated out of this system prior to drilling ahead. - Lithology for this interval is expected to be typical of this region consisting of. sand .and siltstones that are commonly found on West Sak/Schrader Bluff intermediate/production intervals. - Ensure that the fluid properties are maintained to provide the best possible hole conditions for the testing that will be performed on this interval. Maintain mud weights at 9.4 - 9.5 ppg and ensure that rheology is optimized. Monitor for any fluid losses and flow back closely. - A dilution program to help minimize formation damage will not be needed. - Lubricants are not expected to be needed for this interval. If needed, add lubricants such as Lubetex and/or FLOLuBE as needed up to a concentration of 3% v/v. Ensure that hole cleaning is adequate prior to any lubricant additions are made to the system. Additions of lubricant over this recommendation concentration should be carefully considered. Do nonuse lubricants to mask the affects of hole cleaning or other problems that may be manifesting themselves as torque and drag issues - Fluid deliveries, fluid transfers, and cuttings disposal issues will be tracked on a daily basis. - Record product usage and effectiveness of any sweeps that are pumped Location North Slope Alaska Confidential 18 Date: Novemeber 8, 2006 • ~ Rock' Flour #2 ` Sidetrack Production Drilling Interval Drilling Fluid System VersaPro NT Key Products LVT-200, CaCl2, CaCOs, VersaCoat HF, HRP, VersaWet, Lime,VersaMOD Solids Control Shakers, Mud cleaner, Centrifuge, and Magnets Potential Problems Lithoiogic instability near the wellbore. Torque and drag. Hole cleanin . SIDETRACK PRODUCTION INTERVAL MUD PROPERTIES Depth MD (ft) Mud Wt. (ppg) Plastic Viscosity (cp) Yield Point (Ib/100ft2) API Fluid Loss (ml/30min) Chlor--ides (mg/l) pH 5,150 - 8,573 9.5 '' 15 - 18 19 - 23 4 - 6 28,000 - 31,000 9.0 - 9.5 Sidetrack Production Interval Fluid Formulation (for new 9.5 ppg VersaPro NT fluid) Product Per bbl Quanti Unit Mineral Oil -LVT 200 (.825 SpG) 23 gal IMG 400 4 - 6 Ibs Lime 3.0 Ibs VERSACOAT HF 5.0 Ibs VERSAWET 2.0 Ibs Brine (10.7 ppg CaCl2) 16.5 gal VERSA-MOD 0.5 Ibs VERSA HRP 0.5 Ibs 85 S-200 (or as needed for Ibs correct weight) ~- ~ o ~ r~° ° e Q ~s Location North Slope Alaska Confidential 20 Date: Novemeber 8, 2006 • • - _____~ Rock Flour #2 Sidetrack Production Interval Objective The sidetrack production interval will be drilled to a TD of 8,573' MD ~ A 3.5" liner be run to TD after completing this interval. The well will be completed using an ESP pump to perform the production testing. Sidetrack Production Interval Treatment Considerations - The lithology for this interval is expected to be typical of this region consisting of sand and silty sands that are commonly found on West Sak/Schrader Bluff production intervals. - Ensure that the fluid properties are maintained to provide the best possible hole-conditions for the testing that will be performed on this interval. Maintain mud weights at 9.4 - 9.5 ppg and ensure that rheology is optimized. Monitor for any fluid losses and flow back closely. - A dilution program to help minimize formation damage will not be needed. - Ensure that hole cleaning is adequate while drilling this interval. - Fluid deliveries, fluid transfers, and cuttings disposal issues will be tracked on a daily basis. - Record product usage and effectiveness of any sweeps that are pumped. Location North Slope Alaska Confidential 21 Date: Novemeber 8, 2006 Rig: Nabors 27E Location: Exploration Client: ENI Exploration Revision Date: 12/12/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3(~slb.com < TOC at Surface Previous Csg. < 20", 94.# casing at 100' MD ~~ < Base of Permafrost at 1,800' MD (1,800' ND) < Top of Tail at 1,800' MD < 13 3/8", 68.0# casing in 16" OH TD at 2,000' MD (2,000' TvD> CemCADE~ Preliminary Job Design 13 3/8" Surface Casing, V2 on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 1,800' MD. Lead Slurry Minimum pump time: 235 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (100') x 1.00 (no excess) = 101.9 ft3 0.4206 ft3/ft x (1800' - 100') x 3.50 (250% excess) = 2502.6 ft3 0.4206 ft3/ft x (1800' - 1800') x 1.50 (50% excess) = 0 ft3 101.9 ft3 + 2502.6 ft3+ 0 ft3 = 2604.5 ft3 2604.5 ft3 / 4.45 ft3/sk = 585.3 sks Round up to 590 sks Have 320 sks of additional Lead on location for Top Out stage,. if necessary. Tail Slurrv Minimum pump time: 170 min. (pump time plus 120 min.) ARCTICSET I @ 15.7 ppg - 0.93 ft3/sk 0.4206 ft3/ft x (2000' - 1800') x 1.50 (50% excess) = 126.2 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 67.3 ft3 126.2 ft3 + 67.3 ft3 = 193.5 ft3 193.5 ft3/ 0.93 ft3/sk = 208.1 sks Round up to 210 sks BHST = 35~, Estimated BHCT = 58~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) Water 5.0 1 0.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 Water 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH II 5.0 50.0 10.0 33.0 ASL surf 7.0 463.8 66.3 99.3 AS 1 6.0 34.5 5.7 105.0 Drop top plug 0.0 0.0 5.0 110.0 Mud 8.0 278.5 34.8 144.8 Slow & bump plug 3.0 9.0 3.0 147.8 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, TY < 15. As thin. and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per 2 joints below Permafrost to asist in cement placement Mark of Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Casing, V1 reliminary Job Design based on limited input data. For estlmate purposes onl Rig: Location: Exploration Client: ENI Exploration Revision Date: 11/7/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3@slb.com < TOC at Surface Previous Csg. < 20", 94.