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202-010
• • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ( � DATE: August 29, 2008 P. I. Supervisor FROM: Chuck Scheve SUBJECT: Location Clearance Petroleum Inspector Altamura #1 Anadarko PTD 2020100 - Friday, August 29, 2008: I performed a Location Clearance Inspection of Anadarko's exploratory well Altamura #1. I was accompanied on today's inspection by Gerald Nayakic (North Slope Borough). This exploratory location was clean with no evidence of past drilling activity other than a slight discoloration of the pad and access road. The cellar area was mounded nicely to prevent ponding and had been reseeded. I recommend the final location clearance be approved for this location. Attachments: none SCANNED AUG 0 8 2017, 2008-0829_Location_Clear_Altamura-l_cs.docx Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ::¿ 0 ~ - 0 L QWell History File Identifier Organizing (d()II"~) RESCAN 0 Two-Sided III II 11111111111111 0 Rescan Needed III II 1111111 1111111 0 Color items: DIGITAL DATA /. Diskettes, No.1 ~" 'Other, N,Orrype ;L . ,,~ ~ plwkcrT;j OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 Grayscale items: 0 0 Poor Quality Originals: 0 OVERSIZED (Non-Scannable) Other: NOT~~ ~ . ~~ ~ SC6G(.,t. Logs of various kinds Other Scanning Preparation ~ Vl1P I, 111111111"'" ""I DATlÓ, ¿:}If °/f' vuf x 30 = :;( 4:-0 + 1 L{-~ = TOTAL PAGES a 8-(D . V\W DATE: '0 ~6lpsl ~ BY: Project Proofing BY: i BEVERLY ROBIN VINCENT SHERY@,NOY BY: BEVERLY ROBIN VINCENT SHERY~WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: - YES - NO Isl Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY , GRAYSCALE OR COLOR IMAGES) II 111111111111 " III ReScanned (ìlUflvi<iu;)II,)JfP~ (::;p0ciaf MtonfiolJj .fi.cðlJniltfJ l:ompfüí.0d) 111111 """1111111 RESCANNED Br: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is/ General Notes or Comments about this file: Quality Checked (dOI (d 111111111" 11111111 1211 O/02Rev3NOTScanned. wpd Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 27, 2009 10:46 AM To: Regg, James B (DOA) Subject: FW: 2008 Site Inspections Attachments: NSB Altamura 1 Site Cleanup Ltr 2008.doc; Photo Documentation.pdf; Field Summary.docx Jim, 0 4 — 0 ∎ 0 Here are some items regarding the site inspection at Altamura #1 last year. Nothing is in the file regarding Chuck's inspection. 1 will check the read file and if I find something there I will copy and place in the file. I will place Amber's note and the documents in the file. Tom From: Amber Babcock [ mailto :amber.babcock @fairweather.com] Sent: Thursday, August 27, 2009 9:42 AM To: Maunder, Thomas E (DOA) Cc: Bill Penrose Subject: RE: 2008 Site Inspections Good morning Tom, Bill Penrose forwarded me your request regarding a site inspection on the Altumara #1 well. This site was inspected, on August 29, 2008. Chuck Scheve of the AOGCC inspected the site location. I am attaching the field summary, photo documentation and Anadarko's letter to the AOGCC (I do not have a signed version, sorry). Please let me know if you require any further documentation. Thank you, Amber Babcock Amber Babcock Logistics Supervisor Fairweather E & P Services, Inc. ' F}. a 2000 E. 88th Avenue, Suite 200 ,. tf Anchorage, AK 99507 Office: 907 - 258 -3446 Cell: 907 - 602 -0304 From: Maunder, Thomas E (DOA) Sent: Thursday, August 27, 2009 8:09 AM To: 'Bill Penrose' Subject: 2008 Site Inspections Bill, I was reviewing some files, Altimura #1 was one and the most recent information in the file is about from a year ago. It is an 8/22/08 email from Amber regarding the delay in some joint site inspections for Brooks Range and Anadarko. I expect the site inspections were accomplished, however I don't find anything in the file. Can you help me here? Thanks much. Tom Maunder, PE AOGCC 8/28/2009 ANADARKO PETROLEUM CORPORATION • • MAIN 907/273 -6300 3201 C STREET. STUITE 603 •ANCHORAGE, ALASKA 99503 Anadorftot Petroleum Corporation September 12, 2008 Mr. Lon Kelly Arctic Field Manager Bureau of Land Management Arctic Field Office 1150 University Avenue Fairbanks, Alaska 99709 -3844 Ref: FF093476 2884.01 (023) Dear Mr. Kelly: Anadarko Petroleum Corporation has completed its summer clean-up work at the Altamura #1 site. The excavated area surrounding the wellhead was revegetated with fertilizer and seed. Seed cultivar was selected in accordance with the Alaska Department of Natural Resources, Division of Agriculture Revegetation Manual for Alaska and is noted below. Seed 40% Arctared red fescue (Festuca rubra) 30% Tundra glaucous bluegrass (Poa glauca) 30% Alyeska polargrass (Arctagrostis latifolia) The pad area and accompanying right of way was cleared of all debris. For your records please find the attached field activity summary and photo documentation. In accordance with "The Final Programmatic Biological Opinion for the Bureau of Land Management Summer Activities in 2008 in Undeveloped Areas of the National Petroleum Reserve - Alaska ", Anadarko is hereby submitting the required Air Traffic Tracking form as an additional attachment. A Microsoft Excel spreadsheet with landing locations will be provided via email to your office as required in the same BO. Sincerely, B.K. Bowen cc: Jesse Mohrbacher - Fairweather • E & P SERVICES. INC. Anadarko Petroleum Corporation Altamura #1 Summer Clean -Up Work Field Activity Summary August 28, 2008 The Altamura #1 site was accessed by helicopter with two personnel. A vehicle was staged at DS2L pad with two additional personnel (due to weight restriction on helicopter) that were later transported to the site via helicopter. The clean-up crew picked up debris on and around the pad area. The excavated area surrounding the wellhead was raked with landscaping tools. Using a broadcast seeder approximately 10 pounds of fertilizer was applied to the area and raked into the soil approximately two inches deep. Using a broadcast seeder approximately two pounds of seed was applied to the area and lightly raked into the soil one inch deep. Seed is expected to lie dormant and vegetate in the spring. August 29, 2008 The site was accessed again by helicopter and two personnel. The helicopter tracked along the ice road right -of -way using GPS coordinates and visual reference. The clean- up crew made 12 landings to retrieve delineators and miscellaneous other debris along the route. The clean-up crew returned to Deadhorse. A site inspection via helicopter was performed by the Gerald Nayakik of the North Slope Bureau and Chuck Scheve of the Alaska Oil and Gas Conservation Commission. Mr. Scheve has agreed to submit data to the State of Alaska Department of Natural Resources. Personnel from the Bureau of Land Management were unable to attend the inspection. Donna Wixon of the BLM notified Fairweather that she will coordinate a site inspection in spring 2009 under regularly scheduled BLM field activities. 2000 East 88 Avenue, Suite 200 • Anchorage, Alaska 99507 • (907) 258 -3446 • Fax (907) 279 -5740 Altamura #1 — Summer Clean -up Work Photo 1: Pad and right -of -way road looking north prior to revegetation and site clean -up activities. Photo 2: Raking excavated area surrounding wellhead Altamura #1 — Summer Clean -up Work r Photos 3 and 4: Fertilizing and seeding excavated area surrounding wellhead A oviir IIII • Altamura #1— Summer Clean -up Work p� r ,w w, Photos 5: Aerial photo of revegetated area surrounding wellhead z , 4k � ' +swag"' ;" j: ^ H Photos 6: Aer photo of revegetated area surrounding wellhead Page 1 of 2 ~ ~ Maunder, Thomas E (DOA) From: Amber Babcock [amber.babcock@fairweather.com] Sent: Friday, August 22, 2008 10:39 AM To: Maunder, Thomas E(DOA); Weaver, Aaron A(DNR); Schultz, Gary (DNR); gordon.brower@north- slope.org; Lynch, Leon C(DNR); Schmitz, Steven (DNR); Waska Williams; Byrne, Laurence C (DNR); Cnsp, John H(DOA); Scheve, Charles M(DOA); Regg, James B(DOA); Donna_Wixon@ak.blm.gov; Easton, John R (DNR) Cc: Weissert, Robin; Jim Winegarner Subject: RE: Brooks Range 8~ Anadarko - Joint Site Inspections ~~ ~ ~ ~ Good afternoan all, ,,~~ ~~~~,,~~ ~. a N o~~ Due to weather and scheduling of helicopter use it is likely that agency inspections of Tofkat, North Shore and Attamura may be pushed back one day. We are working diligently to keep on track for Aug. 28th; however we would like to make sure that your personnel are available on Aug. Z9th in the event that the inspection is delayed by one day. Ptease confirm your (or your designees) availability on Aug. 29th I have the following people scheduled: ~}5.~ _ ~ i,~~.3,i~"~nn. r~.(~ _ ~~.)li_~ NSB - Gerald Nayakik, Cell: (907) 878-2293 DNR-JohnEaston,Cell: need AOGCC - Chuck Scheve, Pgr: (907) 659-3607 (pending confirmation) BLM - Donna Wixon; Iridium 011-8816-414-31120 - may not be able to attend Thank you, ~Amber From: Amber Babcock Sent: Wednesday, August 13, 2008 4:41 PM To: (tom.maunder@alaska.govj; Aaron Weaver (aaron_weaver@dnr.state.ak.us); Donna Nixon (dwixon@blm.gov); Gary Schultr (gary_schultr@dnr.state.ak.us); gordon.brower@north-slope.org; Leon Lynch {teon_lynch@dnr.state.ak.us); Steve Schmitr (ss@dnr.state.ak.us); 'Waska Williams' Cc: 'Weissert, Robin'; Jim Winegarner Subject: Brooks Range & Anadarko - Joint Site Inspec;tions Good afternoon all, Fairweather E& P Services, Inc. will be coordinating site clean-up, agency visits and other activities at various locations throughout the North Slope on behatf of Brooks Range Petroleum Corporation (BRPC) and Anadarko Petroleum Corporatipn. • Brooks Range Petroleum Corporation - Toflcat and North Shore Drilling Exploration Sites • Anadarko Petroleum Corporation - Altamura P&A Site We would like to invite an inspector from your agency to visits all three sites on August 28, 20Q8 departing from Deadhorse. The attached document provides site locations and details of the planned activities for your review. Please respond at yaur convenience, with the requested information in the attached document to assist with 8/13/2049 • ~~ f & PS~/i11CE5 ?t'C u Site Cleanup 8~ Agency Visits fo r: Petroleum Corporation 8 Anadarko Petroleum Corporation (Altamura P & A Site) Fairweather E& P Services, Inc. will be coordinating site clean-up, agency visits and other activities at various locations on the North Slope on behalf of Brooks Range Petroleum Corporation (BRPC) and Anadarko Petroleum Corporation in late August 2008. BRPC and Fairweather have contracted with Air Logistics to provide air transportation in a Bell 206L helicopter (maximum of six passenger seats, however weight and balance restrictions may limit the payload). The helicopter is contracted from August 26~h through August 30~n • Fairweather will conduct all clean-up activities at Anadarko's Altamura plug and abandonment site. • Fairweather is coordinating with and will assist BRPC as requested for clean-up activities at their Tofkat and North Shore drilling exploration sites. Primarily this will consist of scheduling agency visits and coordinating helicopter fiight operations as needed. Following is a general summary of the intended project activities; and therefore is subject to change as ~ necessary to complete the project objectives. ~~` ~~; S~\~~~~~~~~~,~C`v ~C ~ Altamura Pluq & Abandonment Site (Anadarko) ~ a-~ ~'~ Altamura is located approximately 20 nm S/SW of the village of Nuiqsut. Anadarko utilized the -~- ConocoPhillips annual Alpine ice road (which accessed their Rendezvous #2 well location) as the origination point for the Altamura #1 ice road. Anadarko built a six mile spur from the ConocoPhillips ice road and a 275 by 275 foot ice pad to support their well plugging and abandoning operations. Tofkat is locate oximately'h mile east of the Colville river. Road access to the ' was provided by a half mile ice spur roa was connected to ConocoPhillips annual ce road. Both the pad area and spur road will be cleane ected. North Shore Exploratorv Drillinq Site The North Shore ic ~cation is north of S-Pad in the Prudhoe Bay field. Ac the North Shore ice pad w vided by a six-mile-long ice road that connected just south of S-Pad. Bot d area pur road will be cleaned and inspected. 2000 East 88`~' Avenue, Suite 200 • Ancl~orage, Alaska 99507 •(907) 258-3446 • Fax (907) 279-5740 • Aqencv Insqections The following table outlines the agency inspections required for each site. NSB AOGCC DNR BLM Altamura X X N/A X Tofkat X X X N/A North Shore X X X N/A ~ We anticipate inspecting all three locations on August 28, 2008 over two separate flights pending weather and clean-up activities. The routing and attendees for each flight are listed below: Site Visit Flight #1: Deadhorse - Tofkat - Altamura - Deadhorse Attendees # of Ins ectors/re s North Slo e Borou h 1 Division of Natural Resources'` 1 Alaska Oil & Gas Conservation Commission 1 Bureau of Land Mana ement*' 1 Fairweather E& P Services, Inc. 1 Tota I 'DNR inspection required for Tofkat "*BLM inspection required for Altamura Site Visit Flight #2: Deadhorse - North Shore - Deadhorse Attendees # of Ins ectors/re s North Slo e Borou h 1 Division of Natural Resources 1 Alaska Oil & Gas Conservation Commission 1 Fairweather E& P Services, Inc. 1 Total Helicopter Fliqht Documentation 4 Flight records shall indicate the location (latitude and longitude in decimal degree form) of all landings. The date and time of all landings and takeoffs shall be included on the attached Air Traffic Tracking form and submitted to the Fairweather representative on a daily basis. On some days an overlap may take place wherein the helicopter is performing work for both Fairweather and BRPC, in that event the daily rate and flight charges will be prorated per notations on the daily flight tickets. The Fainnreather representative will coordinate with the captain to document the flight tickets. Actions Needed From Aqencies and Contractors Fairweather is requesting that agencies and contractors provide the foilowing information: 1. Name of inspector/personnel assigned to the project 2. Contact information (cellular phone, pager, email) 3. Specify if assistance is needed to coordinate transportation to/from Deadhorse 4. Itinerary of personnel and lodging location - to coordinate arrival/departure times 5. Any additional instructions or special requirements . • Fairweather Representative For questions, comments and logistics of the project please contact: Amber Babcock Logistics Coordinator Fairweather E& P Services, Inc. Tel: 907-258-3446 X328 Cell: 907-440-4280 amber.babcock c(r~.fairweather.com Attachments The following attachments are included for reference 1. Sectional Aeronautical Chart Excerpt indicating approximate locations 2. Altamura Ice Road and Pad As Built Map 3. Altamura Ice Road and Pad LaULon Coordinates (corresponds with map) 4. North Shore Location Map 5. North Shore Ice Road and Pad As Built 6. Tofkat Location Map 1 7. Tofkat Location Map 2 8. Tofkat As Built 9. Air Traffic Tracking Log Sheet 10. Contact List ;`: •~ ti- ~~ ~ oo.w. r 6t ~ ~ ~ k~'r ' `,' ~'~ } 1~ c~ < ``f'aa j ' . • :: ~1 fr,~l-~~~- ~' ''~ ,.I '~ ~~ ,', ~ ~, t~Tl;'~ 9.~Gyq ~}l~ 4,~~ 'I c,~ ~, ~ ~ ~ _ , . ~~ i . . ~ ' ~ '. i : .. .. ~ ``~ ~, 'o ~.,Lr ; ,~ ; ~_, , . .~ u ia: - s , ~'. 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Q~ Q ; _ o0o Y ~~J In < N ', ~~~ LLl H G aaa ~n I ~ b~~ Y z z ~ Q ~ a II ~ ~- '~ G a a ~N ~ H ~ J ~ a Q~ N O I Q Q~U~ I Qm Q ~ ~QO N o O ~ m ~ ~ Ui ~ Q cV 6~ O ~ ~ ~n d W Q X i : K ~ ~ u n a~v ¢ U W ~ ~ Q mwima O~ N N ~ Q Q ~~ _V a •~ci o 0 m 84[Z I aNZO J Q d W ~ ~N~o~ ~n~ ~ / ~ ~ CJ ~ w , ~° ! . ~ ~~' ~, ~.'~~~\- ~ ~mc~~~ ~ ~~ ~ ~ O ~ ~Q ..~~; a~zo~ ~ a~aUOw a~ ~ o Q N H ~ \ a ~wa \\~ ~ I >o ~ <' ~~' w ~~ ~ ' ' ~.~.~~. n ~ ~mzv'~ ~ ~. ~a. N t~ V aa~ ~ ~ °3 a ~ ~~. ~ 0~ y O r ~ ~i ~ \'.~ ~ W~ U N W Z awa =o H ~ p~m~r-~ ~ ~NM1 V ~ ~IN _ . . -- --.._-._._._ _ _ ___ _._ ~ ~ ~ _ ~ ~.a ~~ 0 N w ~ ao~ ~~ . aZ~., ~~ . a' ~3 3~ _ .._. ._ _:._._._,_ _.. i._. _ . _ _ _. _ ____ _. .._. _ ALTAMURA #1 EXPLORATION SITE 2008 P&A ICE ROAD LOCATION MILE Lat. (D.dd Lon . D.dd) Lat. Dms Lon . Dms Lat. DM.dd Lon . DM.dd Desc. 0 70.2566268N 151.075899gW 70s15'23.85"N 151g04'33.23"W 70~15.3975'N 151e04.5539'W CL ICE ROAD 2 70.252960aN 151.158025BW 70re15'10.65"N 151~09'28.89"W 70m15.1776'N 151m09.4815'W CL ICE ROAD 4 70.246188oN 151.240895~W 70ta14'46.27"N 151014'27.22"W 70m14.7713'N 151014.4537'W CL ICE ROAD 6 70.241467taN 151.323962r~W 70ra14'29.25"N 151r~19'26.26"W 70g14.4880'N 151019.4377'W CL ICE ROAD 8 70.239196oN 151.409042mW 70m14'21.10"N 151~24'32.55"W 70g14.3517'N 151a24.5425'W CL ICE ROAD 10 70.234063raN 151.492415~W 70m14'02.63"N 151g29'32.69"W 70014.0438'N 151029.5449'W CL ICE ROAD 12 70.224502raN 151.556702pW 70g13'28.21"N 151033'24.12"W 70g13.4701'N 151033.4021'W CL ICE ROAD 14 70.206073~N 151.626929r~W 70m12'21.86"N 151~37'36.94"W 70p12.3644'N 151e37.6157'W CL ICE ROAD 16 70.197261~N 151.7Q6273eW 70oi f'50.14"N 151042'22.58"W 70011.8356'N 151ra42.3763'W CL ICE ROAD 18 70.170787aN 151.718029eW 70a10'14.83"N 151m43'04.90"W 70ra10.2472'N 151p43.0817'W CL ICE ROAD 20 70.146914aN 151.743084r~W 70ra08'48.89"N 151~a44'35.10"W 70e08.8148'N 151m44.5850'W CL ICE ROAD 22 70.118677~N 151.734927oW 70m07'07.23"N 151~44'05.73"W 70m07.1206'N 151fa44.0956'W CL ICE ROAD 23.3 70.1000810N 151.731959mW 70e06'00.29"N 151ra43'55.05"W 70g06.0048'N 151a43.9175'W CL ICE ROAD Notes: 1. Datum is WGS84\NAD83 2. Date of Survey: April, 18, 2008 3. Ref. Field Book: MI08-02, Page 22. 4. Mile markers refer to drawing FRB08 AMIR 01-02 ~ ~ Z:1000\Altamura\2008\M1080222 Alta Mira Ice Road Lat-Long.xis BY: CSS 07/21/08 1 of 1 ANADARKO PETROLEUM CORPORATION • 5 6P .~~. Bm.&'. SAY ~ ~ ~~o~ ~~1aS1fc~ l)fif ?z ~~35 tr0i4a i. tFi1'!Cf1lSfiti~ ,~ nr~tn~~Q May 16, 2008 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report Anadarko Petroleum Corporation: Altamura #1 PTD #202-010 / P&A Sundry # 308-078 Dear Mr. Seamount, • MAIN 907/273-6300 3201 C STREET. STUITE 603 •ANCHORAGE, ALASKA 99503 ~nadarl~~ Petroleum Corporation ~~NEE3 JUN ~ ~ Z00~ Anadarko Petroleum Corporation hereby submits its Well Completion Report for the work performed in plugging and abandoning its Altamura #1 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 Log 2) Wellbore Schematic 3) Well Operations Summary (Field Progress Reports) 4) Chronological Photo Documentation 5) Tubing puncher log, cement tag up depth 6) Pressure Test Charts 7) Cement Pumping Charts If you have any questions or require additional information, please contact me at (907) 273-6302 or Jesse Mohrbacher at (907) 258-3446. Sincerely, ANADARKO PETROLEUM CORPORATION ~~ . ~~ W.C. Rowe Drilling Operations Manager Anadarko Petroleum Corporation enclosures cc: Jesse Mohrbacher -Fairweather STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas^ Plugged Q Abandoned ~ Suspended ^ ` 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 1b. Well Class: Development ^ Exploratory Q Service ^ Stratigraphic Test^ 2. Operator Name: Anadarko Petroleum Company 5. Date Comp., Susp., or Aband.• 4/17/2008 ' 12. Permit to Drill Number: 202-010 ' 3. Address: 3201 C Street, Suite 603 Anchorage, AK 99503 6. Date Spudded: 3/10/2002 13. API Number: 50-103-20403-00 . 4a. Location of Well (Governmental Section): Surface: 331' FSL, 2258' FWL, Sec 30, T9N, R2E UM 7. Date TD Reached: 4/2/2002 ~ 14. Well Name and Number: Altamura No 1 ' Top of Productive Horizon: 150' FNL, 2423' FWL, Sec 31, T9N, R2E, UM 8. KB (ft above MSL): 154' Ground (ft MSL): 29' 15. Field/Pool(s): Total Depth: 150' FNL, 2423' FWL, Sec 31, T9N, R2E, UM 9. Plug Back Depth(MD+TVD): Surface Exploratory 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 284420.3• y- 5888899.91 • Zone- 4 10. Total Depth (MD + TVD): • 9100 MD / 9014 TVD ' 16. Property Designation: AA-081736 NPRA TPI: x- 284582.41 y- 5888367.51 Zone- 4 Total Depth: x- 284589.26 y- 5888368.15 Zone- 4 11. SSSV Depth (MD + TVD): 1,539' MD / 1,539' TVD 17. Land Use Permit: N/A BLM Land 18. Directional Survey: Yes No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 649 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Tubing puncher record, cement top tag up. 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD TOP BOTTOM SETTING DEPTH TVD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65 H-40 Surface 150' Surface 150' 20" Cement to surface None 9/58" 40 L-80 Surface 2,750' Surface 2,750' 12.25" 1,846' to surface None 7" 26 L-80 Surface 8,501 Surface 8,415' 8.5" TOC at 7,050' None 4-1/2" 12.6 L-80 8,308 9,096 8,401' 9,010' 6.125" 8,308' - 9,096' None 23. Open to production or injection? Yes ^ No ^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1 /2" 8,308 8,308' 2-7/8" 8,43T 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8,557' - 8,655' 9.0 bbl 15.8 ppg Class G 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: ~ •~ Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~~- yv7 ~6~+d•~+~c~Z r a.r. r , SSIax. -Yh,e- ~ Zv02- , VER $Z$•D$ G d~. Form 10-407 Revised 2/2007 CONTINUED ON REVERSE ~= ~~ (~ 1 2QQQ ~ S' 2~ ~ ~~~~ • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base 649 649 T/ Nanushuk 2,854 2,854 T/ HRZ 7,566 7,480 B/ HRZ 7,719 7,633 T/Jurassic 8,554 8,468 ~~~ -7"~S {~/ h J-4 Unconformity 8,656 8,570 e ~ZS•O~ 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: W. C. Rowe Title: Drilling Operations Manager Signature: l~V. ~ rl ow f Phone: (907) 273-6302 Date: ,~Mi4 Y o8 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • Altamura No. 1 Well Schematic Final Abandonment Condition 24" x 24" x'/." marker plate installed on well casings 4' below tundra level ~. s ,~ 20" Hole ~ r~, ; ` ~ , 16", 65ppf, H-40 @ 150' Cmt to surf 3 %:" tubing stub at 210' BGL , ~ %< SS control line for injection sub and SCSSV control and injection lines cut at 210' BGL 3.5" TRM-4E SCSSV 3HSS-1247 2.81 X-nip @ 1539' (open) B/ Permafrost @ 649' , _ ' ~ - { ! w Camco 3.5"x1" KBUG-MW/DM.BK-5 Mandrel @ 2640' '' 1 . t ~ ~~ ~ '.~ Y Nova Injection sub @ 2,729' 12-1/4" HOIe 9-%1', 40ppf, L-80, BTC @ 2,746' Cmt to surf .~ ~~ - CMT w/329 sx 10.7 ppg (lead) + 327 sx 15.9 ppg (tail) 3 Y2 tubing perforated at ~ " ~~ 2,984' to 2,988' with 4 sfp Kick-off point @ 3000' (Max dev = 24 deg, DLS = 4.5 deg/100 ft) Hold angle @ 23 deg, 3550-4100 Drop angle at 4100' Vertical @ 4850' Inhibited 9.8 ppg KCI-NaGI Brine 3'/:, 9.3 ppf, EUE 8rd-mod, L-80 tubing TOC @ 7050' (USIT log) Camco 3.5" x 1" KBUG-MW/EKED D., BEK Side Pocket Mandrel @ 7965' ,F Wireline tagged TOC in 3.5" tubing @ 8,022' BST Pressure Gauge Mandrels @ 8,144', 8,054' Camco 2.813-2.750 XN profile nipple @ 8,223' c/w PXN 8-1 /2" Hole , s Baker G-36 seal assembly Promore Surface Read Out Pressure Gauges @ 8,256' ,` Baker 7x4'/z Lnr Hngr c/w ZXP Packer and 10' PBR @ 8,308' X-over, 2 7/8" tbg (2 jts + 3 pups), flow sub @ 8401, and REG @ 8437' Cement plug in 4 %" casing from 8650' to 8300' 7", 26ppf, L-80, BTC-mod @ 8,501' - cmt w/ 52.3 bbl 13.0 ppg (lead) + 34.7 bbl 15.8 ppg (tail) USIT shows very poor Perfs (6 JSPF with 2-1/2" scallop gun w/11g HMX millennium charges) cmt bond - 8572-75) 8557 - 8575' Stim sleeves (8560-66 Behind the 4'/:" liner , ' Stim Sleeves (8594-8606, 8616-28, 8638-50) 8590 - 8655 PBTD after dropping guns = 8777' Dropped TCP pert gun (gun assembly 218 ft + 10 foot bar 6-1/8" Hole 4-1/2", 12.60ppf, L-80, IBT-mod, Liner 8308-9096' PBT D = 9010' MD Cmt w/ 30 bbl 12.0 ppg cemcrete TD = 9 100' MD, 9014' TVD ~' C] FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: Work Period: 0600-0600 hrs Report Date: Wednesday Apri12, 2008 Work Date: March 30-April 1, 2008 Activity Report: Pioneered into lake MO 151 and set water house on lake. Begin water withdrawals from MO 151 and making road back to Rendezvous 2 location. Making chip ice with limited progress due to warm temperatures. Mobilizing camp to takeoff point near Rendezvous. Spills, incidents, near losses? None Personnel on-site: Fairweather (1), Peak (6) Next Planned Activity: Build ice road from Rendezvous 2 to water sources and Altamura #1. Plan to ramp up crew from 6 to 12 tomorrow. Weather @ 0600 hrs April 2, 2008: 19 F, 4 kts SE, mostly cloudy Submitted By: Ben Shafsky Fairweather E&P Services, Inc. ~ ~,I~;~HiF{FHA • FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 2 Work Period: 0600-0600 hrs Report Date: Wednesday Apri13, 2008 Work Date: March 30-April 1, 2008 Activity Report: Completed 1 mile of ice road from Rendezvous 2 toward Altamura #1. Equipment onsite includes 1 water buffalo, 1 blade, 2 loaders, 2 end dumps, 1 A40 articulating dump truck. Utilizing the substantial snow cover for construction of road and water from MO 151 lake. Spills, incidents, near losses? None Personnel on-site: Fairweather (1), Peak (18) Next Planned Activity: Continue to build ice road from Rendezvous 2 to Altamura #1. Hoping for 2 miles complete by tomorrow AM. Weather @ 0600 hrs Apri13, 2008: 7 F, 3 kts SW, clear Submitted By: Ben Shafsky Fairweather E&P Services, Inc. rII'.,Il~'~ • • r. FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: Work Period: 0600-0600 hrs Report Date: Wednesday April 4, 2008 Work Date: Apri13, 2008 Activity Report: Complete with 2.5 miles ice road to Altamura #1 with 0.2 miles pioneered ahead. Using chips, snow and freshwater to construct road. Currently estimating Apri19-10 completion date for ice facilities. Spills, incidents, near losses? None Personnel on-site: Fairweather (1), Peak (25) Next Planned Activity: Continue to build ice road from Rendezvous 2 to Altamura #1. Weather @ 0600 hrs Apri13, 2008: 7 F, 3 kts SW, clear Submitted By: Ben Shafsky Fairweather E&P Services, Inc. "~ .1 ~' ~ c~~ , FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 4 Work Period: Report Date: Saturday April 5, 2008 Work Date: 0600-0600 hrs Apri14, 2008 Activity Report: Complete with 3.5 miles ice road to Altamura #1 and 0.3 miles pioneered ahead. Using chips, snow and freshwater to construct road. Currently estimating Apri18-9 completion date for ice facilities. Spills, incidents, near losses? None Personnel on-site: Fairweather (1), Peak (23) Next Planned Activity: Continue to build ice road from Rendezvous 2 to Altamura #1. Weather @ 0600 hrs Apri13, 2008: 19 F, 9 kts E, Ovcst Submitted By: Ben Shafsky Fairweather E&P Services, Inc. i b: i E i,. I FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 5 Work Period: Report Date: Sunday Apri16, 2008 Work Date: 0600-0600 hrs Apri15, 2008 Activity Report: Complete with 4.5 miles ice road to Altamura #1 and pioneered to wellhead. Using chips, snow and freshwater to construct road. Pad construction to start tomorrow morning. Currently estimating April 7-8 completion date for ice facilities. Spills, incidents, near losses? None Personnel on-site: Fairweather (1), Peak (23) Next Planned Activity: Continue to build ice road from Rendezvous 2 to Altamura #1. Weather @ 0600 hrs: 9 F, 14 kts SW, partly cloudy Submitted By: Ben Shafsky Fairweather E&P Services, Inc. • ~~~ ~ a ~. FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 6 Work Period: Report Date: Monday April 7, 2008 Work Date: • 0600-0600 hrs Apri16, 2008 Activity Report: Complete with S.lmiles ice road to Altamura #1 and 200' x 200' ice pad at well location. Spills, incidents, near losses? None Personnel on-site: Fairweather (1), Peak (9) Next Planned Activity: Continue to lay down freshwater on ice road. Mobilize equipment and P&A personnel to well location. Weather @ 0600 hrs: 9 F, 8 kts W, mostly cloudy Submitted By: Ben Shafsky On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 7 Work Period: Report Date: Tuesday April 8, 2008 Work Date: 0600-0600 hrs Apri17, 2008 Activity Report: Mobilizing P&A equipment and personnel to the Altamura #1 location. Spills, incidents, near losses? None Personnel on-site: Fairweather (1), Peak (3) Next Planned Activity: Maintain ice road. Mobilize equipment and P&A personnel to well location. Weather @ 0600 hrs: 9 F, calm, partly cloudy, 2" snow overnight. Submitted By: Ben Shafsky On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax rfi.