# casing at 100' MD 4V, < Base of Permafrost at ;err 1,800' MD (1,800' TV D) Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 50% permafrost. The top of the tail slurry is designed to be at 1,800] Lead Slurry Minimum pump time: 280 min. (pump time pJufs 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk ~ 1.0190 ft3/ft x (100') x 1.00 (no excess) = 101.9 ft3 0.6946 ft3/ft x (1800' - 100') x 3.50 (250% exces = 4132.9 ft3 0.6946 ft3/ft x (1800' - 1800') x 1.50 (50% exc s) = 0 ft3 101.9 ft3 + 4132.9 ft3+ 0 ft3 = 4234.8 ft3 4234.8 ft3 / 4.45 ft3/sk = 951.6 sks Round up to 960 sks Have 510 sks of additional Lead Tail Slurry Minimum pump t ARCTICSET 1 @ 15.7 ppg - below the location for Top Out stage, if necessary. min. (pump time plus 120 min.) 0.6946 ft3/ft x (2000' - 180 0 (5 'excess) = 208.4 ft3 0.8407 ft3/ft x 80' (Shoe oin 67.3 ft3 208.4 ft3 + 67.3 ft3 = - ,^,~ 275.7 ft3 275.7 ft3/ 0.93 ft3/sk ~ ~~'~ 296.5 sks Round up to 300 s .7~ \ BHST = 35`F, F~timated BHCT = 58`F. (BHST calcu ted using a gradient of 2.69=/100 ft. below the permafrost) / Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) < Top of Tail at 1,800' MD < 13 3/8", 68 # casing in 171/ ~t 2,000' MD ,000' TV D) Water 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 Water 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH II 5.0 50.0 10.0 33.0 ASL 7.0 754.3 107.8 140.8 AS1 6.0 49.1 8.2 149.0 Drop top plug 0.0 0.0 5.0 154.0 Mud 8.0 278.5 34.8 188.8 Slow & bump plug 3.0 9.0 3.0 191.8 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, T„ < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.2 ppg MudPUSH" II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per 2 joints below Permafrost to assist in cement placement Mark of Schlumberger • ~ Schlumberger CemCAD E*well cementing recommendation for 13 3/8" Surface Casing Operator : ENI Well Country :USA Field State :Alaska Prepared for : Amjad Chaudhry Location Bill Penrose Proposal No. : V2 -16" OH Service Point Date Prepared. :December 12, 2006 Business Phone FAX No. Prepared by :Mike Martin Phone (907) 263-4207 E-Mail Address martin13@slb.com ~5,~~ ~ Q C ~G~9 / Rock Flour #2 Exploration Prudhoe Bay (907659-2434 (907) 659 -2538 Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than ahsolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wel Is might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the wel I or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger • • Client ENI Well Rock Flour 2 String 13 3/8 Surface District Prudhoe Bay Country USA Loadcase 1338 Surf Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :2000.0 ft BHST : 37 degF Bit Size : 16 in ft o- 0 o- o~ 0 o- o~ 0 ~n o 0 o- CV O O l[7 N UVell Lithology SG~I~m~rg~r Formation Press. 5 Page 2 ENI - Aock Flour 2.c(w ; 12-122006. Loadcase 1338 Surf : Version wcs-cem45_89 (x 1000) psi • • Client ENI ~ I ~~ Well Rock Flour 2 String 133/8 Surface District Prudhoe Bay Country USA Loadcase 1338 Surf Previous String MD OD Weight ID ft in Ib/ft in 100.0 20 94.0 19.124 Landing Collar MD :1920.0 ft Casing/liner Shoe MD :2000.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2000.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter :16.000 in Mean Annular Excess :228.9 Mean OH Equivalent Diameter :20.798 in Total OH Volume :798.3 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 1800.0 16.000 250.0 21.184 2000.0 16.000 50.0 17.163 Max. Deviation Angle : 0 deg Max. DLS :0.000 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.3 0.0 0.000 2000.0 2000.0 0.3 0.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (Ib/gal) (Ib/gal) 1800.0 12.50 8.30 P.Frost 2000.0 12.50 8.50 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 32 0.0 1800.0 1800.0 32 0.0 2000.0 2000.0 37 0.3 Page 3 ENI-Rock Flour2.cfiv;12-12-2006; LoadCase1338Surf;Versionwcs-cem45_09 • • Client ENI Scrl~rg~r Well Rock Flour 2 String 133/8 Surface District Prudhoe Bay Country USA Loadcase 1338 Surf Section 2: centralizer placement Top of centralization :1800.0 ft Bottom Cent. MD :1980.0 ft Casing Shoe :2000.0 ft NB of Cent. Used :3 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 2000.0 3 1/2 S1104613-13 3/8-8-46 3/16" 94.6 1820.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) S1104613-13 3/8-8- 13 3/8 18.752 14.500 No Houma 17.500 490.08 2214.37 46 3/16" (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 4 ENI -Rock Flour 2.ciw ; 12-12-2006: Loadcase 1338 Surf; Version wcs-cem45_89 • Client ENI Well Rock Flour 2 String 133/8 Surface District Prudhoe Bay Country USA Loadcase 1338 Surf Section 3: fluid description - Mud DESIGN Fluid No: 1 Density : 9.50 Ib/gal Job volume :287.5 bbl MUDPUSH II DESIGN Fluid No: 4 Density : 10.20 Ib/gal Job volume :50.0 bbl ASL surf DESIGN Fluid No: 2 Density Rheo. Model : HERSCHEL_B. k At temp. ; 65 degF n Ty Gel Strength DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type :Fresh water SLURRY. Mix Fluid :20.722 gal/sk Yield :4.45 ft3/sk Porosity :62.3 Density :8.321b/gal r~~r 10.70 Ib/gal 5.42E-3 Ibf.s^n/ft2 :0.663 9.56 Ibf/100ft2 (Ibf/100ft2) Job volume :463.8 bbl Quantity :585.84 sk Solid Fraction :37.7 Base Fluid :20.153 gal/sk AS1 DESIGN Fluid No: 5 Density : 15.70 Ib/gal Rheo. Model : HERSCHEL_B. k : 1.35E-3 Ibf.s^n/ft2 At temp. : 65 degF n :1.068 Ty :5.431bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : ArcticSETi Dry Density : 174.56 Ib/ft3 Sack Weight : 80 Ib BASE FLUID Type :Fresh water SLURRY Mix Fluid :3.536 gal/sk Yield :0.93 ft3/sk Porosity :50.8 Density :8.321b/gal Job volume :34.5 bbl Quantity :208.09 sk Solid Fraction :49.2 Base Fluid :3.536 gal/sk Page 5 ENI -Rock Flour 2.cTw; 12-12-206; Loadcase 1338 Surf; Version wcs-cem45_89 • Client ENI ~ ~ r~~r Well Rock Flour 2 String 13 3/8 Surface District Prudhoe Bay Country USA Loadcase 1338 Surf Section 4: fluid sequence Original fluid Mud 9.50 Ib/gal P~ : 20.000 cP Ty :30.00 Ibf/100ft2 Displacement Volume 287.5 bbl Total Volume 875.8 bbl TOC 0.0 ft Fluid.Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al Water 40.0 0.0 8.32 viscosity:1.000 cP MUDPUSH II 50.0 0.0 10.20 k:1.80E-1 Ibf.s^n/ft2 n:0.195 Tv:2.77 Ibf/100ft2 ASL surf 463.8 1800.0 0.0 10.70 k:5.42E-3 Ibf.s^n/ft2 n:0.663 Tv:9.56 Ibf/100ft2 AS1 34.5 200.0 1800.0 15.70 k:1.35E-3lbf.s^n/ft2 n:1.068 Tv:5.43Ibf/100ft2 Mud 287.5 0.0 9.50 P~:20.000 cP Tv:30.00 Ibf/100ft2 Static Security Checks Frac 9 psi at 100.0 ft Pore 12 psi at 100.0 ft Collapse 2051 psi at 1920.0 ft Burst 5020 psi at 0.0 ft Cs .Pum out 48 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments Water 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines Water 5.0 30.0 6.0 40.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 5.0 50.0 10.0 50.0 80 ASL surf 7.0 463.8 66.3 463.8 80 AS1 6.0 34.5 5.7 34.5 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Mud 8.0 278.5 34.8 278.5 80 Mud 3.0 9.0 3.0 287.5 80 Slow & bum lu Total 02:27 875.8 bbl hr:mn Dynamic Security Checks Frac 9 psi at 100.0 ft Pore 0 psi at 100.0 ft Collapse 2051 psi at 1920.0 ft Burst 4841 si at 0.0 ft Page 6 ENI -Rack Flour 2.ciw ; 12-12-2006: Loadcase 1338 Surf; Version wcs-cem45_89 • Client ENI Well Rack Flour 2 String 13 3/8 Surface District Prudhoe Bay Country USA Loadcase 1338 Surf ft o~ O u7 pO O $~ S _. N O u7 N i6 ~Of ~_ N N ~ h y ~ O a c a 0 Sc~lrg~r Ib/gal 8 12 16 --,' -Hydrostatic - Nin. Hydrostatic - Max. Dynamic - - Mn. Dynamic - Frac - Pore ' 0 0 N ~- O a O S c_ N E k ~UUO~ O O N C C - Q O ~---- 0 100 200 Fluid Sequence Dynamic WeIlSecurity Time (min) Depth = 2000 ft _ _ •Frac - a oar - ~ In c ~ o a d `m ~ ~ ~ ~. o LL l O 20 40 60 80 100 120 140 160 Time (min) Fluids at 2000 ft ~~ ___..r_~.___. _~---__ 1 _ - -- 20 40 60 80 100 120 140 160 Time (m in) Page 7 ENI -Rock Flour 2.cfw : 12-12-200fi ; Loadcase 1338 Surf ; Version wcs-cem45_89 O 0 100 200 Time (min) ' • ~ Schlumberger CemCADE Preliminary Job Design 9-518" Intermediate Casin , V3 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nabors 27E Location: Exploration Client: ENI Exploration Revision Date: 12/12/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3@slb.com Previous Csg. < 13 3/8", 68.0# casing at 2,000' MD Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 1000' MD annular length. Lead slurry is calculated to surface Lead Slurry Minimum thickening time: 230 min. (Pump time plus 120 min.) 10.7 ppg ASL - 4.45 ft3/sk 0.3132 ft3/ft x (3740 - 2000') x 1.40 (40% excess) = 762.3 ft3 0.3354 ft3/ft x 2000' x 1.0 (No Excess) = 670.8 ft3 762.3 ft3 + 670.8 ft3 = 1433.1 ft3 1433.1 ft3/ 4.45 ft3/sk = 322.0 sks Round up to 330 sks Tail Slurry Minimum thickening time: 175 min. (Pump time plus 120 min.) 15.8 ppg Class G + 0.4% S1, 0.2%D46, 0.3%D65, 0.4% D167 - 1.16 ft3/sk 0.3132 ft3/ft x 1000' x 1.40 (40% excess) = 438.5 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 438.5 ft3 + 34.1 ft3 = 472.6 ft3 472.6 ft3/ 1.16 ft3/sk = 407.4 sks Round up to 410 sks BHST = 83`F, Estimated BHCT = 72~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time .Cumulative Stage Volume Time. (bpm) (bbl) (min) (min) < Top of Tail at 3,740' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 4,740' MD (3,832' TVD) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100. 5.0 10.0 2.0 14.0 Drop bottom plug 0.0 0.0 5.0 19.0 MUDPUSH II 6.0 40.0 6.7 25.7 ASL 7.0 255.4 36.5 62.2. Tail Slurry 5.0 84.0 16.8 79.0 Drop top plug 0.0 0.0 5.0 84.0 Mud 7.0 332.1 47.4 131.4 Slow & bump plug 3.0 9.0 3.0 134.4 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, T„ < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH'` II, Pv = 19-22, Tv = 22-29 Centralizer Recommendation: • 1 per 2 joints from 1500' - 2060' • 1 per joint from 2060' - 3740' • 3 per 2 joints from 3740' - 4660' • 2 per joint on the shoe track Rig: Location: Exploration Client: Eni Revision Date: 11/15/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3@slb.com Previous Csg. < 13 3/8", 68.0# casing at 2,000' MD < Top of Tail at 4,150' MD < 9 5/8", 47.0# in 12 1/4" OI TD at 150' MD (4, 6' TVD) CemCADE Preliminary Job Design 9-5/8" intermediate Casin , V2 reliminary Job Design based on limited input data. For estimate purposes onl Schlumberger Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 1000' MD Lead slurry is calculated to surface Lead Slurrv Minimum thickening time: 240 min. (Pump time plus 12 'min.) 10.7 ppg ASL - 4.45 ft3/sk 0.3132 ft3/ft x (4150 - 2000') x 1.40 (40% excess) = 942.7 t3 0.3354 ft3/ft x 2000' x 1.0 (No Excess) = 67 ft3 942.7 ft3 + 670.8 ft3 = 1 13.5 ft3 1613.5 ft3/ 4.45 ft3/sk = /362.5 sks Round up to 370 sks Tail Slurrv Minimum thickening time: 200 min. ump time plus 120 min.) 15.8 ppg Class G + 0.4%S1, 0.2%D46, 0.3% 5, 0.4%D167 - 1.16 ft3/sk 0.3132 ft3/ft x 1000' x 1.40 (4 ° xcess) ~ 438.5 ft3 0.4110 ft3/ft x 80' (Shoe Joint ~ 32.9 ft3 438.5 ft3 + 32.9 ft3 = ,i 471.4 ft3 471.4 ft3/ 1.16 ft3/sk = ~~' ~ '~ 406.4 sks Round up to 410 sks ~ ~~ ~~ BHST = 87~, Estimate = 74~. (BHST calculated usid dient of 2,6/100 ft. below the permafrost) PUMP SCHEDU Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) fminl CW 5.0 10.0 2.0 2.0 Pressure st lines 0.0 0.0 10.0 12.0 CW 5.0 10.0 2.0 14.0 Dro bottom plug 0.0 0.0 5.0 19.0 MUDPUSH II 6.0 40.0 6.7 25.7 ASL Lead 7.0 287.4 41.1 66.8 Tail Slurry 5.0 84.0 16.8 83.6 Drop top plug 0.0 0.0 5.0 88.6 Mud 7.0 362.2 51.7 140.3 Slow & bump plug 3.0 9.0 3.0 143.3 lar length. Recommended Mud Properties: 9.5 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. MUD REMOVAL Spacer Properties: 10.2 ppg MudPUSH" II, Pv ^ 19-22, TY ~ 22-29 Centralizer Recommendation: • 1 per 2 joints from 1500' - 2030' • 1 per joint from 2030' - 4030' • 3 per 2 joints from 4030' - 5070' • 2 per joint on the shoe track Schlumberger CemCAD E*well cementing recommendation for 9 5/8" Intermediate Casing Operator : ENI Well Rock Flour #2 Country :USA Field Exploration State :Alaska Prepared for : Amjad Chaudhry Location Bill Penrose Proposal No. : V3 - Change TD Service Point Prudhoe Bay Date Prepared :December 12, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by Phone E-Mail Address Mike Martin (907) 263-4207 martin13@slb.com t~G -" ~~~ATE Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data, The information presented is Schlumberger's best estimate of the actual results that may be achieved and should he used far comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlgmberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are goad for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger • Client ENI Well Rock Flour#2 String 9 5/8 District Prudhoe Bay Country USA Loadcase 9581nt Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD : 474Q.0 ft BHST : 84 degF Bit Size : 12 1/4 in Previous String MD OD Weight ID ft in Ib/ft in 2000.0 13 3/8 68.0 12.415 Landing Collar MD :4660.0 ft Casing/liner Shoe MD :4740.0 ft ~~ f~ t; Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 4740.0 9 5/8 40.0 47.0 8.681 L-80 4760 5980 BTCSH Formation Data MD Frac. Pore Name Lithology ft Ib/ al Ib/ al 4740.0 12.50 9.00 N Sand Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1800.0 1800.0 3 i 0.4 4740.0 3832.0 84 1.5 ENI-Rock Flour2.cfiv;12-12-2006; LoadCase9561nt;Versionwcs-cem45_69 Page 2 Client ENI ~ ~ r~r Well Rock Flour#2 String 9 5/8 District Prudhoe Bay Country USA Loadcase 9581nt Mean OH Diameter :12.250 in Mean Annular Excess :40.0 Mean OH Equivalent Diameter :13.154 in Total OH Volume :460.6 bbl (including excess) Max. Deviation Angle : 80 deg Max. DLS :19.033 deg/100ft MD ft Directional Survey Data TVD Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 2000.0 2000.0 0.0 176.4 0.000 2100.0 2100.0 0.0 176.4 0.000 2200.0 2199.9 3.8 176.4 3.780 2300.0 2299.4 7.6 176.4 3.780 2400.0 2398.0 11.3 176.4 3.780 2500.0 2495.4 15.1 176.4 3.780 2600.0 2591.0 18.9 176.4 3.780 2700.0 2684.5 22.7 176.4 3.780 2800.0 2775.4 26.5 176.4 3.790 2900.0 2863.4 30.3 176.4 3.780 2950.0 2906.1 32.1 176.4 3.780 3150.0 3075.5 32.1 176.4 0.000 3200.0 3117.4 34.0 176.4 3.780 3300.0 3198.3 37.8 176.4 3.800 3400.0 3275.2 41.6 176.4 3.800 3500.0 3347.7 45.4 176.4 3.790 3600.0 3415.5 49.2 176.4 3.800 3700.0 3478.3 53.0 176.4 3.790 3800.0 3535.7 56.8 176.4 3.800 3900.0 3587.7 60.6 176.4 3.800 4000.0 3633.8 64.4 176.4 3.790 4100.0 3674.0 68.2 176.4 3.800 4147.5 3690.9 70.0 176.4 3.793 4347.5 3759.3 70.0 176.4 0.000 4400.0 3772.9 80.0 176.4 19.033 4500.0 3790.3 80.0 176.4 0.000 4600.0 3807.7 80.0 .176.4 0.000 4610.6 3809.5 80.0 176.4 0.000 4740.0 3832.0 80.0 176.4 0.000 Page 3 ENI -Rock Flour 2.cfiv; 12-12-2066; LoadCase 9561nt; Version wcs-cem45_89 • Client ENI Well Rock Flour #2 String 9 5/8 District Prudhoe Bay Country USA Loadcase 9581nt Section 2: centralizer placement Top of centralization :1500.0 ft Bottom Cent. MD :4730.0 ft Casing Shoe :4740.0 ft NB of Cent. Used :87 NB of Floating Cent. :0 • Sc~l~rg~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 2060.0 7 1/2 S1103695-9 5/8-6-36 (3/16") 100.0 2040.0 3740.0 42 1/1 S1103695-9 5/8-6-36 (3/16") 68.3 2180.0 4700.0 36 3/2 S1103695-9 5/8-6-36 (3/16") 81.9 4173.3 4740.0 2 2/1 S1103695-9 5/8-6-36 3/16" 87.8 4740.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) S1103695-9 5/8-6-36 9 5/8 13.626 10.811 No Houma 12.250 629.47 1780.49 3/16") (1) -Centralizer pertormance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 4 ENI -Rock Flour 2.clw ; 12-12-2006 ; Loadcase 958 Int : Version wcs-cem45_89 Client ENI ~ I ~~~ Well Rock Flour #2 String 9 5/8 District Prudhoe Bay Country USA Loadcase 9581nt Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 Ib/gal Job volume :341.1 bbl CW DESIGN. Fluid No: 2 Density : 8.32 Ib/gal Job volume :20.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 10.50 Ib/gal Job volume :40.0 bbl ASL DESIGN Fluid No: 6 Density : 10.70 Ib/gal Rheo. Model : HERSCHEL_B. k : 9.69E-2 Ibf.s^n/ft2 At temp. : 78 degF n :0.356 Ty :1.981bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type :Fresh water SLURRY Mix Fluid :20.722 gal/sk Yield :4.45 ft3/sk Porosity :62.3 Density :8.321b/gal Job volume :255.4 bbl Quantity : 322.52 sk Solid Fraction :37.7 Base Fluid :20.153 gal/sk Tail Slurry DESIGN Fluid No: 4 Density Rheo. Model : HERSCHEL_B. k. At temp. : 80 degF n Ty Gel Strength DESIGN BLEND SLURRY Name : G Mix Fluid :5.090 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 1.16 ft3/sk Sack Weight : 94 Ib Porosity :58.5 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Additives Code Conc. Function D046 0.200 %BWOC ANTIFOAM D065 0.300 %BWOC DISPERSANT D167 0.400 %BWOC FLUID LOSS S002 0.400 %BWOC accelerator 15.80 Ib/gal 1.50E-2 Ibf.s^n/ft2 :0.788 0.24 Ibf/100ft2 (Ibf/100ft2) Job volume :84.0 bbl Quantity :404.95 sk Solid Fraction :41.5 Base Fluid :5.090 gal/sk Page 5 ENI-Rock Flour2.cfw;12-12-2006; LoadCase9561nt;Versionwcs-cem45_89 • Client ENI Well Rock Flour#2 String 9 5/8 District Prudhoe Bay Country USA Loadcase 9581nt N i s~ Section 4: fluid sequence Original fluid Mud 9.50 Ib/gal k : 1.19E-2 Ibf.s^n/ft2 n :0.512 Tv :6.14 Ibf/100ft2 Displacement Volume 341.1 bbl Total Volume 740.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al CW 20.0 0.0 8.32 k:1.26E-31bf.s^n/ft2 n:0.583 Tv:1.41Ibf/100ft2 MUDPUSH II 40.0 0.0 10.50 k:1.80E-1 Ibf.s^n/ft2 n:0.195 Tv:2.77 Ibf/100ft2 ASL 255.4 3740.0 0.0 10.70 k:9.69E-21bf.s^n/ft2 n:0.356 Tv:1.981bf/100ft2 Tail Slurry 84.0 1000.0 3740.0 15.80 k:1.50E-2 Ibf.s^n/ft2 n:0.788 Tv:0.24 Ibf/100ft2 Mud 341.1 0.0 9.50 k:1.19E-21bf.s^n/ft2 n:0.512 Tv:6.141bf/100ft2 Static Securi Checks Frac 187 psi at 2000.0 ft Pore 177 psi at 2000.0 ft Collapse 4253 psi at 4660.0 ft Burst 5980 psi at 0.0 ft Cs .Pum out 65 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments CW 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW 5.0 10.0 2.