~ • • E~~I~I~~I~~~, FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: Work Period: 0600-2200 hrs Report Date: Wednesday April 9, 2008 Work Date: Apri18, 2008 Activity Report: Mobilized tool conexes, heaters, triplex pump, 100 bbl open top tank, hose and pipe baskets to wellsite. Erected scaffolding around well, winterized same and applied heat to well. SDFN. Spills, incidents, near losses? None Personnel on-site: Fairweather (6), Peak (3), Cruz (2) Next Planned Activity: Maintain ice road, set camp on pad, service wellhead, pull VR plugs and tubing hanger check valve. Pressure test 7" casing and 3.5" tubing. Weather @ 0600 hrs: -15 F, 5 kts NE, clear to partly cloudy Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax ~~ ~ ~ ~.. 4 ~ <; >- r FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 9 Work Period: Report Date: Wednesday April 10, 2008 Work Date: 0600-2200 hrs Apri19, 2008 Activity Report: Mobilized additional equipment to well site including boom truck, wellhead service equipment and camp. Serviced wellhead with FMC hand. Pulled tubing check valve from hanger, found 900 psi on tubing with diesel to surface. Pulled VR plugs on annulus wing valves and found 1100 psi with gas at surface in 9-5/8" x 7" casing annulus and 0 psi on 7" x 3.5" annulus. Spills, incidents, near losses? None Personnel on-site: Fairweather (7), Peak (3), Cruz (2), BJS (1) Next Planned Activity: Maintain ice road, pressure test 7" casing and 3.5" tubing, bleed off gas from 9-5/8"x7" annulus until diesel at surface and check for recharge, perform diagnostics as necessary, prepare for slickline to pull PXN plug. Weather @ 0600 hrs: -15 F, 3 kts S, clear Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax ~f~IPI~ER(N~~ Report #: FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project 10 Work Period: 0600-0600 hrs Report Date: April 11, 2008 Work Date: April 10, 2008 Activity Report: Tested 7" x 3.5" annulus to 3000 psi. Pressure fe1160 psi in 30 minutes. Bled annulus to 1250 psi. Pressure tested 3.5" tubing to 5000 psi for 30 minutes, bled tubing to 0 psi. Chart recorded both tests. Unable to safely bleed gas off 9-5/8" x 7" annulus due to inconsistent swirling winds on location. Pressured up on SSSV and opened same. Rigged up slickline and made two runs to pull PXN plug from tubing. RIH with third run to pull plug. Spills, incidents, near losses? None Personnel on-site: Fairweather (5), Peak (3), Cruz (2), BJS (1) Next Planned Activity: Pull PXN plug, test infectivity of perforations, bleed off 9-5/8" x 7" annulus. Weather @ 0600 hrs: -24 F, 6 kts S, ice fog Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax plp.~lE • FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 11 revised Work Period: 0600-0600 hrs Report Date: April 12, 2008 Work Date: April 11, 2008 Activity Report: RIH with third slickline run to pull PXN plug. Retrieved plug, found 625 psi on tubing. Rig down slickline unit. Rigged up to inject down tubing. Pumped 19 bbls diesel total, perforations began taking fluid at 2250 psi. Established infection rate of 3 bbl ner minute at 2350 psi. Bled 9-5/8" x 7" annulus with strong blow for 50 minutes. Pressure dropped from 1150 to approximately 1100 psi and built back up to 1150 ..psi when shut in. Unable to bleed off annulus with existing equipment and gas handling capability. Injected 80 bbl 9 ppg NaCI brine down 9-5/8" x 7" annulus. Tried to bleed off annulus, got back mud, water and gas mix. Shut in annulus. Annulus pressure reduced to 700 psi after shut in. Spills, incidents, near losses? None Personnel on-site: Fairweather (5), Peak (2), Cruz (2), BJS (1), BLM (1) Next Planned Activity: Bullhead annulus with 2 x annulus volume of brine to attempt to kill annulus. Squeeze perforations with class G cement. Weather @ 0600 hrs: -18F, 4 kts S, partly cloudy Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax r~C th~~~~~J~~~Q Report #: FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project • 12 Work Period: 0600-0600 hrs Report Date: April 13, 2008 Work Date: April 12, 2008 Activity Report: Rig up Schlumberger cementers and vac trucks for squeeze job. Pump 100 bb19. brine followed b 3 bbl water. Dro wi er lu Pum 9 bbl 15.8 Class G cement. Displaced cement with 5 bbl water followed by 66 bb19.8 ppg brine. Final shut in pressure after squeeze job was 475 psi. Rigged up to pump down 9-5/8" x 7" annulus. Shut in pressure on 9-5/8"x 7" annulus rose to 1000 psi by the end of cement job. Called out hot oil truck and pump 275 bbl, 70 degree F water at 2 bpm followed by 125 bbl 9.4 ppg NaCI brine pumped at 4 bpm. Shut in annulus at 700 psi, rig down, SDFN. Spills, incidents, near losses? None Personnel on-site: Fairweather (6), Peak (2), Cruz (2), BJS (2), BLM (1) Next Planned Activity: WOC and monitor 9-5/8" x 7" annulus, adjust P&A plan as necessary. Weather @ 0600 hrs: -6F, 3kts N, overcast Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax ~~ ~. FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 13 Work Period: 0600-0600 hrs Report Date: April 14, 2008 Work Date: April 13, 2008 Activity Report: WOC. Cleanup tools and serviced equipment. Donna Wixon and Mike Woreley of BLM stopped by to visit location. Bled 9-5/8" x 7" annulus from 500 psi to 350 psi, annulus liquid packed with 9.4 ppg brine. Developed alternative P&A option to deal with pressure on annulus of bullheading cement down to annulus shoe and perfing tubing at 3000' and circulating cement back to near surface. Discussed alternate plan with Tom Maunder of AOGCC and Fred McDougal. Awaiting confirmation of plan with Tom Maunder. Tested perforation squeeze plug to 2300 psi after 24 hours CIP. Test OK. By 10:00 PM, 9-5/8" x 7" annulus had dropped to 300 psi and 250 psi by 0600 hrs. Spills, incidents, near losses? None Personnel on-site: Fairweather (5), Peak (2), Cruz (2), BJS (2), BLM (1) Next Planned Activity: Perforate tubing, cement 9-5/8"x7" annulus, cement 3.5" tubing and tubing/casing annulus. Weather @ 0600 hrs: -IOF, Skts E, high overcast Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax ~ .~ ~~. FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 14 Work Period: Report Date: April 15, 2008 Work Date: ~~ 0600-0600 hrs April 14, 2008 Activity Report: Rig up Schlumberger E-line. RIH and tag cement plug per BLM request at 8022' with sinker bar and collar locater. Correlate TOC to jewelry in well. POOH. RIH with tubing punch and perforate tubing ..2984' to 2988' with 4 spf. Tubing went on vacuum and well equalized with diesel in 3.5" x 7" annulus bled to open top tank. POOH with E-line and rig down same. Rig up cementers. Pump 72 bbl Arctic Set Lite 10.7 ppg cement down 9-5/8" x 7" annulus at 2.5 bpm followed by 14 bbl Arctic Set I. Circulating pump in cementing unit blew a seal resulting in difficulty mixing cement and having to pump the last 14 bbls by batching. The first 6 bbl Arctic Set I slurry was at 11 to 13 ppg with the last 8 bbls batched to 15~ ppg. Unable to complete remainder of job due to equipment failure, shut down, cleanup lines and rig down cementers. Spills, incidents, near losses? None Personnel on-site: Fairweather (5), Peak (2), Cruz (2), BJS (2), BLM (1) Next Planned Activity: Cement 3.5" tubing and tubing/casing annulus, cut tubing, pull tubing from well. Weather @ 0600 hrs: OF, 15-20 kts W, snow, overcast Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax i~~i'~.lllhnl,t,4~. Report #: FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project 15 Work Period: 0600-0600 hrs Report Date: April 16, 2008 Work Date: April 15, 2008 Activity Report: Ready tanks and equipment for 3.5" x 7" annulus and 3.5" tubing cement job. Rig up cementers to pump down 3.5" tubing and up 3.5" x 7" annulus taking returns to open top tank. Mixed 9 bbls 9 ppg NaCI brine. Pumped 4.5 bbls brine and pressure test lines to 3000 psi. Pumped remaining 4.5 bbls brine followed by 1 bbl fresh water and 96.5 bbls of 10.7 ppg Arctic Set Lite permafrost cement. Displaced cement with 2.5 bb19 ppg NaCI brine. CIP @ 2115 hrs. Well was on vacuum for most of pumping job. Maximum pumping pressure was 288 psi at 1.3 bpm at end of job. Cement balanced on com letion with a calculated TOC of 238' RKB in both the tubing and annulus. Clean up and rig down cementers. Rig up Schlumberger E-line and jet cut tubing at 238'. Cut tubing 10' above collar to give best chance of severing control and injection lines. Control line pressure on SSSV went to 0 psi after cut. Reversed out annulus and tubing with air, got ,back brine and 1 bbl cement. Pulled tree and backed out hanger lock down screws. Made up lifting sub into hanger and pulled tubing hanger to verify tubing cut. Released Schlumberger E-Line. cementers stayed in camp due to road conditions. SDFN. Added 2 Peak maintenance personnel and blower to equipment spread for maintenance of road from 4 corners to Altamura. Spills, incidents, near losses? Steiger blew hydraulic hose, approximately 12 ounces discharged to drifted snow on pad. Cleaned up oily snow and bagged same for disposal. Personnel on-site: Fairweather (6), Peak (4), Cruz (2), BJS (2), BLM (1), SLB(3) Next Planned Activity: Pull tubing from well, dig out and cutoff well, perform top job on 7" casing, weld on marker plate, backfill excavation. Begin demobilizing equipment and personnel. Weather @ 0600 hrs: Blowing snow all day, winds decreased overnight, current 15 kts SW, -9F, light snow, overcast Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax ~' • .3 r ~,~ FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: Report Date: April 17, 2008 Work Date: Activity Report: Rigged down wellhead shelter. Pulled 218 ` of 3.5"tubing from well and layed down same. Final cutoff de th of tubin is 210` below round level. Control lines cut with tubing. Shoved excess downhole pressure gauge line back on top of tubing stub and anchored the line with 10' of 3.5" tubing. Excavated cellar area around well to 6' below original tundra level. Rigged up Wachs saw and cut well off 4' below tundra level. Batch mixed 70 sx 15.5 ppg permafrost cement at the surface and poured same down 7" casing. Topped off 16" x 9-5/8" annulus. SDFN. Spills, incidents, near losses? None Personnel on-site: Fairweather (5), Peak (4), Cruz (2), BJS (2), BLM (1), SLB(3), Marsh Creek (1) Next Planned Activity: Weld on marker plate, backfill cellar area, demobilize personnel and equipment. Weather @ 0600 hrs: Clear, -24F, 4 kts S Submitted By: Mike Flynn 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax 16 Work Period: 0600-0600 hrs April 16, 2008 On-Site Phones: 907-448-3085 office i Report #: FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project • 17 Work Period: 0600-0600 hrs Report Date: April 18, 2008 Work Date: April 17, 2008 - Activity Report: Welded marker plate on 16" casing. Backfilled excavation. Demobilized 10 truckloads of equipment. Pulled delineators from Altamura #1 section of road, south of Rendezvous 2. Spills, incidents, near losses? None Personnel on-site: Fairweather (4), Peak (4), Cruz (2), BLM (1), Marsh Creek (2) Next Planned Activity: Demobilize 12 more truckloads of equipment, as-built survey pad and road, cut stream crossings at Altamura section of road and Ublutuoch Creek. Notify CPAI that we are gone. Weather @ 0600 hrs: -2F, 7 kts S, partly cloudy Submitted By: Mike Flynn On-Site Phones: 907-448-3085 office 907-448-1755 camp Fairweather E&P Services, Inc. 907-448-1755 fax ~ . • ~~I~i!'~~J~~~ Report #: FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project 18 Work Period: 0600-0600 hrs Report Date: April 19, 2008 Work Date: April 18, 2008 Activity Report: Demobilized 10 truckloads of equipment and as-built survey pad and road. Pulled delineators from CPAI section of road. On-site contact phone # is now 907-244-4857. Spills, incidents, near losses? None Personnel on-site: Fairweather (2), Peak (?), Cruz (2), Marsh Creek (2) Next Planned Activity: Demobilize 2 more truckloads of equipment, cut unnamed stream crossing on Altamura section of road and Ublutuoch Creek. Notify CPAI that we are gone. Weather @ 0600 hrs: 22F, 9 kts S, partly cloudy Submitted By: Mike Flynn On-Site Phones: ~-448-388 office nn~ ~ ~ Q , ~cc camp Fairweather E&P Services, Inc. nn~ AA4 ,~cc fax ~~IP'!i~P N~-' Report #: Report Date: • FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project 19 Work Period: 0600-0600 hrs Apri120, 2008 Work Date: April 19, 2008 Activity Report: Demobilized remaining two loads of equipment. Cut unnamed stream crossing on Altamura section of road. Began cutting Ublutuoch Creek crossing. On-site contact phone # is now 907-244-4857. Spills, incidents, near losses? None Personnel on-site: Fairweather (2), Peak (?), Marsh Creek (2) Next Planned Activity: Demobilize 2 more truckloads of equipment, cut crossing on Ublutuoch Creek. Notify CPAI that we are gone. Weather @ 0600 hrs: IOF, 8 kts W, clear Submitted By: Mike Flynn On-Site Phones: office nn~ AAQ »cc camp Fairweather E&P Services, Inc. nn~ AA4 , ~cc fax fi • • ~~I~!.!i~~~H FIELD PROGRESS REPORT Anadarko Petroleum Corp. Altamura #1 P&A Project Report #: 20 Work Period: 0600-2000 hrs Report Date: Apri121, 2008 Work Date: Apri120, 2008 Activity Report: Completed cutting Ublutuoch Creek crossing. Left a channel in the ice bridge that was at least 75'W x 35'L x 10'D. Photo documented crossing cut. Piled up ice on east side of cut to block access. Blocked access to Rendevous and Altamura at 4 corners with snow berm. This will be the final field report. Spills, incidents, near losses? None Personnel on-site: Fairweather (2), Peak (?), Marsh Creek (2) Next Planned Activity: Notify CPAI that we are gone. Weather @ 0600 hrs: 9F, 11 kts ENE, partly cloudy Submitted By: Mike Flynn On-Site Phones: nn~ ~~Q znQC office nn~ AA4 ,~cc camp Fairweather E&P Services, Inc. nn~ AA4 , ~cc fax • Anadarko • Altamura #1 Plug &Abandonment Photo Documentation ... ;, y Photo 2: Pulled 3.5" tubing plug from XN profile nipple. Photo 1: Wellhead shelter • • ~~~ Photo 4: Cement equipment and vac trucks staged for cement squeeze job. Pagc 2 of 5 Photo 3: Preparation for cement squeeze job. Photo 6: Excavation of Cellar. • Pagc 3 of 5 Photo 5: Wireline operations in progress. ~: `~ .. ~ ~`i ~~ ~• + ~ ~ ,~~~ ~ 4 & '#~ ~' f* ~ ~~~ ~*a"~, d " ~ ~ •~ , }s ~~i is ~~~~~ °:~ -}-. ~L ~qr ~ ~ ~' _,W ,- ~, ,+ ` r `'.. ` Y ~~ ~ .. ~; t f;i ,, ,:,~ t _ , ,,,e . ,_ ~~~ l f ~ f 1 , w W. Photo 8: Cement to surface in all casings. Pagc 4 of 5 Photo 7: Cutting casing strings with Wachs saw. ~,.," >' .,, t ^ \ If ~d ;~~' ?~ • ~~ R .. ° '-` ' ~~ . ~ 4 ~ yy i }uy yy ~ ~p "~ *Y~ ' n r ~ r , ~ ' +j~~ ~ ~, ~~ n .:;~ i ~ , . ;~ iI ' ~ x ~ ~ --y~ ;,rti '~ ~.1' ,^ ~ crr~ r Photo 9: Marker plate installed. ,arc ,~~.~, ~',~ ~ ~,' ,, ~. ~ :~, '~ AAA Y ` ~~r . S x ~ t r t,, ~, S' ~~ ,+ ~,'~ ~" ~ar ~ ~ :_. ~~ ~ ~. ~^ w . q ~'..y.~ x .; v,.. ~ --. ~/~ - E, "~ f ~, a ~} ' . L R4 J~f ~<~• .~.'~-: `fir. - `~ ~,. +~ >.~, _ 1~~~' . 'r~„ _~ ~~ ~Q ~ ~ ~~~/ ~o r- ~ 23 i~.~~y~~ Pagc 5 of 5 ~ ~ BJ Services JobMaster Program Version 3.10 . Job Number: Customer: Fairweather E&P Well Name: Altamura #1 Pressure Integrity Test of 3.5" tubing. Altamura #1 Tubing Test 10 6000 18 Pressure Test Tubing Bleed off ., ~ 15 4000 ~~ i vl C. - --- +- -------------- - -------- - ~ ------------- Q. ~. ~ ~ ~ ~'' ~ 5 d ~ ~ c ~ ~ ~ pC y L ~ K ~ N LL f a, a ~, u_ 2000 - ~' 5 0 0 0 0 20 40 60 Elapsed Time (min) BJ Services Job Start: Thursday, April 10, 2008 ~ , BJ Services JobMaster Program . Job Number: Customer: Fairweather E&P Well Name: Altumura #1 Version 3.10 Pressure Integrity Test of 7" x 3.5" annulus. Altamura #1 Casing Test 10 5000 15 i ~I i i i Test Lines 4000 Pressure Test Casing Bleed Off 3000 10 - -__--_ --- ------- . ~ ~ '~ ~ Q . Q. ~ r ,~, •~ 5 ~ N ~ ~ ~ ~ N C N LL d K t a a LL 2000 5 1000 0 0 0 0 20 40 60 Elapsed Time (min) BJ Services . • Job Start: Thursday, April 10, 2008 ~ ~ BJ Services JobMaster Program Version 3.10 . Job Number: 1001304235 Customer: Fairweather E&P Well Name: Altamura #1 Injection test into perforations. Altamura #1 Injection Test 5 5500 14 4 4000 10 2350 PSI --- 3.2 BPM 3 .~ - ~ . . Q N C. a ~,, ~ ~ ' ... ~ ~ 2.4 BPM ~ y -- OC N N 0 N LL a a ~ 1 BPM 2 I 2000 5 j ~ ------- - ---- i i I 1 ~ 0 0 0 0 20 40 60 Elapsed Time (min) BJ Services Job Start: Friday, April 11, 2008 ~ , BJ Services JobMaster Program Version 3.10 . Job Number: 1001304235 customer: Fairweather E&P Pressure Integrity Test # 1 of Perforated Interval Squeeze Job. Well Name: Altamura #1 Altamura #1 Cement Squeeze Test 6 3000 2000 4 .-. C. Q N d d ~ 3 ~ y tlf N LL d i + a ~'i 1000 2 0 0 0 10 20 30 40 Elapsed Time (min) BJ Services Job Start: Sunday, April 13, 2008 ~ ~ BJ Services JobMaster Program Version 3.10 Job Number: 1001304235 Customer: Fairweather E&P Well Name: Altamura #1 Pressure Integrity Test #2 of Perforated Interval Squeeze Job. Altamura #1 Cement Squeeze Test #2 6 3000 2000 4 a .~ ~_ N d d ~ 7 ~ N N N ~ ~ L + a LL iooo 2 0 0 0 10 20 30 40 ' Elapsed Time (min) BJ Services Job Start: Sunday, April 13, 2008 Schlumberger ~ementing .lob Repo CemCATvl.( " Cement squeeze fob on perforations down 3.5 tubing Well ALTAMURA # 1 Client Anadarko Field NPRA SIR No. 2201082360 Engineer Bill Wilson )ob Type P A -Squeeze Country United States ]ob Date 04-12-2008 Time o, 2200fl1 , Pressure ~~ Rate Density Messages 16:15:57 '~, SAFETY mEETING @ 16:00 i '~, Prime pump's 16:36:00 I Stall Pump's Check Trip's j Start Pumping Water 16:56:00 ~~ re tighten head I ~ I End Water 17:16:00 17:36:00 17:56:00 18:16:00 18:36:00 18:56:00 19:16:00 retighten head again Pressure Test Lines Reset Total, Vol = 3.86 bbl ~, start 9.8 brine j Reset Total, Vol = 0.01 bbl Increase Pump Rate end 9.8 brine Start Pumping Water Reset Total, Vol = 101.84 bbl End Water Drop Top Plug Reset Total, Vol = 3.29 bbl plug didn't go End Water Reset Total. Vol = 2.79 bbl start hatching cement I wait on more water batch up 15.8 cement ~. Start Cement Slurry Reset Total, Vol = 0.03 bbl 19:36:00 End Cement Slurry ', Reset Total, Vol = 9.61 bbl '., i Start Pumping Water I~l i End Water start 9.8 brine i 2000 psi on annulus 19:56:00 ' plug landed in tubing tail cement @ perfs end brine and displacement master closed i 20:18:39 End Job . ~ Stopped Acquisition hh:mmas o,aa iaoo zoos 300o aaao soaa o.oo z.o a o ao e.o m o s.o io o is o zo.o zs o o.~«aoaa:o.~e.39 -PSI B/M - - LB/G Customer: adarko n District: ~dhoe-bay Sch~oroberge~ Representative: Mike Flynn DS Supervisor: Bill Wilson Job Date: 04-12-2008 Well: ALTAMURA # 1 Time Density CMT STG VOL CMT TREAT PRES mm:dd:yyyy:hh:mm:ss Ib/gal bbl psi 04:12:2008:16:15:57 0.02 04:12:2008:16:16:21 PJSM @ 16:00 04:12:2008:16:16:22 0.02 04:12:2008:16:16:27 0.02 04:12:2008:16:16:57 Prime pumps 04:12:2008:16:16:57 0.02 04:12:2008:16:43:14 Stall Pumps Check Trips 04:12:2008:16:43:14 8.39 04:12:2008:16:43:32 Start Pumping Water 04:12:2008:16:43:32 8.40 04:12:2008:16:43:44 8.40 04:12:2008:16:44:14 8.39 04:12:2008:16:44:44 8.39 04:12:2008:16:45:14 8.39 04:12:2008:16:45:44 8.39 04:12:2008:16:46:14 8.39 04:12:2008:16:46:44 8.39 04:12:2008:16:47:14 8.39 04:12:2008:16:47:44 8.39 04:12:2008:16:48:14 8.39 04:12:2008:16:48:44 8.22 04:12:2008:16:49:14 8.32 04:12:2008:16:50:14 8.33 04:12:2008:16:51:14 8.35 04:12:2008:16:51:44 8.33 04:12:2008:16:52:14 8.32 04:12:2008:16:52:44 8.33 04:12:2008:16:53:14 8.34 04:12:2008:16:53:44 8.39 04:12:2008:16:54:14 8.39 04:12:2008:16:54:44 8.39 04:12:2008:16:55:14 8.39 04:12:2008:16:55:44 8.39 04:12:2008:16:55:45 Re tighten head 04:12:2008:16:55:45 8.39 04:12:2008:16:56:14 8.38 04:12:2008:16:56:22 End Water 04:12:2008:16:56:22 8.39 04:12:2008:16:56:44 8.39 04:12:2008:16:57:14 8.39 04:12:2008:16:57:44 8.39 04:12:2008:16:58:14 8.39 04:12:2008:16:58:44 8.39 04:12:2008:16:59:14 8.39 04:12:2008:17:02:14 8.39 04:12:2008:17:02:44 7.85 04:12:2008:17:03:14 7.90 04:12:2008:17:03:44 8.18 04:12:2008:17:04:14 8.34 04:12:2008:17:04:44 8.35 04:12:2008:17:05:14 8.34 04:12:2008:17:05:44 8.35 04:12:2008:17:06:44 8.34 04:12:2008:17:07:14 8.34 04:12:2008:17:07:44 8.25 04:12:2008:17:08:14 8.28 04:12:2008:17:08:44 8.35 CMT VOL CMT RATE bbl bbl/min 0.0 -28 0.0 0.0 0.0 -24 0.0 0.0 0.0 -28 0.0 0.0 0.0 -24 0.0 0.0 0.0 896 0.0 0.0 0.0 896 0.0 0.0 0.0 947 0.0 0.0 0.3 1395 0.3 0.9 0.9 1899 0.9 1.4 1.1 1784 1.1 0.0 1.1 1684 1.1 0.0 1.1 1606 1.1 0.0 1.1 1555 1.1 0.0 1.1 4 1.1 0.0 1.2 -24 1.2 0.2 1.2 -28 1.2 0.0 1.2 -28 1.2 0.0 1.2 -24 1.2 0.0 1.2 -24 1.2 0.0 1.2 -24 1.2 0.0 1.2 -24 1.2 0.0 1.2 -24 1.2 0.0 1.2 -24 1.2 0.0 1.2 -19 1.2 0.0 1.3 59 1.3 0.2 1.3 146 1.3 0.0 1.3 1221 1.3 0.0 1.3 1217 1.3 0.0 1.5 1501 1.5 0.9 1.6 1519 1.6 0.9 2.2 2000 2.2 1.5 2.4 2045 2.4 1.6 2.5 1858 2.5 0.0 2.5 1853 2.5 0.0 2.5 1844 2.5 0.0 2.5 1656 2.5 0.0 2.5 -1 9 2.5 0.0 2.5 -24 2.5 0.0 2.5 -38 2.5 0.0 2.5 -33 2.5 0.0 2.5 -33 2.5 0.0 2.5 -28 2.5 0.0 2.5 -28 2.5 0.0 2.5 -28 2.5 0.0 2.5 -28 2.5 0.0 2.5 -28 2.5 0.0 2.5 -33 2.5 0.0 2.5 -28 2.5 0.0 2.5 -28 2.5 0.0 2.5 -28 2.5 0.0 2.5 -28 2.5 0.0 Well: ALTAMURA # 1 Job Date: 04-12-2008 Time Density CMT STG VOL CMT TREAT PRES CMT VOL CMT RATE mm:dd:yyyy:hh:mm:ss Ib/gal bbl psi bbl bbl/min 04:12:2008:17:09:44 04:12:2008:17:10:14 04:12:2008:17:11:14 04:12:2008:17:12:14 04:12:2008:17:12:44 04:12:2008:17:13:14 04:12:2008:17:13:44 04:12:2008:17:14:14 04:12:2008:17:16:14 04:12:2008:17:18:44 04:12:2008:17:19:14 04:12:2008:17:19:44 04:12:2008:17:20:44 04:12:2008:17:21:14 04:12:2008:17:21:44 04:12:2008:17:22:14 04:12:2008:17:22:44 04:12:2008:17:22:51 04:12:2008:17:22:51 04:12:2008:17:23:01 04:12:2008:17:23:01 04:12:2008:17:23:14 04:12:2008:17:23:44 04:12:2008:17:24:14 04:12:2008:17:24:44 04:12:2008:17:25:14 04:12:2008:17:25:44 04:12:2008:17:25:53 04:12:2008:17:25:53 04:12:2008:17:26:14 04:12:2008:17:26:44 04:12:2008:17:27:44 04:12:2008:17:29:01 04:12:2008:17:29:01 04:12:2008:17:29:14 04:12:2008:17:29:44 04:12:2008:17:30:14 04:12:2008:17:30:44 04:12:2008:17:31:14 04:12:2008:17:31:44 04:12:2008:17:32:14 04:12:2008:17:32:44 04:12:2008:17:33:14 04:12:2008:17:33:44 04:12:2008:17:34:14 04:12:2008:17:34:44 04:12:2008:17:35:14 04:12:2008:17:35:44 04:12:2008:17:36:14 04:12:2008:17:36:44 04:12:2008:17:37:14 04:12:2008:17:37:44 04:12:2008:17:38:14 04:12:2008:17:38:44 04:12:2008:17:39:14 04:12:2008:17:39:44 04:12:2008:17:40:14 04:12:2008:17:40:27 04:12:2008:17:40:27 04:12:2008:17:40:44 04:12:2008:17:41:14 04:12:2008:17:41:44 04:12:2008:17:42:14 8.39 8.39 8.39 8.40 8.40 8.39 8.40 8.40 8.40 8.40 8.31 8.37 8.39 8.39 8.39 8.40 8.39 retighten head again 8.39 Pressure Test Lines 8.39 8.39 8.39 8.40 8.40 8.40 8.40 Reset Total, Vol = 3. 8.40 8.40 8.39 8.39 start 9.8 brine 8.39 8.39 8.51 9.47 9.65 9.68 9.70 9.72 9.73 9.72 9.73 9.74 9.75 9.75 9.75 9.75 9.75 9.75 9.75 9.75 9.75 9.75 9.75 9.75 Increase Pump Rate 9.75 9.74 9.74 9.75 9.75 86 bbl 2.5 77 2.5 0.0 2.5 68 2.5 0.0 2.5 63 2.5 0.0 2.5 63 2.5 0.0 2.5 59 2.5 0.0 2.5 59 2.5 0.0 2.5 59 2.5 0.0 2.5 54 2.5 0.0 2.5 49 2.5 0.0 2.5 -1 5 2.5 0.2 2.7 915 2.7 0.1 2.7 1166 2.7 0.0 3.1 1720 3.1 1.7 3.8 1986 3.8 0.0 3.8 1047 3.8 0.0 3.8 553 3.8 0.0 3.8 361 3.8 0.0 3.8 329 3.8 0.0 3.8 292 3.8 0.0 3.8 960 3.8 0.0 3.8 3222 3.8 0.0 3.8 2576 3.8 0.0 3.8 4362 3.8 0.0 3.8 5163 3.8 0.0 3.8 4 3.8 0.0 3.9 49 3.9 0.0 0.0 72 3.9 0.0 0.0 59 3.9 0.0 0.0 63 3.9 0.0 0.0 1349 3.9 0.0 0.0 1363 3.9 0.0 0.4 1752 4.2 0.9 0.9 1981 4.8 1.3 1.6 2027 5.5 1.5 2.4 2064 6.3 1.8 3.4 2082 7.3 2.0 4.5 2045 8.3 2.0 5.5 2022 9.3 2.0 6.5 2022 10.3 2.0 7.5 1995 11.4 2.0 8.5 1963 12.4 2.0 9.5 1977 13.4 2.0 10.5 1967 14.4 2.0 11.6 1935 15.4 2.0 12.6 1913 16.4 2.0 13.6 1917 17.4 2.0 14.6 1890 18.5 2.0 15.6 1844 19.5 2.0 16.6 1853 20.5 2.0 17.6 1844 21.5 2.0 18.7 1784 22.5 2.0 19.7 1789 23.5 2.0 20.7 1789 24.6 2.3 21.2 1803 25.1 2.4 22.0 1812 25.8 2.6 23.3 1821 27.2 2.7 24.7 1780 28.5 2.7 26.0 1766 29.9 2.7 Well: ALTAMURA # 1 Time Density mm:dd:yyyy:hh:mm:ss Ib/gal CMT STG VOL T CMT TREAT bbl psi Job Date: 04-12-2008 CMT VOL CMT RATE bbl bbl/min 04:12:2008:17:42:44 9.75 27.4 1743 31.2 2.7 04:12:2008:17:43:14 9.75 28.7 1739 32.6 2.7 04:12:2008:17:43:44 9.76 30.1 1734 34.0 2.7 04:12:2008:17:44:14 9.75 31.4 1697 35.3 2.7 04:12:2008:17:44:44 9.75 32.8 1670 36.7 2.7 04:12:2008:17:45:14 9.75 34.2 1656 38.0 2.7 04:12:2008:17:45:44 9.75 35.5 1638 39.4 2.7 04:12:2008:17:46:14 9.75 36.9 1629 40.7 2.7 04:12:2008:17:46:44 9.75 38.2 1588 42.1 2.7 04:12:2008:17:47:14 9.76 39.6 1597 43.5 2.7 04:12:2008:17:47:44 9.75 41.0 1592 44.8 2.7 04:12:2008:17:48:14 9.76 42.3 1551 46.2 2.7 04:12:2008:17:48:44 9.75 43.7 1519 47.5 2.7 04:12:2008:17:49:14 9.75 45.0 1514 48.9 2.7 04:12:2008:17:49:44 9.75 46.4 1487 50.2 2.7 04:12:2008:17:50:14 9.75 47.7 1487 51.6 2.7 04:12:2008:17:50:44 9.75 49.1 1496 53.0 2.7 04:12:2008:17:51:14 9.75 50.5 1464 54.3 2.7 04:12:2008:17:51:44 9.75 51.8 1414 55.7 2.7 04:12:2008:17:52:14 9.75 53.2 1441 57.0 2.7 04:12:2008:17:52:44 9.75 54.5 1418 58.4 2.7 04:12:2008:17:53:14 9.75 55.9 1404 59.7 2.7 04:12:2008:17:53:44 9.75 57.2 1423 61.1 2.7 04:12:2008:17:54:14 9.75 58.6 1372 62.5 2.7 04:12:2008:17:54:44 9.75 60.0 1331 63.8 2.7 04:12:2008:17:55:14 9.75 61.3 1317 65.2 2.7 04:12:2008:17:55:44 9.75 62.7 1285 66.5 2.7 04:12:2008:17:56:14 9.75 64.0 1267 67.9 2.7 04:12:2008:17:56:44 9.75 65.4 1253 69.3 2.7 04:12:2008:17:57:14 9.75 66.8 1240 70.6 2.7 04:12:2008:17:57:44 9.75 68.1 1189 72.0 2.7 04:12:2008:17:58:14 9.75 69.5 1171 73.3 2.7 04:12:2008:17:58:44 9.75 70.8 1162 74.7 2.7 04:12:2008:17:59:14 9.75 72.2 