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 40.0 6.7 40.0 80 ASL 7.0 255.4 36.5 255.4 80 Tail Slurry 5.0 84.0 16.8 84.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Mud 7.0 332.1 47.4 332.1 80 Mud 3.0 9.0 3.0 341.1 80 Total 02:14 740.4 bbl hr:mn Dynamic Securi Checks Frac 17 psi at 4740.0 ft Pore 32 psi at 2000.0 ft Collapse 4253 psi at 4660.0 ft Burst 5387 si at 0.0 ft Page 6 ENI-Rock FlourZciw;t2-12-2006; LoadCase9581nt:Versionwcs-cem45_69 Client ENI SGrIINll~rg~r Well Rock Flour #2 String 9 5/8 District Prudhoe Bay Country USA Loadcase 9581nt Section 6: WELLCLEAN II Simulator ft o- 0 0 o- CY O O O O ~Il Cement Coverage pro Fluids Concentrations z° 1500 ~ ' i500 2000- ?000 2500- ^500 " 3000 - s 1000 " r O o° 3500 - a 3500 0 4000 5000 d500 1500 • ; o • ~ 0 z ~ P~ud ~ MUDPUSH II ~ Tail Slurry ~ CbV O ASL ~0 Risk Mud on the Wall z° ~ 1500 u.® 1500 2000- 2000 2500- ^500 `" 3000 - s X000 " s ~ 0 3500 - 4 3500 n 4000- 1000 4500- 4500 • 3 • o ~ 0 z ~ H igh ~ Low ~ h4edium ~ None Page 7 ENI -Rock Flaur 2.clw ; 12-12-2006 ; Loadcase 958 Int ; Version wcs-cem45_69 • • Client ENI Well Rock Flour#2 String 9 5/8 District Prudhoe Bay Country USA Loadcase 9581nt ft o- O O_ N O O O ~- v ~a m N N y y ~ O a c c Q m Fluid Sequence Ib/g al l 12 1{6 - Hydrostatic - fv5n. Hydrostatic - Nix. Dynamic - Nin. Dynamic - Frac - Pore II Dynamic Well Security Depth = 4740 ft Time (m in) 50 75 Time (m in) O r r-. g rn ~ a >=o > N O 0 v C (V .~ T ~ '~ O C C Q O Schl~r~er 0 100 200 Time (min) 100 125 150 Page 8 ENI -Rock Flour 2.cfw; 12-12-2006: Loadcase 9581nt ;Version wcs-cem45_89 100 200 Time (min) hl S h ~~ ~ ~m c um erger .Rock Flour 2 PB1 (P5) Proposal Report Date: December 12, 2006 Survey 1 DLS Computation. Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 176.450° Field: Structure I Slot: ENI - Rodc Flour Rock Flour 2 /Rock Flour 2 ~ ~ Vertical Section Origin: ~O TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table Well: ~ Rock Flour 2 Ov~ ~ 7VD Reference Elevation: 93.75 ft relative to MSL Borehole: Rock Flour 2 PB1 pppr Sea Bed 1 Ground Level Elevation: 60.50 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 23.746° Survey Name 1 Date: Rock Flour 2 P61 (P5) /January 11, 2007 Total Field Strength: 57623.991 nT Tort 1 AHD 1 DDI 1 ERD ratio: 0.000° 10.00 ft / 0.000 10.000 Magnetic Dip: 80.844° Grid CooMinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: January 11, 2007 Location LatlLong: N 70.28444133, W 149.36988075 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5953995.930 ftUS, E 577861.180 ftUS North Reference: True North Grid Convergence Angle: +0.59318374° Total Corr Mag North -> True North: +23.746° Grid Scale Factor: 0.99990689 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS ~ Gravity DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de 1100 k d 1100 ft d 100 h kUS ftUS Kit U.UU U.UU U.UU -`J3,/J U.UU V.VV V.VV V.VV --- V.VV V.VV V.VV J~VJJJJ.JJ J//OV 1.10 IV /V.LOYYY IJJ VV IY'.JO~OOV/J 100.00 0.00 0.00 6.25 100.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 500.00 0.00 0.00 406.25 500.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 1000.00 0.00 0.00 906.25 1000.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 1500.00 0.00 0.00 1406.25 1500.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93. 577861.18 N 70.28444133 W 149.36988075 13-3/8" Csg Pt 2000.00 0.00 0.00 1906.25 2000.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 2500.00 0.00 0.00 2406.25 2500.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 3000.00 0.00 0.00 2906.25 3000.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 3500.00 0.00 0.00 3406.25 3500.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 4000.00 0.00 0.00 3906.25 4000.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 TD /End 10-5/8" Open 4332.00 0.00 0.00 4238.25 4332.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 5953995.93 577861.18 N 70.28444133 W 149.36988075 Hole Leoal De scription: NAD27 ASP Zone 4 NAD27 UTM Zone 6 Northi ng (Y) [ftUS] Easting (X) [ftUS] Northing (Y) [ftUS] Easting (X) [ftUS] Surface :. 513 FNL 1208 FWL S28 T11N R11E UM 5953995.93 577861.18 25587784.26 1347730.96 BHL : 513 FNL 1208 FWL S28 T11N R11E UM 5953995.93 577861.18 25587784.26 1347730.96 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Rock Flour 2\Rock Flour 2\Rock Flour 2 P81\Rock Flour 2 PB1 (P5) Generated 12/12/2006 10:06 AM Page 1 of 1 - ~i ~~m Schlumherger Rock Flour 2 PB1 (P4) Proposal Report Date: November 13, 2006 Client: ENI Field: Structure 1 Slot: ENI -Rock Flour Rock Flour 2 /Rock Flour 2 Well: ~~~ Rock Flour 2 O Borehole: ~~~r Rock Flour 2 PB1 UWUAPI#: 50029 Survey Name FDate: Rock Flour 2 PB1 (P4) I January 15, 2007 Tort IAHD / DDI 1 ERD ratio: 0.000° / 0.00 ft / 0.000 / 0.000 Grid Coordinate System: NAD27 UTM Zone 06N, US Feet Location LaULong: N 70.28458136, W 149.36987511 Location Grid NIE YIX: N 25587784.264 ftUS, E 1347730.958 ftUS Grid Convergence Angle: -2.23109764° Vertical Section Azimuth: 178.680° lO Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 102.25 ft relative to MSL Sea Bed 1 Ground Level Elevation: 70.00 ft relative to MSL Magnetic Declination: 23.741 ° Total Field Strength: 57624.111 nT Magnetic Dip: 80.845° Declination Date: January 15, 2007 Magnetic Declination Model: BGGM 2006 North Reference: TNe North Total Corr Mag North -> True North: +23.741 ° Comments Measured Inclination Azimuth Subsea TVD 7Vp Vertical NS EW Gravity ` DL Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft % k h d e 100 ft de 1100 ft de 1100 ft ftUS ncco~~on a ftUS r.