1130 76.0 2.7 04:12:2008:17:59:44 9.75 73.5 1111 77.4 2.7 04:12:2008:18:00:14 9.75 74.9 1111 78.8 2.7 04:12:2008:18:00:44 9.75 76.3 1075 80.1 2.7 04:12:2008:18:01:14 9.75 77.6 1047 81.5 2.7 04:12:2008:18:01:44 9.75 79.0 1052 82.8 2.7 04:12:2008:18:02:14 9.75 80.3 1038 84.2 2.7 04:12:2008:18:02:44 9.75 81.7 1038 85.6 2.7 04:12:2008:18:03:14 9.75 83.0 1038 86.9 2.7 04:12:2008:18:03:44 9.75 84.4 1043 88.3 2.7 04:12:2008:18:04:14 9.75 85.8 1024 89.6 2.7 04:12:2008:18:04:44 9.75 87.1 1015 91.0 2.7 04:12:2008:18:05:14 9.75 88.5 1015 92.3 2.7 04:12:2008:18:05:44 9.75 89.8 1002 93.7 2.7 04:12:2008:18:06:14 9.75 91.2 1029 95.1 2.7 04:12:2008:18:06:44 9.75 92.6 1024 96.4 2.7 04:12:2008:18:07:14 9.75 93.9 1015 97.8 2.7 04:12:2008:18:07:44 9.75 95.3 1015 99.1 2.7 04:12:2008:18:08:14 9.76 96.6 1011 100.5 2.7 04:12:2008:18:08:44 9.75 98.0 1011 101.8 2.7 04:12:2008:18:09:14 9.75 99.3 1029 103.2 2.7 04:12:2008:18:09:44 9.76 100.7 1029 104.6 2.7 04:12:2008:18:09:48 end 9.8 brine 04:12:2008:18:09:48 9.75 100.9 1038 104.7 2.7 04:12:2008:18:10:01 Start Pumping Water 04:12:2008:18:10:01 9.74 101.5 1002 105.3 2.7 04:12:2008:18:10:09 Reset Total, Vol = 101.84 bbl 04:12:2008:18:10:09 8.72 101.8 1006 105.7 2.7 04:12:2008:18:10:14 8.47 0.2 1011 105.9 2.7 04:12:2008:18:10:44 8.37 1.6 1006 107.3 2.7 Well: ALTAMURA # 1 Time mm:dd:yyyy:hh:mm:ss 04:12:2008:18:11:14 04:12:2008:18:11:24 04:12:2008:18:11:24 04:12:2008:18:11:39 04:12:2008:18:11:39 04:12:2008:18:11:42 04:12:2008:18:11:43 04:12:2008:18:11:44 04:12:2008:18:12:14 04:12:2008:18:12:44 04:12:2008:18:13:14 04:12:2008:18:13:44 04:12:2008:18:14:14 04:12:2008:18:14:44 04:12:2008:18:15:14 04:12:2008:18:15:44 04:12:2008:18:16:14 04:12:2008:18:16:44 04:12:2008:18:16:58 04:12:2008:18:16:58 04:12:2008:18:17:03 04:12:2008:18:17:03 04:12:2008:18:17:14 04:12:2008:18:18:14 04:12:2008:18:18:44 04:12:2008:18:19:14 04:12:2008:18:19:44 04:12:2008:18:20:14 04:12:2008:18:20:44 04:12:2008:18:21:14 04:12:2008:18:21:44 04:12:2008:18:22:14 04:12:2008:18:23:14 04:12:2008:18:23:44 04:12:2008:18:24:14 04:12:2008:18:24:44 04:12:2008:18:25:14 04:12:2008:18:27:14 04:12:2008:18:28:14 04:12:2008:18:28:44 04:12:2008:18:30:14 04:12:2008:18:30:44 04:12:2008:18:31:44 04:12:2008:18:32:44 04:12:2008:18:33:44 04:12:2008:18:34:14 04:12:2008:18:35:14 04:12:2008:18:35:44 04:12:2008:18:36:44 04:12:2008:18:37:14 04:12:2008:18:37:44 04:12:2008:18:38:00 04:12:2008:18:38:00 04:12:2008:18:38:14 04:12:2008:18:38:44 04:12:2008:18:39:44 04:12:2008:18:40:25 04:12:2008:18:40:25 04:12:2008:18:40:44 04:12:2008:18:41:14 04:12:2008:18:43:44 04:12:2008:18:44:14 04:12:2008:18:44:44 Job Date: 04-12-2008 Density CMT STG VOL CMT TREAT PRES CMT VOL ~ CMT RATE Ib/gal bbl psi bbl ~ bbl/min 8.39 End Water 8.39 Drop Top Plug 8.40 Reset Total, Vol = 3.29 8.39 8.40 8.38 8.40 8.39 8.40 8.37 8.40 8.41 8.39 8.39 8.39 plug didn't go 8.40 End Water 8.40 8.39 8.40 8.40 8.39 8.40 8.39 8.40 8.39 8.40 8.40 8.39 8.40 8.39 8.40 8.39 8.40 8.39 8.39 8.40 8.39 8.40 8.39 8.40 8.39 8.40 8.39 8.39 8.39 8.40 Reset Total, Vol = 2.79 8.39 8.39 8.41 8.40 start batching cement 8.41 8.40 8.41 8.41 8.41 8.41 2.9 1024 108.6 2.7 3.3 539 109.0 0.0 3.3 667 109.0 0.0 0.0 672 109.0 0.0 0.0 672 109.0 0.0 0.0 672 109.0 0.0 0.0 658 109.0 0.0 0.0 667 109.0 0.0 0.0 681 109.0 0.0 0.0 690 109.0 0.0 0.0 590 109.0 0.0 0.2 617 109.2 1.0 0.9 777 109.9 2.1 2.0 814 111.0 2.1 2.8 709 111.8 0.0 2.8 608 111.8 0.0 2.8 612 111.8 0.0 2.8 612 111.8 0.0 2.8 580 111.8 0.0 2.8 -42 111.8 0.0 2.8 -42 111.8 0.0 2.8 -42 111.8 0.0 2.8 -42 111.8 0.0 2.8 -42 111.8 0.0 2.8 -38 111.8 0.0 2.8 -42 111.8 0.0 2.8 -38 111.8 0.0 2.8 -38 111.8 0.0 2.8 -33 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -33 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -24 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 2.8 -28 111.8 0.0 0.0 -28 111.8 0.0 0.0 -24 111.8 0.0 0.0 -24 111.8 0.0 0.0 -24 111.8 0.0 0.0 -24 111.8 0.0 0.0 -24 111.8 0.0 0.0 -28 111.8 0.0 0.0 -24 111.8 0.0 0.0 -28 111.8 0.0 bbl bbl Well: ALTAMURA # 1 Job Date: 04-12-2008 Time Density •CMT STG VOL ,; CMT TREAT PRES CMT VOL CMT RATE mm:dd:yyyy:hh:mmas Ib/gal bbl ~; psi bbl bbl/min 04:12:2008:18:46:14 04:12:2008:18:50:44 04:12:2008:18:51:14 04:12:2008:18:52:14 04:12:2008:18:52:44 04:12:2008:18:55:14 04:12:2008:18:55:44 04:12:2008:18:56:14 04:12:2008:18:57:14 04:12:2008:18:57:44 04:12:2008:19:18:29 04:12:2008:19:18:30 04:12:2008:19:18:35 04:12:2008:19:19:59 04:12:2008:19:23:59 04:12:2008:19:24:09 04:12:2008:19:24:09 04:12:2008:19:24:29 04:12:2008:19:24:59 04:12:2008:19:25:29 04:12:2008:19:25:59 04:12:2008:19:26:29 04:12:2008:19:26:59 04:12:2008:19:27:12 04:12:2008:19:27:12 04:12:2008:19:27:29 04:12:2008:19:27:59 04:12:2008:19:28:29 04:12:2008:19:28:59 04:12:2008:19:29:29 04:12:2008:19:29:59 04:12:2008:19:30:29 04:12:2008:19:30:59 04:12:2008:19:31:29 04:12:2008:19:31:59 04:12:2008:19:32:29 04:12:2008:19:32:59 04:12:2008:19:33:29 04:12:2008:19:33:59 04:12:2008:19:34:29 04:12:2008:19:34:59 04:12:2008:19:35:29 04:12:2008:19:35:47 04:12:2008:19:35:47 04:12:2008:19:35:50 04:12:2008:19:35:50 04:12:2008:19:35:59 04:12:2008:19:35:59 04:12:2008:19:36:29 04:12:2008:19:36:59 04:12:2008:19:37:29 04:12:2008:19:37:59 04:12:2008:19:38:13 04:12:2008:19:38:13 04:12:2008:19:38:29 04:12:2008:19:38:41 04:12:2008:19:38:41 04:12:2008:19:38:59 04:12:2008:19:39:29 04:12:2008:19:39:59 04:12:2008:19:40:29 04:12:2008:19:40:59 04:12:2008:19:41:29 8.41 0.0 -24 111.8 0.0 8.41 0.0 -28 111.8 0.0 8.41 0.0 -24 111.8 0.0 8.41 0.0 -28 111.8 0.0 8.41 0.0 -24 111.8 0.0 8.42 0.0 -24 111.8 0.0 8.48 0.0 -5 111.8 0.0 8.48 0.0 -10 111.8 0.0 8.48 0.0 -15 111.8 0.0 8.47 0.0 -15 111.8 0.0 8.44 0.0 -24 111.8 0.0 wait on more water 8.44 0.0 -28 111.8 0.0 8.44 0.0 -24 111.8 0.0 8.57 0.0 13 111.8 0.0 batch up 15.8 cement 8.65 8.36 8.76 11.09 13.25 14.84 15.84 Start Cement Slurry 15.83 15.82 15.82 15.83 15.83 15.82 15.91 15.91 16.48 15.79 16.32 15.57 16.60 15.66 16.48 16.04 16.51 16.52 End Cement Slurry 10.95 Reset Total, Vol = 9.61 10.37 Start Pumping Water 9.47 8.82 8.60 8.48 8.45 End Water 8.44 9.38 start 9.8 brine 9.31 9.73 9.73 9.73 9.74 9.74 9.74 0.0 77 111.8 0.0 0.0 81 111.8 0.0 0.0 81 111.8 0.0 0.0 81 111.8 0.0 0.0 81 111.8 0.0 0.0 77 111.8 0.0 0.0 72 111.8 0.0 0.0 72 111.8 0.0 0.0 36 111.8 0.2 0.0 68 111.8 0.0 0.0 81 111.8 0.0 0.0 77 111.8 0.0 0.0 77 111.8 0.0 0.4 645 112.2 1.6 1.2 695 113.0 1.6 2.0 754 113.8 1.6 2.8 686 114.6 1.6 3.5 663 115.4 1.6 4.3 677 116.1 1.6 5.1 608 116.9 1.6 5.9 631 117.7 1.6 6.7 599 118.5 1.6 7.5 544 119.3 1.6 8.3 512 120.1 1.6 9.1 498 120.9 1.6 9.5 484 121.3 1.6 bbl 9.6 457 121.4 1.6 0.2 480 121.7 1.6 1.0 434 122.4 1.6 2.1 548 123.5 2.5 3.4 571 124.8 2.5 4.6 576 126.0 2.5 5.2 585 126.6 2.5 5.8 590 127.3 2.5 6.3 814 127.8 3.4 7.4 791 128.9 3.7 9.3 768 130.7 3.7 11.2 764 132.6 3.7 13.0 768 134.5 3.7 14.9 773 136.3 3.7 16.8 782 138.2 3.7 Well: ALTAMURA # 1 Job Date: 04-12-2008 Time Density CMT STG VOL j' CMT TREAT PRES CMT VOL CMT RATE mm:dd:yyyy:hh:mmas Ib/gal bbl ', psi bbl bbl/min 04:12:2008:19:41:59 9.74 18.6 796 140.1 3.7 04:12:2008:19:42:29 9.74 20.5 782 141.9 3.7 04:12:2008:19:42:59 9.74 22.4 764 143.8 3.7 04:12:2008:19:43:29 9.74 24.2 773 145.7 3.7 04:12:2008:19:43:59 9.74 26.1 796 147.5 3.7 04:12:2008:19:44:29 9.75 28.0 809 149.4 3.7 04:12:2008:19:44:59 9.74 29.8 818 151.2 3.7 04:12:2008:19:45:29 9.74 31.7 818 153.1 3.7 04:12:2008:19:45:59 9.75 33.6 800 155.0 3.7 04:12:2008:19:46:29 9.74 35.4 782 156.8 3.7 04:12:2008:19:46:59 9.75 37.3 796 158.7 3.7 04:12:2008:19:47:29 9.74 39.2 791 160.6 3.7 04:12:2008:19:47:59 9.75 41.0 796 162.4 3.7 04:12:2008:19:48:29 9.75 42.9 800 164.3 3.7 04:12:2008:19:48:53 2000 psi on annulus 04:12:2008:19:48:53 9.75 44.4 782 165.8 3.7 04:12:2008:19:48:59 9.74 44.8 800 166.2 3.7 04:12:2008:19:49:29 9.75 46.6 796 168.1 3.8 04:12:2008:19:49:59 9.74 48.6 800 170.0 3.8 04:12:2008:19:50:29 9.75 50.5 809 171.9 3.8 04:12:2008:19:50:59 9.75 52.4 818 173.8 3.8 04:12:2008:19:51:29 9.75 54.3 828 175.7 3.8 04:12:2008:19:51:59 9.75 56.2 814 177.6 3.8 04:12:2008:19:52:29 9.75 58.1 805 179.5 3.8 04:12:2008:19:52:59 9.75 60.0 791 181.4 3.8 04:12:2008:19:53:29 9.74 61.9 796 183.3 3.8 04:12:2008:19:53:59 9.75 63.8 855 185.2 3.8 04:12:2008:19:54:29 9.74 65.7 818 187.1 3.8 04:12:2008:19:54:35 plug landed in tubing tail 04:12:2008:19:54:35 9.75 66.1 814 187.5 3.8 04:12:2008:19:54:59 9.75 67.6 873 189.0 3.6 04:12:2008:19:55:29 9.75 69.1 727 190.5 2.1 04:12:2008:19:55:43 cement @ pens 04:12:2008:19:55:43 9.75 69.6 754 191.0 2.1 04:12:2008:19:55:59 9.75 70.1 759 191.6 2.0 04:12:2008:19:56:29 9.75 71.0 736 192.4 1.6 04:12:2008:19:56:59 9.76 71.5 585 192.9 0.0 04:12:2008:19:57:29 9.76 71.5 480 192.9 0.0 04:12:2008:19:57:59 9.76 71.5 416 192.9 0.0 04:12:2008:19:58:05 end brine and displacement 04:12:2008:19:58:05 9.76 71.5 406 192.9 0.0 04:12:2008:19:58:20 master closed 04:12:2008:19:58:20 9.76 71.5 384 192.9 0.0 04:12:2008:19:58:29 9.76 71.5 370 192.9 0.0 04:12:2008:20:18:32 End Job 04:12:2008:20:18:32 8.22 71.5 27 192.9 0.0 Schlumberger lCementin fob Re ort• 9 P CemCA7 v1.O 9-5/8" x 7" annulus cement iob (bullhead) Well Altamura 01 ~ Cllent T Anadarko Field SIR No. Engineer Rob Clarke ]Ob Type 7" by 9 5/8" Abandonment Squee Country United States lob bate 04-14-2048 "~ --- lime • --. __ --- a,~«~....~,,., Pressure Rate Density Messages 22:17:45 Start ]Ob Pressure up Unes ~ Open to Well Start Pumping Water 22:23:00 Pressure Test Unes End Water Reset Total, Vol = 5.01 bbl 22:28;00 Start Lead (ASL) Slurry 22:33:00 22:38:00 22:43:00 .~ 22:48:00 22:53:00 £nd CemenY Slurry Reset Total, Vol = 72.13 bbt 22:58:00 Statt Tail (ASS) Slurry 23:03:00 23;08:00 23:13:00 End Cemnt Slurry Reset Tbta1, YOI = 14.01 bbl Close in Well Flush Lines End )ob 23:20:54 Stopped Acquisition hh-mm•ss o.oo woo iooo woo aso seoo o.oo xo a.o c.o e.o io.o s.o io.o u.o ~o.e n.o 04/14/2008 22:52:26 ~~~N Cemen#ing Service Report • Cudonwr Anadarko Pe#rafeum Corp. Job Number 2201078968 Wets ALTAMURA 1 Location Repali Schlum6ergar Location Prudhoe Bay, AK Job Start 2008-Apr-14 Field WIL©CAT Formation NamelTyps Deviation Bit Si:a in well MD ft watt TVD ft County Harrison Bay _ "~ StatelProvince AK BNP psi 8N5T °F 13NCT °~ Pore Press. Gradierd psilft well Mashr. 0630402397 APl rE1Wi: 5010320403OD00 _ CasirigJLiaer Rig Name DAliatlFOr ~ ~ Service Via _ Depth,ft Slze,nr welght,IWtt Grade Thread Wellhead Oit Land 2980 9.63 40 L-80 BTC Ofranore zone wen Clxas w.tl Typo ---- 8100 7 26 K55 ~ BTC _ Old WorICOVer 't'ubing/DritF Pipe ~ Drilling Fluitl Type Max. oens0y Plastic Vi: ay Depth, Side, in Weipht, tbAt Grade Theead Brine 9.4 iblgal 9000 3.5 9.3 H40 IdlA Servke ttna Jub Type Cementing Plug 8 Abandon PerfaratfiansK7pen Ho(e` Max. Allowed Tubnig Pressure Max. Albwed Ann. Pressure WsIlNead Comrectlan Top, ft aattern, ft apT No. of Snotd Total Interval 3000 psi 1000 psi 1502" Weep 2970 2980 5 50 ft Service Instructions Diameter To provide equipment, personal and products to abandon well. in Treat Down Annulus Displacement 3 bbl Packer type Packer Depth ft Tubinp Vol. 26 bbl Cashtg Vol. 70 bbi Ararular Vol. 85 bbi OpsnNale Vol bbl Caei:lglTubirq scoured ® 1 Hole Volume Circulated prior to Cemerding© Caging TOOIS Squeozta Job LittPressure: ps i shoe Type: Guide 39uee>;s7ype Running Pipe Rotated ~ Pipe Reclprocated~ Shoe Depth: 91 OO ft Toot Type: None No. Cerdrellmre: Top lugs: Bottom plugs: ~ ~ Stage Tool Type: Tool Depth: 3000 ft axr# Head Type: stage Toot Depth: ft Tiii Pipe size; In Job Sclmduled For: Arrived on Caption: ~ Leave Loptton: Collar Type: --`--~~~ _-Tail Pipe Depth: ~_._._._.._ ~ - 4/14l2008 13:00 20D8-Apr-14 17:00 20D8-Apr-15 O:OD collar Depth: g spa total va: bbi Date Tittle 24fir -.dock srsagng Pmsun ppi cr:trr RATE bbnmtn LINT vtn bbl o 0 o 0 ® 0 e 0 ~~ 2008-Apr-i 4 22:17 31 0.0 0.0 0 0 0 0 20D8-Apr-14 22:17 31 fl.0 0.0 0 0 0 0 2008-Apr-14 22:17 Star# Job 2008-Apr-14 22:18 31 0.0 0.0 0 0 0 0 2008-Apr-14 22:18 Pressure up Lines 2008-Apr-t 4 22:19 36 0.3 0.1 0 0 0 0 2008-Apr-14 22:20 283 0.0 0.4 0 0 0 0 2008-Apr-14 22:20 Open to Well 2008-Apr-14 22:21 791 3.2 1.4 D 0 0 0 2008-Apr-14 22;21 Start Pumping Water 2008-Apr-14 22;21 782 3.3 2.1 0 0 0 0 2008-Apr-14 22:22 686 0.0 5.0 0 0 0 0 2008-Apr-14 22:23 3409 0.0 5.0 0 0 0 0 2008-Apr-14 22:23 Pressure Test Lines 2008-Apr-14 22:24 3373 0.0 5.0 0 0 0 0 2008-Apr-14 22:28 808 0.0 5.0 0 0 0 0 2008-Apr-14 22:26 End Water 2008-Apr-14 22:26 599 O.Q 5.0 0 0 0 0 2008-Apr-14 22:26 Reset Tatal, Vol = 5.01 bbl 2008-Apr-i 4 22:26 599 0.0 5.0 0 0 0 0 2008-Apr-14 22:28 Siart Lead (ASL) Slurry 2008-Apr-14 22:26 599 0.0 5.0 0 0 0 0 Apr 14,2000 WR53 v3.4145R Page 1 of 3 • • Wei! ..-..... ALTAMURA #1 Fleld WILDCAT 5ervioe Date 00105-Apr-14 Customer Job Number Anadarko petroleum Corp. 2201 0 78 9 88 pBtA Time 24 hr ~{ppk Treating Prasauna psi CtNt RATE bbtlmiR erutr VOL Wtf 0 0 0 0 0 0 0 0 NFtassage ~ 2008-Apr-14 22:27 741 2.2 0.4 0 0 0 0 2008-Apr-14 22:29 750 2.5 5.3 0 0 0 _ 0 2008-Apr-14 22:31 754 2.5 9.5 0 0 0 0 2008-Apr-14 22:32 736 2.5 13.7 0 0 0 0 2008-Apr-14 22:34 727 2.5 18.0 0 D 0 0 2008-Apr-14 22:35 727 2.5 22.2 0 0 0 0 2008-Apr-14 22:37 713 2.5 26.4 D 0 0 0 2008-Apr-14 22:39 713 2.5 30.6 0 0 0 6 2008-Apr-14 22:41 713 2.5 34.8 0 0 0 0 2008-Apr-14 22:42 704 2.5 39.0 0 0 0 0 2006-Apr-14 22:44 699 2.5 43.3 0 0 0 0 2008-Apr-14 22:46 686 2.5 47.5 0 0 0 0 2008-Apr-94 22:47 709 2.5 51.7 0 0 D 0 2008-Apr-14 22:49 704 2.5 55.9 0 0 0 0 2008-Apr-14 22:51 713 2.5 60.1 0 0 0 0 2008-Apr-14 22:52 690 2.5 84.3 0 0 0 0 2008-Apr-14 22:54 713 2.5 B8.5 0 0 0 0 2008-Apr-14 22:55 End Gemerit Slurry 2008-Apr-14 22:55 704 2.5 72.0 0 0 0 0 2008-Apr-14 22:55 699 2.5 72.1 0 0 D 0 2008-Apr-14 22:55 Reset Total, Vol = 72,13 bbl 2008-Apr-14 22:55 709 2.5 0.2 0 0 0 0 2008-Apr-i4 22:55 Start Tail (AS1) Slurry 2008-Apr-14 22:56 704 2.5 0.6 0 0 0 0 2008 Apr-14 22:57 493 0,0 2.4 Q 0 0 0 2008-Apr-14 22:59 402 0.0 2.4 0 0 0 D 2008-Apr-14 23:01 B21 0,0 3.1 p 0 0 0 2008-Apr-14 23:02 434 0.0 3,1 0 0 0 0 2008-Apr-94 23:04 518 0.0 3.5 0 0 0 0 2008-Apr-14 23:06 553 0.0 4.3 0 0 0 0 2008-Apr-14 23:07 516 0,0 5.4 0 0 0 0 2008-Apr-14 23:09 484 0.0 5.8 0 0 0 0 2008-Apr-14 23:97 71$ 1.6 7.$ 0 0 0 0 2008-Apr-14 23:12 690 9.6 9.5 0 0 0 D 2008-Apr-14 23:94 fi81 1,6 12.2 0 0 0 0 2008-Apr-14 23:15 493 0.0 14.0 0 0 0 0 2008-Apr-14 23:15 End Cement Slurry 2008-Apr-14 23:15 Rest Total, Vol = 14.01 bbl 2008-Apr-14 23:15 489 0.0 14.0 0 0 0 0 2008-Apr-14 23:16 471 0.0 0.0 0 0 0 0 2008-Apr-14 23:17 Close in Well 2008-Apr-14 23:17 59 0.0 0.0 0 0 4 0 2008-Apr-14 23:17 72 0.2 0.0 0 0 0 0 2008-Apr-14 23:19 59 0.9 1.1 0 0 0 0 2008-Apr-14 23:19 Flush Lines 2008-Apr-14 23:19 59 1.0 1.3 0 0 0 0 2008-Apr-14 23:19 59 1.0 1.6 0 0 0 D 2008-Apr-14 23:19 End Job 2008-Apr-14 23:21 63 O.D 2.5 0 0 0 0 2008-Apr-14 23:22 123 0.0 2.5 0 D 9 0 2008-Apr-14 23:24 127 0.0 2.5 0 0 0 D 2008-Apr-14 23:26 68 0.0 2.8 0 0 0 0 2098-Apr-14 23:27 59 0.0 2.8 0 0 0 0 2008-Apr-14 23:29 54 0.0 2.8 0 0 0 0 Apr 14,2008 WR53 v3.474SR Page 2 of 3 • • well ~~.. Fleld ..- - Service Date Customer -~. Job:Number ALTAMURAlft WILDCAT OB105Apr-i4 AnadarkoPadoleumCOip. °2201078988 Ddte Time Treating CMT RATE CMT VOL 0 0 0 0' Messag@ Prsssurc 24 hr - clock psi b6tfmin bbl 0 0 0 0 2008-Apr-'! 4 23:31 B3 0.0 2.8 0 0 ~ 0 0 2008-Apr-14 23:32 40 0.0 2.8 0 p p p 2008-Apr-14 23:34 40 0.0 2.8 p 0 p 0 _ _---- ____ Post Job S ummaq Average Pump Rates, bpm ^ Volume of Fluid injected, bbl Slurry N2 Mud Mpxtmum Rabe Total Slurry ldua Spacer N2 2.5 2.5 76 5 Treating Pressure Summary, psi Breakdown Fluid Maximum Flnal Average Bump Plug to Breakdown Volume 17erralty 800 650 ~ bbl ~ Ib/gal Avg. N2 Percem Designed Slurry Volume Dlsplacemerrt Mix Water Temp ~ Cement Circulated to Surface? Volume bbl °~ 74 bbl ~ 0.5 bbl 75 °F ^ weatxd Thro Perfa To g Customer ar AuHrorbx+d Repreaerdathre Schlumhergar Supervisor Mohrbacher, Jesse Robert Clarke [] cln:alationLost ^ Jab Completed Apr 14,2008 WRS3 v3.414SR Page 3 of 3 Schlumberger ~ementing )ob Repor~ CemCAT vi.0 Balanced plug in 3.5" tubing and 3.5" X 7" annulus Well Altamura 1 Client Anadarko Field Wildcat SIR NO. 2201078986 Engineer Kyfe Christensen ]ob Type Balance plug Country United States ]ob Date 04-15-2008 Time W9sfiua 1e~.6:oI pressure --- Rate Density Messages ~ 18:46:03 }SA start Prime Up W 19:01:00 1 19:16:00 19:31:00 } S' !~ i ' f 19:46:00 t 7 } 20:01:00 I ~ ,~~ a start water ahead z ~ ~ zo:16:00 I i start batch up ASL 10.7 PPG 20:31:00 j Start Pumping ~ ~1 1 20:46:00 ~ j `~ 21:01:00 { f ~~ ~ Stop Pumping 21:16:00 ~ ! S J ~ s start water behl»d bleed back, check pressure 21:29:51 EndJOb hh:mm•ss om sooo zooo 7000 •oao saoo o.oo x.u ..0 6A ao io,o s.o io.a 9e.o zo.o zs.o 9tl.VJ99.Sb39:59 PSI 8/M - - L8/G 04/15/2008 22:23:02 c;rlaCOmer: AnadarKO ~~ Distric#: Prudhoe Bay Representative: Mike Flynn DS Supervisor: Kyle Christensen Job Date: 04-15-2008 Weft Altamura 1 Time Treating Pressure Density MM RATE mm:dd:yyyy:ilh:mm:ss psi Ib/gal bbl/min 04:15:2008:18:46:03 0 -0.00 0.0 `~'~ 1 r:~ ~~~: ~~ ~'ir'~ ~ v=Ja1 04:15:2008:1$:46:31 0 -0.00 0.0 {34:'f°~J:z<~~~1~:~1~:~~~ Mart I~CiCTI~? ~.lp 04:15:2008:18:46:49 0 -0.00 0.0 04:15:200$:18:47:03 0 -0.00 0.0 04:15:2008:18:48:03 0 -0.00 0.0 04;15:2008:18:49:03 0 -0.00 0.0 04:15:2008:18:50:03 0 -0.00 0.0 04:15:2008:18; 51:03 0 -0.00 0.0 04:15:2008:18:52:03 0 -0.00 0.0 04:15:2008:18:53:03 0 -0.00 0.0 04:15:2008:1$:54:03 -5 0.69 0.0 04:15:2008:18:55:03 60 8.34 0.0 04:15:2008:18:56:03 0 8.21 0.0 04:15:2008:18:57:03 0 8.32 0.0 04:15:2008:18:58:03 46 8.35 0.0 04:15:2008:18:59:03 128 8.35 0.0 04:15:2008:19:00:03 -5 8.30 0.0 04:15:2008:19:01:03 -5 8.20 OA 04:15:2008:19:02:03 55 8.30 0.0 04:15:2008:19:03:03 0 8.35 0.0 04:15:2008:19:04:03 0 8.35 0.0 04:15:2008:19:05:03 0 8.35 0.0 04:15:2008:19:06:03 27 $.35 0.0 04:15:2008:19:07:03 27 8.35 0.0 04:15:2008:19:08:03 27 8.35 0.0 04:15:2008:19:09:03 46 $.35 0.0 04:15:2008:19:10:03 46 8.35 0.0 04:15:200$:19:11:04 46 8.35 0.0 04:15:2008:19:12:04 41 8.3fi 0.0 04:15:2008:19:13:04 41 8.76 0.0 04:15:2008:19:14:04 41 8.83 0.0 04:15:2008:19:15:04 41 8.86 0.0 04:15:2008:19:16:04 41 8.94 0.0 04:15:2008:19:17:04 41 8.93 0.0 04:15:200$:19:18:04 27 8.92 OA 04:15:2008:19:19:04 fi4 8.84 0.0 04:15:2008:19:20:04 9 9.05 D.0 04:15:2008:19:21:04 0 9.06 0.0 04:15:2008:19:22:04 0 8.44 0.0 04:15:2008:19:23:04 0 8.65 0.0 04:15:2008:19:24:04 0 8.75 0.0 04:15:2008:19:25:04 0 8.86 0.0 Page 1 of 4 Weil: Altamura 1 I ob Date: 04-15-2008 Time Treating Pressure Density MM RATE mm:dd:yyyy:hh:mm:ss psi Ib/gal bbi/min 04:15:2008:19:28:04 0 8.94 0.0 04:15:2008:19:29:04 0 8.93 0.0 04:15:2008:19:30:04 0 8.93 0.0 04:15:2008:19:31:04 0 8.92 0.0 04:15:2008:19:32:04 0 8.92 0.0 04:15:2008:19:33:04 0 8,92 0.0 04:15:2008:19:34:04 0 8.91 0.0 04:15:2008:19:35:04 215 9.01 0.0 04:15:2008:19:36:04 105 9.00 0,0 04:15:2008:19:37:04 14 8.92 0.0 04:15:2008:19:38:04 9 8.92 0.0 04:15:2008:19:39:04 5 9.01 0.0 04:15:2008:19:40:04 5 8.94 0.0 04:15:2008:19:41:04 5 8.40 0,0 04:15:2008:19:42:04 5 8.38 0.0 04:15:2008:19:43:04 0 8.38 0.0 04:15:2008:19:44:04 0 8.38 0.0 04:15:2008:19:45:04 0 8.38 0.0 04:15:2048:19:46:04 0 8.38 0.0 04:15:2008:19:47:04 0 8.37 0.0 04:15:2008:19:48:04 0 8.38 Q.0 04:15:2008:19:49:04 0 8.37 0.0 04:15:2008:19:50:04 0 8.37 0,4 04:15:2008:19:51:04 0 8.54 0.0 04:15:2008:19:52:04 0 8.74 0.0 04:15:2008:19:53:04 0 8.93 0.0 04:15:2008:19:54:04 0 8.93 0.0 04:15:2008:19:55:04 0 9.02 0.0 04:15:2008:19:56:04 0 8.96 0.0 04:15:2008:19:57:04 128 9.28 0.0 04:15:2008:19:58:04 82 9.28 0.0 04:15:2008:19:59:04 64 9.28 0.0 04:15:200$:20;00:04 64 9.28 0.0 04:15:2008:20:01:04 60 8.57 0.0 04:15:2008:20:02:04 9 8.22 0.0 04:15:2008:20:03:04 37 8.97 0.0 04:15:2008:20:04:04 0 8.99 0.0 04:15:2008:20:05:04 101 8.99 0.0 04:15:2008:20:06:04 96 8.99 0.0 ~r~ '~~~;r'~1~~`~ ~ ~Ct:~~~.~~ ~i`~•";'ii~' k~ll~i';s!'t' c`~F'.::1% 04:15:2008:20:06:24 96 8.99 0.0 04:15:2008:20:07:04 92 8.99 0.0 04:9 5:2008:20:08:04 0 8.98 1.9 04:15:200$:20:09:04 -5 8.98 1. $ 04:15:2008:20:10:04 9 8.98 0.0 04:15:2008:20:11:04 9 8.99 0.0 04:15:2008:20:12:04 1442 8.98 0.0 04:15:200$:20:13:04 3369 8.98 0.0 04:15:2008:20:14:04 3186 8.98 OA 04:15:2008`2Q:14:09 FT 04:15:2008:20:14:09 2948 8.98 0.0 Page 2 of 4 Weli; Altamura 1 ~ ' ob Date: 04-15-2008 Time Treating Pressure Density MM RATE mm:dd:yyyy:hh:mm:ss psi Ib/gal bbl/min 04:15:2008:20:15:04 9 8.98 0.0 04:15:2008:20:18:04 9 8.96 1.8 04:15:200$:20:17:04 -5 8.63 3.2 04:15:2008:20:18:04 18 8.87 0.0 04:15:2008:20:4 9:04 23 8.67 0.0 04: ~15:20i~82Q: ~l 9:4:4 start batch up ASL 10.7 F'F'G 04:15:2008:20:19:44 23 8.67 0.0 04:15:2008:20:20:04 23 8.67 0.0 04:15:200$:20:21:04 78 8.67 0.0 04:15:2008:20:22:04 7$ 8.48 8.4 04:15:2008:20:23:04 78 8.52 0.0 04:15:2008:20:24:04 78 9.50 0.0 04:15:2008:20:25:04 78 10.4 4 0.0 04:15:2008:20:26:04 73 10.47 0.0 04:15:2008:20:27:04 73 10.63 0.0 04:15:2008:20:28:04 73 10.92 0.0 04:15:2008:20:29:04 101 10.75 0.0 04.:15:2()Oti:20:29:1Fi Start Q~~mping 04:15:2008:20:29:18 60 10.$1 2.5 04:15:2008:20:30:04 82 19.17 4.5 04:15:2008:20:31:04 50 1Q,40 $.$ 04:15:2008:20:32:04 87 10.75 0.0 04:15:2008:20:33:04 50 9.83 0.0 04:15:2008:20:34:04 37 10.40 0.0 04:15:2008:20:35:04 23 10.74 0.0 04:9 5:2008:20:36:04 27 10.65 9.5 04:15:200$:20:37:04 73 10.73 4.8 04:15:2008:20:38:04 87 10.93 3.9 04:15:2008:20:39:04 92 10.95 0.0 04:15:2008:20:40:04 82 11.16 0.0 04:15:2008:20:41:04 82 11.28 0.0 04:15:200$:20:42:04 64 9.71 4.8 84:15:200$:20:43:04 69 10.63 4.7 04:15:2008:20:44:04 78 10.73 3.7 04:15:2008:20:45:44 78 10.69 3.5 04:15:2008:20:46:04 78 10.60 3.3 04:15:2008:20:47:04 82 10.57 3.2 04:15:2008:20:4$:04 82 10.85 3.0 04:15:2008:20:49:04 78 10.79 2.9 04:15:2008:20:50:04 82 10.92 3.0 04:15:2008:20:51:04 82 11.10 3.0 04:15:2008:20:52:04 82 10.73 2.9 04:15:2008:20:53:04 87 10.77 3.0 04:15:2008:20:54:04 82 10,79 2.8 04:15:2008:20:55:04 $7 10.97 2.8 04:15:2008:20:56:04 87 14.03 2.6 04:15:2008:20:57:04 82 10.73 2.4 04:15:2008:20:58:04 87 10.64 2.2 04:15:2008:20:59:04 92 10.91 2.0 04:15:2008:21:00:04 92 11.00 1.6 04:15:200$:21:01:04 92 10.83 1.3 Page 3 of 4 Well: Altamura 1 ~ ' ~ob Date: 04-15-2008 Time Treating Pressure Density MM RATE mm:dd:yyyy:hh:mm:ss psi Ib/gal bbUmin 04:15:2008:21:02:04 96 10.84 0.9 04:15:2008:21:03:04 92 10.95 0.6 04:15:2008:21:04:04 119 10.93 1.4 04:15:2008:21:05:04 252 10.80 1.3 04:15:2008:21:06:04 142 10.57 1.3 04:15:200$:21:07:04 261 10.51 1.3 04:15:2008:21:08:04 233 10.73 1.3 04:15:2008:21:09:04 288 10.65 1.3 04:15:2008:21:10:04 224 10.89 1.3 D4:15:2008:21:11:04 114 10.94 1.3 04:15:2008:21:12:04 288 11.08 1.3 04: t 5:2008:21:3 2:36 Stop Pumping 04:15:2408:21:12:36 69 10.90 0.0 04:15:2008:21:13:04 64 10.86 0.0 04:9 5:200$:21:14:04 64 11.07 0.0 04:15:2008:21:15:04 64 11.12 0.0 04:15:2008:21:16:04 60 11.15 0.0 04:15:2008:21;17:04 60 10.93 0.0 04:15:2008:21:18:04 60 11.11 0.0 04:7 5:2008:21:19:04 55 11.12 0.0 04:15:2008:21:20:04 55 11.05 0.0 04:15:2008:21:21:04 55 8.$0 0.0 04:15:20{}8:21:22:04 55 9.01 0.0 ~i~i .15.:2Ui~~3:~ `I '':~i l)!~ start water i<~ehnci D4:15:2008:21:23:00 55 9.02 D.0 04:15:2008:21:23:04 55 9.02 0.0 04:15:2008:21:24:04 179 9.09 0.4 04:15:2008:21:25:04 224 9.08 0.6 04:15:2008:21:26:04 5 9.08 0.p 04:15:2008:21:27:04 5 9.11 0.0 0~~:-I 5:2008:2`1.27:54 bleed k~acK, o~aok p~°essu~°e 04:15:2008:21:27:54 5 9.09 0.0 04:15:2008:21:28:04 5 9.09 0.0 04:15:2008:21:29:04 5 9.08 0.0 U4:'15::20G8; 71:29:'18 End .tnb 44:15:2008:21:29:1$ 5 9.08 0.0 Page 4 of 4 • • Maunder, Thomas E (DOA) From: Alaska.DrillingOpsMgr [Alaska.DritlingOpsMgrQanadarko.com] To: Maunder, Thomas E {DOA) Sent: Monday, April 14, 200812:47 PM Subject: Read: RE: Altamura #1 {202-010) Revised Surface Cementing Your message To: Ala~ca.Drigir~psMgr@anadarko.wm Subject: was read ort 4Ji4/20~ 12:47 PM. ~aoa~ ono __--- ~~~ A~~ ~ ~oa~ Page 1 of 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 12:14 PM To: 'Alaska.DrillingOpsMgr' Subject: RE: Altamura #1 (202-010} Revised Surface Cementing Fred, We have completed our analysis of the file information. Based on the logs and mud log, it would appear that there is a possible culprit sand at about 6270' that could be the potential source of the gas. Based on there being a "show" determined from that sand and the log quality, that interval should have been cemented when the well was originally drilled in 2002. I realize that you were not involved with that original drilling effort. We have also reviewed the proposed cementing program for the outer annulus and tubing. Commissioner Foersfier has been informed and has given her oral approval for you to proceed. Call or message with any questions. Tom Maunder, PE From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 10:45 AM To: 'Alaska.DrillingOpsMgr' Subject: RE: Altamura Revised Surface Cementing Fred, Thanks for the information. We are still examining the logs/records. What is the basis for the cement volume planned for the 9-5/8" x 7" annulus? Do you also have any information regarding the rates and pressures used when the annulus was killed? Tom Maunder, PE AOGCC From: Alaska.DrillingOpsMgr [mailto:Alaska.DrillingOpsMgr@anadarko.com] Sent: Monday, April 14, 2008 10:34 AM To: Maunder, Thomas E (DOA} Subject: FW: Altamura Revised Surface Cementing Please find attached the revised P&A procedure for the Altamura #1. If you have any questions feel free to call. Fred McDougal Drilling Operations Manager Anadarko Petroleum Company 3201 C Street, Ste 603 Anchorage, Alaska 99503 907-273-6302 (office) 713-819-6437 (cell) 832-636-5534 (fax to email account) 4/14/2008 Page 2 of 2 • • From: Amber Babcock [mailto:amber.babcock@fairweather.com] Sent: Monday, April 14, 2008 10:24 AM To: Alaska.DrillingOpsMgr Subject: Altamura Revised Surface Cementing Fred, Attached is the Revised Surface Cementing program for your review. Jesse will be contacting you shortly to discuss this. Thank you, Amber Amber Babcock Logistics Coordinator Fairweather E&P Services, inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Ofc: 907-258-3446 Ext. 328 Cell: 907-440-4280 Email: amber.babcock@fairweather.com Website: www.fairweather.com 41141200$ • Anadarko Petroleum Corp. • Altamura #1 P&A Project Proposed Change to Cementing Program Current Well Status as of 0600 hrs April 14, 2008: Perforations at 8600'f have been squeezed through the existing packer with 9 bbl cement and pressure tested to 2300 psi. The 9-5/8" x 7"annulus originally had 1150 psi on it and could not be bled off safely due to swirling winds on location. The annulus was bullheaded with $0 bb19 ppg NaCI brine which lowered the shut in pressure to 700 psi. Attempts tc> bleed off again yielded gas, mud, diesel mix. The annulus was then successfully swept with 27S bb170 degree water followed by 125 bb19.4 ppg NaCI brine with a shut in pressure of 700 psi and is now liquid packed to the surface. Current pressure on annulus is 250 psi and has been steadily dropping over the last 24 hours. Proposed Revisions to Surface Ceinentiutg Program; The originally proposed surface cementing program called for cementing both the 9-5/8 x 7" annulus and the 7" casing from 200' to surface. Because the 9-518" x 7" annulus was found to have pressure on it, the following proposed changes to the cementing program are recommended to eliminate any future potential for pressure to migrate to the near surface: 1. Rig up Schlunriberger and perforate the 3.5", 9.3 ppf tubing at 3000'. Rig down Schl Berger. 