~ ~n oon ro~oc ~ni inn ocno~un K I C U.UU U.UU U.UU - I VG.GO V.V V V.VLL u.uu V[..V. v.vv ~.vv v.vv aaav~ i ~~.a~ , u~i i a~.av ,. , ... c.,~w , vu .. , ~c...'vou ~ v ~ ~ 100.00 0.00 0.00 -2.25 100.00 0.00 0.00 0. --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 500.00 0.00 0.00 397.75 500.00 0.00 0.00 ~ --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 1000.00 0.00 0.00 897.75 1000.00. 0.00 0.00 - 0 - 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 1500.00 0.00 0.00 1397.75 1500.00 0.00 0.00 0:00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 ~ ~ 2000.00 0.00 0.00 1897.75 2000.00 0.00 /,, `~/ . 0.00 ~ 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 13-3/8" Csg Pt 2032.25 0.00 0.00 1930.00 2032.25 0.00 0.00 0.0~ --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 2500.00 0.00 0.00 2397.75 2500.00 0. 0.0~ 'QO --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 3000.00 0.00 0.00 2897.75 3000.00 .00 0. 0 --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 3500.00 0.00 0.00 3397.75 3500.00 0.00 0.00 0 --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 4000.00 0.00 0.00 3897.75 4 .00 0.00 0.00 0.00 --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.36987511 4500.00 0.00 0.00 4397.75 500.00 0.00 0.00 0.00 --- 0.00 0.00 0.00 25587784.26 1347730.96 N 70.28458136 W 149.369 TD /End 10-5/8" Open 4632.25 - 0.00 0.00 453 4632.25 0.00 0.00 0.00 --- .0.00 0.00 0.00 25587784.26 1347730.96 8 N 70.28458136 W 149.3698 Hole Legal Description: NAD27 ASP Zone 4 NAD27 UTM Zone 6 Northi ng (Y) [ftUS] Easting (X) [ftUS] Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4781 FSL 408 EL S28 T11 N R11 E UM 5954047.18 577861.35 • 25587784.26 1347730.96 BHL : 4781 FSL 8 FEL S28 T11 N R11 E UM 5954047.18 577861.35 25587784.26 1347730.96 WeIlDesign Ver SP 2.1 Bld( doc40x_100 ) Rock Fbur 2\Rock Flour 2\Rock Flour 2 P81\Rock Flour 2 PB1 (P4) Generated 11/20/2006 10:38 AM Page 1 of 1 ~,' ~~~m Rock Flour 2 (P Report Date: December 12, 2006 Client: ENI Field: ENI -Rock Flour Stmcture 1 Slot: Rock Flour 2 /Rock Flour 2 0~~ Borehole: Rock Four 2 ~ APp UWIIAPI#: 50029 Survey Name I Date: Rock Flour 2 (P5) /January 15, 2007 Tort I AHD 1 DDI 1 ERD ratio: 90.000° / 5607.27 ft / 6.055 / 1.455 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.28444133, W 149.36988075 Location Grid NIE YIX: N 5953995.930 ftUS, E 577861.180 ftUS Grid Convergence Angle: +0.59318374° Proposal S~hlumberger Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 176.450° 0 ertical Section Origin: ~ N 0.000 ft, E 0.000 ft 1 ~ TVD Reference Datum: Rotary Table TVD Reference Elevation: 93.75 ft relative to MSL Sea Bed I Ground Level Elevation: 60.50 ft relative to MSL Magnetic Declination: 23.741 ° Total field Strength: 57624.170 nT Magnetic Dip: 80.845° Declination Date: January 15, 2007 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North -> True North: +23.741 ° • Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical NS EW Gravity DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de h ft ft ft ft de d 100 k de 1100 it de 1100 h ftUS kUS KUt'Grv3.8/1UU 'G1UU.UU U.UU 1/6.45 ZUU6.Zb Y1UU.UU u.uu u.uu u.uu na u.uu u.uu u.uu oaa3aaay3 ~//aoi.io rv /U.L84441JJ W 14y.30yb8V/J 2200.00 3.78 176.45 2106.18 2199.93 3.30 -3.29 0.20 HS 3.78 3.78 0.00 5953992.64 577861.42 N 70.28443234 W 149.36987910 2300.00 7.56 176.45 2205.67 2299.42 13.18 -13.15 0.82 HS 3.78 3.78 0.00 5953982.79 577862.13 N 70.28440540 W 149.36987414 2400.00 11.34 176.45 2304.29 2398.04 29.60 -29.54 1.83 HS 3.78 3.78 0.00 5953966.41 577863.32 N 70.28436063 W 149.36986591 2500.00 15.12 176.45 2401.62 2495.37 52.48 -52.38 3.25 HS 3.78 3.78 0.00 5953943.59 577864.98 N 70.28429823 W 149.36985443 2600.00 18.90 176.45 2497.23 2590.98 81.74 -81.58 5.07 HS 3.78 3.78 0.00 5953914.41 577867.09 N 70.28421846 W 149.36983975 2700.00 22.68 176.45 2590.70 2684.45 117.23 -117.01 7.27 HS 3.78 3.78 0.00 5953879.02 577869.66 N 70.28412168 W 149.36982195 2800.00 26.47 176.45 2681.62 2775.37 158.81 -158.51 9.84 HS 3.78 3.78 0.00 5953837.55 577872.66 N 70.28400830 W 149.36980109 2900.00 30.25 176.45 2769.61 2863.36 206.30 -205.90 12.79 HS 3.78 3.78 0.00 5953790.19 577876.10 N 70.28387882 W 149.36977727 End Crv 2950.00 32.14 176.45 2812.38 2906.13 232.19 -231.75 14.39 --- 3.78 3.78 0.00 5953764.37 577877.97 N 70.28380822 W 149.36976429 Crv 3.8/100 3150.00 32.14 176.45 2981.74 3075.49 338.58 -337.93 20.99 HS 0.00 0.00 0.00 5953658.27 577885.66 N 70.28351814 W 149.36971092 3200.00 34.03 176.45 3023.63 3117.38 365.87 -365.17 22.68 HS 3.80 3.80 0.00 5953631.05 577887.64 N 70.28344372 W 149.369697 3300.00 37.83 176.45 3104.58 3198.33 424.54 -423.73 26.32 HS 3.80 3.80 0.00 5953572.54 577891.88 N 70.28328374 W 149.3696 3400.00 41.63 176.45 3181.48 3275.23 488.45 -487.51 30.28 HS 3.80 3.80 0.00 5953508.81 577896.50 N 70.28310949 W 149.3696' 3500.00 45.42 176.45 3253.97 3347.72 557.30 -556.23 34.55 HS 3.80 3.80 0.00 5953440.14 577901.48 N 70.28292175 W 149.36960122 3600.00 49.22 176.45 3321.75 3415.50 630.80 -629.59 39.10 HS 3.80 3.80 0.00 5953366.84 577906.79 N 70.28272133 W 149.36956436 3700.00 53.01 176.45 3384.51 3478.26 708.63 -707.27 43.93 HS 3.80 3.80 0.00 5953289.22 577912.42 N 70.28250912 W 149.36952533 3800.00 56.81 176.45 3441.98 3535.73 790.44 -788.92 49.00 HS 3.80 3.80 0.00 5953207.63 577918.34 N 70.28228605 W 149.36948430 3900.00 60.61 176.45 3493.91 3587.66 875.88 -874.20 54.30 HS 3.80 3.80 0.00 5953122.42 577924.52 N 70.28205309 W 149.36944145 4000.00 64.40 176.45 3540.07 3633.82 964.57 -962.72 59.79 HS 3.80 3.80 0.00 5953033.98 577930.93 N 70.28181126 W 149.36939697 4100.00 68.20 176.45 3580.26 3674.01 1056.12 -1054.09 65.47 HS 3.80 3.80 0.00 5952942.68 577937.55 N 70.28156163 W 149.36935106 End Crv 4147.46 70.00 176.45 3597.19 3690.94 1100.46 -1098.34 68.22 --- 3.80 3.80 .0.00 5952898.46 577940.76 N 70.28144074 W 149.36932883 Crv 3.8/100 4347.46 70.00 176.45 3665.60 3759.35 1288.40 -1285.92 79.87 HS 0.00 0.00 0.00 5952711.03 577954.35 N 70.28092830 W 149.36923459 4400.00 72.00 176.45 3682.70 3776.45 1338.07 -1335.50 82.95 HS 3.80 3.80 0.00 5952661.49 577957.94 N 70.28079285 W 149.36920968 4500.00 75.80 176.45 3710.43 3804.18 1434.13 -1431.37 88.90 HS 3.80 3.80 0.00 5952565.69 577964.88 N 70.28053093 W 149.36916151 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Rock Flour 2\Rock Flour 2\Rock Four 2\Rock Flour 2 (P5) Generated 12/12/2006 10:07 AM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Gravity DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de 1100 ft d 100 ft de 1100 ft ftUS ftUS 4600.00 79.60 176.45 3731.74 3825.49 1531.81 -1528.87 End Crv 4610.62 80.00 176.45 3733.62 3827.37 1542.26 -1539.30 9-5/8" Csg Pt 4612.81 80.00 176.45 3734.00 3827.75 1544.42 -1541.45 Crv 3.8/100 4630.62 80.00 176.45 3737.09 3830.84 1561.96 -1558:96 4700.00 82.64 176.45 3747.56 3841.31 1630.54 -1627.40 4800.00 86.44 176.45 3757.08 3850.83 1730.07 -1726.74 End Crv 4893.78 90.00 176.45 3760.00 3853.75 1823.78 -1820.28 TD / 7" Lnr 8677.26 90.00 176.45 3760.00 3853.75 5607.27 -5596.50 Legal Description: NAD27 ASP Zone 4 Northi ng (Y) [ftUS] Surface : 513 FNL 1208 FWL S28 T11 N R11 E UM 5953995.93 Landing : 2054 FNL 1304 FWL S28 T11 N R11 E UM 5952455.70 BHL : 840 FNL 1526 FWL S33 T11N R11E UM 5948403.86 94.96 HS 3.80 3.80 0.00 5952468.27 577971.95 N 70.28026458 W 149.36911253 95.60 --- 3.80 3.80 0.00 5952457:85 577972.70 N 70.28023608 W 149.36910729 95.74 --- 0.00 0.00 0.00 5952455.70 577972.86 N 70.28023019 W 149.36910621 96.82 HS 0.00 0.00 0.00 5952438.21 577974.13 N 70.28018237 W 149.36909742 101.08 HS 3.80 3.80 0.00 5952369.81 577979.09 N 70.27999538 W 149.36906304 107.24 HS 3.80 3.80 0.00 5952270.56 577986.28 N 70.27972400 W 149.36901316 113.05 --- 3.80 3.80 0.00 5952177.09 577993.05 N 70.27946846 W 149.36896622 347.31 --- 0.00 0.00 0.00 5948403.86 578266.37 N 70.26915206 W 149.36707246 NAD27 UTM Zone 6 Easting (X) [ftUS] Northing (Y) [ftUS] Easting (X) [ftUS] 577861.18 25587733.08 1347728.27 577972.86 578266.37 25582129.02 1347857,39 • WeIlDesign Ver SP 2.1 Bld( doc40x_100) Rock Flour 2\Rock Flour 2\Rock Four 2\Rock Flour 2 (P5) Generated 12/12/2006 10:07 AM Page 2 of 2 Eni petroleum Schlumberger wvELL Rock Flour 2 PB1 / 2 (P5-5) FIELD ENI -Rock Flour 51RDCiuRE Rock Flour 2 Magreuc Parameters Surtace LO[d11on NAD1]Nasla S~aie PMnai. Zone 01 US Feet Mcael BGGM 2006 Bas' Date 0] NIO t ] 3989 Many 5399593 MIS GrA Cam n0.59J18J]a' Sbtep lour 2 ND Rel Hoary lade X93>5 ~ aSme MSL~ May Dec B2J ]at' FS. 5)62a2nip Lon x922115)1 Easing 5)]Bfit tBflUS PNn. Rock Fbur2~P5~ Sivy Dde. JnwrytS. 200] -800 0 800 1600 2400 3200 4000 4800 5600 0 .....> ......................R~~ ... 800 .....:.................................. .... 1600 .....:.................................. .... 0 0 ~ 13318" Csg Pt C_ I I KOP Crv 3.81100 O) v 2400 .....i .................................. .. 3200 .....:.................................. .... 4000 .....:.................................. .... TD f End 10.518" Open Hole 0 800 1600 2400 3200 4000 • • -800 0 800 1600 2400 3200 4000 4800 5600 Vertical Section (ft) Azim = 176.45°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V ~i ~,~,,, Schlumberger WELL Rock Flour 2 P61 / 2 (P5-5) FIELD ENI -Rock Flour STRUC TUft[ Rock Flour 2 Magnele Parameters S~rlace loc ation Fa Stare. Planes. Zone Oa. US Foel D Miscella neous MoD el. BGGM 2Wti Dip 80645 200t ~ 19569]XUS Gnd COev ~059]I6]]a Norinin9 596 96 Sbr IVp ReI ]5flaf'ev~~nt'.'.c, ale (9] Mag Dec. L29.I41 lS 5/fi242nT Lon WIa92] 15]t Easting. 5I166116flUS Srzle Facto 99066tl6] Plan Rock Fbir11P51 Srvy Date J uarY 15.2W] -800 0 800 1600 0 -800 1600 n n n Z -2400 0 0 c d m ~ -3200 v v v -4000 -4800 -5600 0 -800 -1600 -2400 -3200 -4000 -4800 -5600 -800 0 800 16C «< W Scale = 1(in):800(ft) E »> ~ Eni l~troleum Schlumberger WALL Rock Flour 2 P61 / 2 (P5-5) F~ELp ENI -Rock Flour s]Rp~IpRE Rock Flour 2 Ma9petic Parameters SuKace LOCalon NNp2%Naska Stale PMires. Zone 06, U5 Feei a MoJal SGGM 2006 pip. Ua~o nary I5. 200] lal. ]989 NoMiing 595]995931105 63]a- Sime c nor Np Ref. bk 193 ]S habove MSLI Ma9 pec. 823 ]4t- FS 2n1 W14922115I1 Easting 5]]961.161tUS ScalepFac10999906888] r21P51 Srvy pale JRanuary 15. 200] -6000 -4500 -3000 -1500 0 1500 3000 4500 0 0 1500 °0 3000 to C N (0 U ~ 4500 . 13-3I8" Csg Pt 1500 3000 4500 6000 7500 SAK RIV 6 -6000 -4500 -3000 -1500 0 1500 3000 Vertical Section (ft) Azim = 176.45°, Scale = 1(in):1500(ft) Origin = 0 N/-S, 0 E/-V 4500 6000 7500 E E~~ ~trore~~, Schlumberger WLLL Rock Flour 2 PB1 / 2 (P5-5) FIELD ENI -Rock Flour STRUCTURE Rock Flour 2 Pa stma~e Location Rnov ka Slala Planol:. mna o4. us Faac a re ~ o Moael RG GM 2005 Dip y e o t6 200] Lat. 595]995 9] BUS GrlO Conv a0 5931B3i4 0113969 ~in9 shi ROCk Flocr 2 TW Ret Rotary ta61e l9] ]5 Y at+ove MSLI 2]l41 F6 5]6]4x2 nT Map Dac Lon. W1492f 11511 Lasury 511061 t0ItU5 Scale Fact. 09999060661 Plan Rock Flour2 (PS) Srvy Oale January 15. 