2. Rig up Schlumberger cementers on 9-S/S"x7" annulus and bullhead down annulus 396 cubic feet of 10.71 ppg Arctic Set Light cement followed by 77 cubic feet of 15.5E ppg Arctic Set I cement. Shut in annulus. ~ 535 I;~c~~ ~~ 3. Switch over to the tubing and pump 539 cubic feet of Arctic Set Light 10.7 ppg cement in the tubing and 3.5" x 7" annulus. Displace the tubing with diesel to 250'f below surface leaving brine in the 3.5" x 7" annulus from surface to 250'. 4. WOC per cementer's recommendation. 5. Rig up Schlumberger and cut tubing at 250'f. 6. Evacuate top 250' of 7"casing and 3.5" tubing with air by pumping air down the 7" x 3.S" annulus and up the tubing. 7. Remove tree and pull tubing hanger and tubing from well with booth truck. 8. Fi117" casing with 15.5 ppg Arctic Set I cement from 250' to surface. 9. Bleed off any residual pressure on 9-5/8" x 7" annulus. 10. Excavate cellar and cut off wellhead 4' below original tundra level. 11. Weld on marker plate and backfill excavation. Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 8:34 AM To: 'Alaska.DrillingOpsMgr' Cc: 'Jesse Mohrbacher' Subject: Altamura #1 (202-010) Contacts: AnadarkoAlaska. DrillingOpsMgr Fred and Jesse, I acknowledge our discussions yesterday regarding the discovery of pressure in the 9-5/8" x 7" outer annulus (OA) on the subject well. Jesse advised that they had successfully killed the annulus on 4/12 and Fred €urther advised by voice mail this morning that the pressures on the annulus continue to decline. 1 would appreciate an email summarizing the findings and the plan forward. My colleagues and 1 will be examining the logs in a bit. Thanks in advance for the summary and ptan forward. Tom Maunder, PE AOGCC 4/14/2008 • ~~ ~ SARAH PALIN, GOVERNOR t~il[~~7~ Ol[L A1QD GA$ 333 W. 7th AVENUE, SUITE 100 COI~TSERQA'1`I011T COMI~IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Fred McDougal 1=Ax (so7) z7sasa2 Drilling Operations Manager Anadarko Petroleum Corporation 3201 C Street, Suite 603 MAR ~ ~ 2008 Anchorage, Alaska 99503 RE: Exploration, Wildcat, Altamura # 1 Sundry Number: 308-078 ~ ~ ~ ~~ (~.~. ~; .;:. ,: Dear Mr. McDougal: Enclosed is the approved Application for Sundry Approval (Form 10-403) relating to the above referenced well. 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). During this exploration season, 48 hour notice will be appreciated. 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, Danie . Seamount, Jr Chair DATED this Z_b day of March, 2008 Encl. ANADARKO PETROLEUM CORPORAT~ March 7, 2008 Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7t" Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval: Abandonment MAIN 907/ 273-6300 3 STREET, SUITE 603 • ANCHORAGE, ALASKA 99503 ~„~a~~ Anadarko Altamura #1 Plug and Dear Mr. Seamount: ~ ao~ ono Anadarko Petroleum Corporation hereby applies for Sundry Approval to perform the final plug and abandonment of the Altamura #1 exploratory well located in the NPRA area of the North Slope. Enclosed find a Sundry Notice and the proposed P&A program for this well. The planned start date for ice road construction operations is on or about March 22, 2008 with well operations starting April 1, 2008 or shortly thereafter. For your information, this Sundry Notice is being simultaneously submitted to the US Bureau of Land Management. If you have any questions or require additional information, please contact me at (907) 273-6302. Sincerely, ~~r.~E~ MAR ~ ~ 2fl08 Fred McDougal Drilling Operations Manager Anadarko Petroleum Corporation enclosures MAR 1 ~ 2008 Aaaska 0~ & Gas Cons. Commission . Anchorage ORIGINAL ^^,~~ q~~~ ~ 3~~ST~ATE OF ALASKA~N ~~"'~~ I ALA OIL AND GAS CONSERVATION COM1~510N ib' ~'V" U ~ qR M _. ~~ APPLICATION FOR SUNDRY APPROVALS ~~~ ~ 20 AAC 25.280 1. Type of Request: Abandon ^~ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ~lOf~ Other Alter casing ^ Repair well ^ Plug Perforations ~~.(~ySt~imulate ^ Time Extension - ---~---• ll ~~ d W l ^""~ ° \ R d t S e e-en er uspen e Change approved program ^ Pull Tubing ^ Perforate New Poo 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Anadarko Petroleum Company Development ^ Exploratory ^ -_ 202-010 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: 3201 C Street, Suite 603 Anchorage, AK 99503 50-103-20403-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N/A Spacing Exception Required? Yes ^ No ^ Altamura No 1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): . AA-081736 NPRA 29 AGL, 154 AMSL Explorato " 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,100 9,014 Surface Surface 9010 MD / 8924 TVD None Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 105' 105' 1640 670 Surface 2721' 9 5/8" 2750' 2750' 5750 3090 Intermediate 8472' 7" 8501' 8415' 7240 5410 Production 788' 41/2" 9096' 9010' 9020 8540 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8557-8575,8590-8655 8471-8489,8504-8569 31/2" L-80 8838' Packers and SSSV Type: Baker ZXP Packer, 3 1/2" TRM-4E SSSV Packers and SSSV MD (ft): Packer @ 8308' &SSSV @ 1539' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^~ Development ^ Service ^ 15. Estimated Date for April 1, 2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission .Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ~ C.. ~o~F Title DQ/GL/N O ~R,~lT~ra~-~S iE ~~- Signature ~--~ Phone Date ~. /r~wE `107-' Z73-~3~2 // M~c/f o COMMISSION USE ONLY roval: Notify Commission so that a representative may witness Sundry Number: ~ ~- l.% Conditions of a pp lea rance ~ - S V '~~1 Plug Integrity ^~ BOP Test ^ Mechanical Integrity Test ^ Location C ~.5- ~ V~ -' ` ~ \ ~ Other: ~LCc~ e~Ot~~ZSS~~ s\ ~'QP~S~~ ~ ~~~ ~~'~e.S ,~ \V t5 ~\~S~L~ ShOI~W~C~4\Y~\U\ ~ ~ 3C~s~~~.~1~ ~ ~ ~~~~ ~ ~J~~ n ~ CSC- ,~ ~ S~ ri ~`~ ~~.1~ ~'C~S ~. ~ S ~ ~ Subsequent Form Required: ~ ~ -~~ C ~ V~1~~ ~V ~ r APPROVED BY ~ / 2 v f Approved by: C~MMISSI~NER THE C~MMISSI~N Date: .m Form 10-403 Revised 06/2006 O R 1 G I N A L~~'~" `''' ~ (c~~~j~p~p~plicate • Anadarko Petroleum Corporation Altamura No. 1 AA-081736/3160 (BLM) PTD: 202-010 (AOGCC) API No. 50-103-20403-00 Plug and Abandonment Operations Program Current Well Status: Suspended Exploration Well Background and Objectives: Altamura No. 1 was drilled in 2002 to delineate the Moose's Tooth complex in the eastern part of the NPRA. The well was completed as an observation well to assist in characterizing the. reservoir; and surface readout bottom hole pressure gauges were installed in the well for long term data collection before it was suspended at the close of the 2002 drilling season. The well is no longer needed for this purpose, and the operator intends to plug and abandon the well in conformity with BLM and AOGCC regulations. The well was drilled from an ice pad, and site restoration will be facilitated by placement of a subsurface steel abandonment marker plate 4 ft below tundra grade. It is intended that this will be a rigless P&A preferably without using coiled tubing to plug the perforations at 8557'-8575' and 8590'-8655'. If suitable injection rates can be achieved into the perforations, they will be squeezed with cement through the existing packer at 8308'. Otherwise, coiled tubing will be used to set the bottom plug in the well. Attachment I shows the current (suspended) well condition. Attachment II shows the post P&A condition of the well. Current Well Condition: (See Attachment I, Current Well Condition): TD: 9100' MD, 9014' TVD PBTD: 9010' MD, 8924' TVD Perforations: 8577'-8575', and 8590'-8655' Casin Summa : De the are MD Casin Size To Bottom Cementin Record Conductor 16" Surface 106' KB Cmt to Surface Surface 9 S/8" Surface 2476' KB Cement to Surface Intermediate 7" Surface 8501' KB TOC 7050' Liner 4'/a" 8308' 9096' KB 8308'-9096' Alternate No. 1 P&A Program • Tuhinu Summary: Denths are MD Size To Bottom Notes 3 '/z" Surface 8308' Camco 2.750" XN Profile nipple @ 8223' w/ PXN plug 9.3#, L-80 Camco 3.5" TRM-4E SCSSV @ 1539' w/ 2.81" x nipple (closed) 2 718" 8401' 8437' Tail pipe w/Flow sub and REG 6.5#, L-80 ID (Drift) is 2.34T' Notes: (1) Baker T'x4'/z" liner hanger w/ ZXP Packer and 10' PBR @ 8308' (2) Promore Surface read out pressure gauges @ 8256',BST pressure gauge mandrels @ 8144' and 8054', and Camco 3.5" x 1" Side pocket mandrel @ 7965', will all be abandoned in place. (3) The minimum ID in this well is 2.34T', which is the drift diameter of the 2 7/8" tail pipe. (4) The 3 '/2" tubing is filled with diesel from ~ 4363' to surface. (5) The 3 '/2" x 7" annulus is filled with diesel from 2388' to surface. (6) The 9 5/8" x 7" annulus is filled with diesel from 2196' to surface. (7) A BPV is installed in the 3 '/2" tubing hangar. Procedure -Site and Well Preparation 1. Construct ice road access spur to well location from CPAI Rondezvous 2 wellsite. Construct 200' x 200' ice pad around well as shown on stand alone construction plans. 2. MIRU camp and ancillary equipment. Establish voice and data communications from camp. 3. Install wellhead shelter. Rig up hot air heater, and apply heat to shelter before having FMC service wellhead valves. Construct scaffolding around wellhead to access valves. 4. Rig up VR plug lubricator and remove VR plugs from annulus valves. Measure and record initial pressures on 3 '/2" tubing (should be zero), 3 '/2" x T' annulus, and T' x 9 5/8" annulus. Expect to find approximately 200 psi on T' x 9 5/8" annulus due to diesel in annulus. 5. Move in balance of equipment while wellhead is being thawed and serviced. 6. Install waste tanks. Nipple up lines to tank from 3 '/z" tubing, and 3 '/2"x T' annulus ports. Altamura No. 1 PBcA Program 2 • Procedure - P&A Operations: Hold pre-operation safety meeting and JHA. 2. Install lubricator and pull BPV in 3 %" tubing hanger. Open SCSSV and monitor pressure. Pressure should be zero, and the tubing should be filled with diesel. Remainder of program assumes that the SCSSV can be opened from the surface. 5~ S~OI~ pmt rc~a~ 3. Pressure test tubing to 4~si. Pressure test 3 '/2" x T' annulus to psi. If tubing does not hold pressure, call out coiled tubing .unit to place plug across perforations according to attached supplementary coiled tubing cementing program. Proceed to Step 4 and skip Steps 5 and 6 in this scenario. 4. Rig up slickline lubricator, and RIH to pull PXN plug from Camco 2.750" XN profile nipple at 8223'. Test lubricator to 3000 psi. Take returns from well due to displacement of slickline to waste tank while running in hole. Anticipate some pressure increase at surface after PXN plug is pulled due to tubing being filled with diesel to µ 4584', and with 9.8 ppg kill weight brine below. POH with slickline, and close in well at tree. Establish injection pressure and rate into perforations by pumping down tubing with diesel. If unable to inject into perforations at acceptable rates, call out coiled tubing unit to place plug across perforations according to attached supplementary coiled tubing cementing program. 6. Rig up cementers to pump down 3-1/2" tubing and squeeze cement through Baker ZXP packer and into perforations. Follow cementing procedures as follows: a) Hold pre-operation meeting with all service companies involved to review equipment layout and sequence of operations. Follow with pre-operations safety meeting. b) Pressure test surface equipment to ~psiS~~ c) Pump 100 bbl non-freezing NaCI brine to flush diesel from tubing and casing. Mix and pump preflush followed by 7 bbl of class G cement. Drop wiper dart from cementing head before and after cement is pumped. gat a ~~~ ~~-~r~~ ll-~'_ ~ d) Displace cement with total bl cement postflush and 9.8 ppg kill weight non- freezing NaCI brine and shut in tubing. Keep pumping rates above 1.5 bpm to prevent freefall of cement in 4.5" casing. Shut in tubing and WOC per cementers direction. 7. Pressure test cement plug with 2300 psi surface pressure on tubing after WOC period. ~~ Chive AOGCC and BLM inspectors 24 hrs notice of pressure test and plug confirmation. Altamura No. 1 P&A Program • • 8. Prep to cut and pull tubing. Spot crane or boom truck. Rig up wireline with jet cutter. Pressure test lubricator to 1500 psi. RIH with jet cutter to 200'. Make tubing cut as close to 200' as possible, avoiding connection area of tubing. POOH. 9. RIH with tubing/casing punch and perforate tubing and T' casing at 195'. POOH and confirm punch of T' casing. 10. Rig down wireline unit and lubricator. 11. Alternate batch pumping 8 bbl volumes of 9.8 ppg NaCI brine down tubing and 9 5/8" x T' annulus taking returns out 3-1/2" x T' annulus valve to remove 63 bbls diesel in 3-1/2" x T' annulus and 62 bbls diesel in 9 5/8" x T' annulus. Collect diesel in surface tanks for recycle or disposal. 