2UU] -6000 -4500 -3000 -1500 0 1500 6000 4500 3000 n n n Z 1500 0 0 c n °-' 0 U V V V -1500 -3000 -4500 6000 4500 3000 1500 0 -1500 -3000 -4500 -6000 -4500 -3000 -1500 0 1500 c« W Scale = 1(in):1500(ft) E »> • ~ ANTICOLLISION SUMMARY REPORT Client: ENI Slot: Rock Flour 2 Field: ENI -Rock Flour Well: Rock Flour 2 Structure: Rock Flour 2 Borehole: Rock Flour 2 P61 Subject Trajectory: Rock Flour 2 PB1 (P5) (DEF PLN) Rpt Date: December 12, 2006 Analysis Method: Normal Plane Depth Interval: Every 100.OOft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 __ Mag Model: BGGM 2006 Offset Trajectory Sep. Allow Sep. Subject Trajectory Se aration Factor Alert Status Ct-Ct ft Dev. ft Fact. MD ft TVD ft Alert Minor Ma'or 1M-17 (DEF SW) PASS 8780.00 8777.21 44997.76 99.75 99.75 MinPts 3438.33 3389.45 111.13 4325.01 4325.01 MinPts W SAK RIV 6 (DEF SW PASS 5135.07 5132.56 N/ 4.75 4.75 MinPts 5135.07 3802.64 5.79 4304.75 4304.75 MinPts Version DO 4.0 (doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 12/12/2006 8:40 AM Page 1 of 1 • • ANTICOLLISION SUMMARY REPORT ENI -Rock Flour ,. Rock Flour 2 Trajectory: Rock Flour 2 (P5) (DEF PLN) Method: Normal Plane Slot: Rock Flour 2 Well: Rock Flour 2 Borehole: Rock Four 2 Rpt Date: December 12, 2006 Depth Interval: Every 100.OOft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 Offset Trajectory Sep. Allow Sep. Sub'ect Tra'ecto Se aration Factor Alert Status Ct-Ct ft Dev. ft Fact. MD ft TVD ft Alert Minor Ma'or 1 M-17 (DEF SVY) PASS 3095.48 3022.48 65.82 3417.12 3287.96 MinPts 3153.71 3077.02 63.71 3531.76 3369.78 MinPt-O-SF 4116.72 4029.50 72.84 3834.32 3554.19 TD W SAK RIV 6 (DEF SVY) PASS 5135.07 5132.56 N/A 4.75 4.75 Surface 5024.89 3879.70 6.59 4113.28 3678.89 MinPt-CtCt 5179.64 3665.91 5.14 4462.00 3794.40 MinPt-O-ADP 5257.53 3673.77 4.98 4501.95 3804.66 5.00 Enter Alert 5667.93 3881.59 4.7 4600.05 3825.50 MinPt-O-SF 6018.24 4142.71 4.82 4653.34 3834.62 TD Version DO 4.0 (doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 12/12/2006 8:42 AM Page 1 of 1 RE: Rock Flour 2 Question Subject: RE: Rock Flour 2 Question From: Bill Penrose <bill ~r~,fairweathcr.com=- Date: Sun_ CLU Dec 200(1 I ~:iS:j4 -09(10 To: Stephen Da~ic~ ~=str~c da~ieti~~i:admin.~taic.ak:us> Steve, We went through a lot of iterations with the directional well planner so it's not too surprising that some of the locations drifted a little. I'll get with them and get the discrepancies straightened out right away. As for the differing TD's, note that the TD's given on the application form refer to those in the producing lateral, not the vertical pilot hole. There being two holes involved here, we felt you would be most interested in the producing one. The MASP calculations, however, use the pressures from the deepest (i.e. pilot) hole. We probably will set a single long cement plug across all the hydrocarbon intervals, but it'll depend on what we find. We'll submit a request for sundry approval for a well thought-out P&A after logging the well. Thanks and regards, Bill Penrose Vice President / Drilling Manager Fairweather E&P Services, Inc. 2000 E. 88th Avenue, Suite 200 Anchorage, Alaska 99507 907-258-3446 -----Original Message----- From: Stephen Davies [ma.:i'.to:steve davi.es~ad°;;.in.stat.e.ak.~~s Sent: Thursday, November 30, 2006 5:06 PM To: Bill Penrose Subject: Rock Flour 2 Question Bill, While reviewing the permit to drill application of Rock Flour 2, I noticed that the coordinates of the well (surface, top productive interval and TD) measured from governmental section lines on the form and the air photo are different from those presented in the proposed directional survey plan that was approved 11/20/2006 by 20' or so. Could you please check and confirm these locations for me? It's minor, but important to ensure accuracy of the Commission's database. Also, the TD and TVD of the well on the permit to drill form and the wellbore schematic differ from the TD and TVD values presented in the Drilling Procedure by about 100 - 150'. Could you also check these? Just curious about the wellbore schematic: What is the basal depth of the OA sand? Why leave a 100' mud-filled gap between the two cement plugs instead of just placing one continuous plug? (Wouldn't that be easier/cheaper?) Thanks, Steve Davies AOGCC 793-1224 1 of 1 12/4/2006 12:12 PM • FAIRWEATHER EXPL;~RATION & PRODUCTION-SERWCES INC. GENERAL ACCOUNT • FIRST NATIONAL BANK A L A S K A 89-&1252 16382 2000 EAST 88TH AVENUE, SUITE 200 pq~ AMOUNT ANCHORAGE, AK 99507-3804 ` PH. (907) 258-3446 11/29/2006 5100.00 PAY One Hundred Dollars and 00 Cents a _ m g m ' TO THE STATE OF ALASKA - A06CC m LL ORDER 333 WEST 7TH AVE SUITE 100 z OF v ~, p ANCHORAGE AK 99501 USA ~ ar ii'0 L_6 38 2'u' is 1 2 5 200060: 0 L L 2 8 2 3 011^ • ~ w~ii ~ ~:~>« _ ~'wc> r Z- K r' PT®# 20 (Q ^ /~~v ®evelopment Service ~EYpflorato~~ Stratigraphic Test ~`on-Conventiona! ~"e!! Circle Appropriate Letter /Paragraphs to be Incfluded in Transmittal Letter CI-[ECK ADD-ONS WHAT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER ~titULTI LATERAL The permit is for a new weClbore segment of existing well (If last two digiis in ,Permit No. .API No. ~0- 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 A.AC 25.00~(f), all records, data and logs 'acquired for the pilot hole must be clearly differentiated in both =~ wetl name ([~pE,,,(~, ~'~pLGt-r 2 PH) and API number (~0-~~-~,3~~ ~" -~~) from records. data and logs ;acquired for well --~a~1e ~C"/p~~,. Z SPACP_VG '' The permit is approved subject to full compliance with 20 AAC EXCEPTION 2~.0>j. Approval to perforate and produce % iJect 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 D[TCH ~~ SAMPLE ;, Non-Conventional I will AI[ 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. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed ', for (name of well) until after (Com~anv Name) has designed and implemented a water well testing program to provide baseline data ' on water quality and quantity. SCom a~nv Name) must contact the Commission to obtain advance approval of such water well testing Rev: t 25:06 C jody`trarsmittal checklist • • o~ o .: ~ ~ , m N. N~ f0~ C. ~ ~ ~ ~ ~ ~ 4 C ~ c i' a ~ ~ N •~ a ~ o ~~ , 3 o w ~ ~ o ~r c ~ 4 C , m ~ ~ ~ ~ 3~ a v' c O ~~ ~ ~ ~ (~~ s• p~ C• p. ~., rn ._ ~ ~ N ~ ~ a ~~ u~ I N' N, ~ I ~, ~, a' a Q ~, ~ o 3 o ~ o. r to ~ ~ ~ ~ i a ~ ' ~ oo , i o ~, . ~~ ~ 'p ai ° ~ E, ~~ ~' , .n ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~' N y~ O. ~~ f0. -~~ N• O ~ ~ ~ ~ C• ~ ~ W~ ~ ~ ~ ~ O~ ~. 7. ~~ O O~ ~ y L O. f6 ~ N ' f0, a, ~ . 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