12. Remove tree and bonnet. Unseat tubing hanger. Pull tubing with crane and lay down. Surface readout cable from down hole pressure gauges, SSSV control line and chemical injection line should have parted when tubing was cut. If not, damage to these lines should be sufficient to part cable under tension. 13. Run a gauge ring in T' casing to top of tubing stub to verify absence of debris from control or injection lines inside T' casing. Set a plug in 7 inch casing on top of tubing stub at 200' to prevent cement from falling down hole. Re-install bonnet and tree on wellhead. 14. Give AOGCC and BLM inspectors 24 hrs notice of surface plug placement. Rig up cementers and batch mix 14 bbl 15t ppg permafrost cement slurry. Pump cement down T' x 9 5/8" annulus and take returns out T' casing to waste tank or vacuum truck. Shut in annulus and T' casing and WOC as directed. Rig down cementers. 15. While WOC, rig down wellhead enclosure. Excavate and remove well cellar. Extend excavation to 6 ft below tundra surface. Slope sides of excavation to allow ingress and egress of personnel and equipment. Remember: This excavation is a confined space. and conduct subsequent operations in excavation accordingly. 16. Rig up Wachs saw on 16" conductor at a point no less than 4 ft below tundra surface. Attach slings from crane or excavator to wellhead and apply tension to prevent saw. from binding. 17. Cut all casing strings on single pass, and remove wellhead and cut-off casing sections. 18. Top off any voids in cement in surface plugs in T' casing and 7" x 9 5/8" annulus. Photo document cement surface plugs before installing subsurface marker plate. Note:. Give AOGCC and BLM inspectors opportunity to observe cement surface plugs before installing marker plate. Altsmura No. 1 P&A Program 4 • • 19. Weld subsurface well marker plate on outermost casing as per 20 AAC 25.120(a), (b), and (d). Back fill excavation with native material on top of 1-2 ft gravel fill, so as to leave 1-2 ft mound over excavation to allow for settling and compaction. 20. Clean up location and move out equipment. Obtain interim final inspection from AOGCC and BLM representatives. 21. File completion report with AOGCC and BLM within 30 days of completion of field operations. 22. Return to location during summer of 2008 for final location cleanup, regrading (as necessary), and revegetation (as necessary). Obtain final agency location clearances. Notes: (1) Advise AOGCC North Slope Inspectors (telephone 907-659-2714) and BLM Inspectors (telephone 907-267-1429) 24 hours in advance of setting all plugs. (2) Hold Safety meetings and perform JHA's before initiating all critical operations. Altamura No. 1 PBcA Program 5 Anadarko Petroleum Corporation Altamura No. 1 Supplementary Coiled Tubing Cementing Procedure Rig up coiled tubing unit, and cementers to set cement plug across perforations. Follow coiled tubing cementing procedures as follows: a) Hold pre-operation meeting with all affected service companies to review equipment layout and sequence of operations. Follow with pre-operations safety meeting. b) MIRU service coil and cementers as per Schlumberger standards. c) Make up CT cementing BHA, including 2.0" OD ball drop nozzle. Max BHA OD is 2.00". d) Pressure test surface equipment, CT, BOP and lubricator to 4500 psi. e) RIH with coil tubing to 8760' MD. f) Mix and pump preflush spacer followed by 8 bbl, 15.8 ppg class G cement to lay plug across perforations. Use friction reducing additives, and retard slurry to allow minimum 3 hour pumping time. g) Displace fluid in CT with approximately 36 bbl diesel. After 0.5 bbl cement passes cementing nozzle, POOH with coiled tubing at 1:1 rate with cement placement. h) After all cement is out of nozzle, POOH. i) Rig down CT unit and cementers. WOC as directed by Schlumberger. j) Proceed to Step 7 in P&A procedure above. Altamuta No. 1 PBcA Program 6 • Altamura No. 1 Well Schematic Completed April 2002 B/ Permafrost CrD 649' 20" Hole 9 5/8" x 7" Freeze protected w/ 62 bbls Dies 7" x 3'/:" Freeze protected w 63 bbls Diesel 3'/:" Freeze protected w/ 38 bbls Diesel - • 16", 65ppf, H-40 @ 150' Cmt to surf '/. SS control line for injection sub and SCSSV 3.5" TRM-4E SCSSV 3HSS-1247 2.81 X-nip @ 1539' (closed) Camco 3.5"x1" KBUG-MW/DM.BK-5 Mandrel @ 2640' 12-1 /4" Hole Nova Injection sub @ 2,729' 9-6/0", 40ppf, L-80, BTC @ 2,746' Cmt to surf - CMT w/329 sx 10.7 ppg (lead) + 327 sx 15.9 ppg (tail) Kick-0ff point ~ 3000' (Max dev = 24 deg, DLS = 4.5 deg/100 R) Hold angle ~ 23 deg, 3550-4100 Drop angle at 4100' Vertical ~ 4850' Inhibited 9.8 ppg KCI-NaCI Brine 3'/:, 9.3 ppf, EUE 8rd-mod, L-80 tubing TOC @ 7050' (USIT log) 3.5" x 1" KBUG-MW/EKED D., BEK Side Pocket Mandrel ~ 7965' BST Pressure Gauge Mandrels @ 8,144', 8,054' 8-1 /2" Hole Promote Surface Read Out Pressure Gauges @ 8,256' USIT shows very poor cmtbond Behind the 4'/" liner' PBTD after dropping gums = 877T 6-1/8" Hole Camco 2.813-2.750 XN profile nipple @ 8,223' c/w PXN ~ Baker G-36 seal assemby • Baker 7x4 Y: Lnr Hngr c/mr ZXP Packer and 10' PBR ~ 8,308' X-over, 2 7/8" tbg (2 jts + 3 pups), flow sub @8401, and REG @8437' 7", 26ppf, L-80, BTC-mod ~ 8,501' - cmt w/ 52.3 bbl 13.0 ppg (lead) +34.7 bbl 15.8 ppg (tail) Perfs (6 JSPF with 2-112" scallop gun w/11g HMX millennium charges) 8557 - 8575' Stim sleeves (85606, 8572-75) 8590 -8655' Stim Sleeves (8594-8606, 8616-28, 8638-50) Dropped TCP pert gun (gun assembly 218 ft + 10 foot bar 4-112", 12.60ppf, L-80, IBT{rrod, Liner 8308-9096' PBTD = 9010' MD Cmt w/ 30 bbl 12.0 ppg cemcrete TD = 9100' MD, 9014' TVD Altamura No. 1 Well Schematic Proposed Final Abandonment Condition 20" Hole Cement in 9 5!8" x 7" annulus and 7" casing from 195' to surtace - 3'/:" tubing stub at 200', control and injection lines cut at 200' 16", 65ppf, H-40 ~ 150' Cmt to surf SS control line for injection sub and SCSSV 3.5" TRM-4E SCSSV 3HSS-1247 2.81 X-nip @ 1539' (closed) B/ Permafrost Cd) 649' 9 5/8" x 7" Freeze protected w/ 62 bbls Diesel 7" x 3'/i" Freeze protected w 63 bbls Diesel 3'/z" Freeze protected w/ 38 bbls Diesel - Camco 3.5"x1" KBUG-MW/DM.BK-5 Mandrel ~ 2640' Hole Remove all diesel 9.8 ppg kill weight NaCI bring in tubing and casing Inhibited 9.8 ppg KCI-NaCI Brine Nova Injection sub @ 2,729' 9-s/.", 40ppf, L-80, BTC @ 2,746' Cmt to surf - CMT w/329 sx 10.7 ppg (lead) + 327 sx 15.9 ppg (tail) Kick-0ft point @3000' (Max dev = 24 deg, DLS = 4.5 deg/100 ft) Hold angle @ 23 deg, 3550-4100 Drop angle at 4100' Vertical ~ 4850' 3'/, 9.3 ppf, EUE 8rd-mod, L-80 tubing TOC ~ 7050' (USIT log) 3.5" x 1" KBUG-MW/EKED D., BEK Side Pocket Mandrel @ 7965' BST Pressure Gauge Mandrels ~ 8,144', 8,054' 8-1/2" Hole Camco 2.813-2.750 XN profile nipple ~ 8,223' c/w PXN Baker G-36 seal assembN Promore Surface Read Out Pressure Gauges @ 8,256' Cement plug in 4 Y:" casing from 8760' to USIT shows very poor cmt bond Behind the 4'/z" liner PBTD after dropping guns = 8777' Baker 7x4'/: Lnr Hngr c/w ZXP Packer and 10' PBR @ 8,308' -0ver, 2 718" tbg (2 jts + 3 pups), flow sub @8401, and REG @8437' 7", 26ppf, L-80, BTC-mod ~ 8,501' - cmt w/ 52.3 bbl 13.0 ppg (lead) +34.7 bbl 15.8 ppg (tail) Perfs (6 JSPF with 2-1/2" scallop gun w/11g HMX millennium charges) 8557 - 8575' Stim sleeves (8560-66, 8572-75) 8590 - 8655' Stim Sleeves (8594-8606, 8616-28, 8638-50) Dropped TCP pert gun (gun assembly 218 ft + 10 foot bar 6-1/8" Hole a-1/2", 12.60ppf, L-80, IBT-mod, Liner 8308-9096' PBTD =9010' MD Cmt w/ 30 bbl 12.0 ppg cemcrete TD = 9100' MD, 9014' TVD Page 1 of 3i • Maunder, Thomas E (DOA) From: Jesse Mohrbacher [jesse@fairweather.com] Sent: Tuesday, March 18, 2008 4:21 PM To: Maunder, Thomas E (DOA) Cc: Alaska Supply Chain Mgmt; tzelenka@blm.gov; Mike Flynn; Bill Penrose Subject: RE: Altamura #1 (202-010) P&A Attachments: Altamura TUBEMOVE Summary jm21.xls Dear Mr. Maunder, With regard to your questions on the Altamura #1 P&A we offer the following discussion. After servicing the wellhead, we will determine if the well is capable of injection at sufficient rates to permit a squeeze of the perforations through the existing packer. Baker has run the attached tubing movement calculations for the well to establish safe injection conditions. During initial breakdown, we anticipate the formation will breakdown at about 6850 to 7850 psi bhp which will equate to 4100 psi maximum surface pressure with. 8.4 ppg equivalent wt fluid in the tubing (the tubing contains 4367f' of diesel). Tubing movement for this procedure is acceptable and we can safely go up to 5000 psi on the tubing with 1000 psi on the 7" x 3.5" annulus to establish injection rates. If injection rates are acceptable, the tubing would be displaced with 9.8 ppg kill weight non freezing brine prior to cementing. This action will reduce surface injection pressure by about 625 psi due to the bullheading of the diesel column down the tubing and into the perforations. For this procedure and the cementing below, we would place 2500 psi on the tubing/casing annulus. During cementing, a maximum 5000 psi surface pressure will deliver approximately 9360 psi formation pressure which is 1500 psi over the highest anticipated fracture pressure. Thus, the ability during the cement job to raise the surface injection pressure to 5000 psi should provide sufficient pressure to breakdown the formation and put the desired amount of cement away. The 7 bbl cement squeeze plug is sufficient volume to fill the 4.5" casing from the packer to 100 feet below the base of the perforated interval In the event that the cement locked up when hitting the perforations and could not be put away with 5000 psi surface pressure and it was determined that the squeeze job was not adequate to properly plug the perforations, the 3.5" tubing could be perforated and a balanced plug set in the 3.5" tubing and the 3.5"x7" annulus. In this situation, the TOC of cement in the tubing would be well below the TOC behind the 7" casing leaving plenty of room to set a plug to seal off the entire wellbore below. To conduct the above operations, we would need to revise our well procedure slightly to raise the surface test pressure for the tubing and surface equipment to 5000 psi. Also please note that I miscalculated the displacement volume for the cement job and instead of 12$.7 bbl cement postflush, it would be 72.2 bbl to leave the TOC in the 3.5" tubing at 8300'. Please contact me at your earliest convenience with any questions or comments on these issues. Regards, 3/18/2008 • Jesse Mohrbacher Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, AK 99507 907-258-344b 907-343-0320 direct 907-258-5557 fax. -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 12, 2008 3:33 PM To: Jesse Mohrbacher Subject: RE: Altimura #1 (202-010) P&A Page 2 of~, Jesse, Do you have a contingency if the perforated interval were to "lock up" while you are pumping? I am not sure how likely that might be. Look forward to your messages. Tom From: Jesse Mohrbacher [mailto:jesse@fairweather.com] Sent: Wednesday, March 12, 2008 3:29 PM To: Maunder, Thomas E (DOA) Subject: RE: Altimura #1 (202-010) P&A Tom I also miscalculated the displacement volume, used the wrong capacity. I will address your question and get back to you. Thanks Jesse Mohrbacher Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, AK 99507 907-258-3446 907-343-0320 direct 907-258-5557 fax -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 12, 2008 3:27 PM To: Alaska.DrillingOpsMgr Cc: Jesse Mohrbacher Subject: Altimura #1 (202-010) P&A Fred, Chuck and Jesse, I am reviewing the sundry for P&A and have a question. The cement volume planned for the deep plug is the calculated liner volume. Will XS cement be employed to squeeze some away? 3/18/2008 CONDITION = lYft$E2l€ t1~3~'(€ ~O~~9f1OE1S Surface Bottomhole SURF. PRES. Tubin Annulus :3U 2'C+`~ (Psi) U f1 FLUID WEIGHTS (Ibs/ Tubing Annulus Bottom Section 4,!ifJ :;+, ~£? FORCE (Ibs) STRESS (psi) Top -69120 26685 Bottom 9930 0 CONDITION = ~.i~~~3d~~7V~~~E Surface Bottomhole SURF. PRES. Tubing Annulus E-~f ;ii3U (psi) K2si~'L' LGTH. CHANGE(in) Piston Buckling Ballooning Temperature TOTAL Bottom Section -54.44 -17.11 -22.18 7.04 -86.69 TOTAL -54.44 -17.11 -22.18 7.04 -86.69 FLUID WEIGHTS (Ibs/ Tubing Annulus Bottom Section 8.4~' 3.iU CONDITION = €t3,~E:C.#: '€ft~3 ~S(t7€ '9.~5 ~€?i) ~f"€t3~* Surface Bottomhole SURF. PRES. Tubing Annulus FLUID WEIGHTS (Ibs/ Tubing Annulus Bottom Section ~s.3£~ 9.fri; MOVEMENT IF PERMITED (in -86.69 FORCE Ibs) STRESS si To -26956 27088 Bottom 52094 54942 LGTH. CHANGE in Piston Bucklin Ballooning Tem erature TOTAL Bottom Section -47.57 -8.35 -9.53 -15.84 -81.28 TOTAL -47.57 -8.35 -9.53 -15.84 -81.28 MOVEMENT IF PERMITED in) -81.28 FORCE (Ibs STRESS si) To -28228 19878 Bottom 50822 46534 • • CONDITION = i:~fri~';E~ Surface Bottomhole SURF. PRES. Tubing Annulus 6U ?€hf (psi) aU'3fJ ,23vfJ FLUID WEIGHTS (Ibs/ Tubing Annulus Bottom Section /i3,~3U ~.?<i' Estimated Avg. Fluid Column density for cement placement' LGTH. CHANGE(in) Piston Buckling Ballooning Temperature TOTAL Bottom Section -51.10 -9.66 -10.22 -29.91 -100.89 TOTAL -51.10 -9.66 -10.22 -29.91 -100.89 MOVEMENT IF PERMITED (in) •100.89 FORCE (Ibs) STRESS (psi) Top -25496 19652 Bottom 53554 50094 Page 1 of 1 Maunder, Thomas E (DOA) From: Jesse Mohrbacher [jesse@fairweather.com] Sent: Thursday, March 13, 2008 7:44 AM -~,c~ ~~Q \~ To: tzelenka@blm.gov c~'~1 Cc: Alaska.DrillingOpsMgr@anadarko.com; Maunder, Thomas E (DOA); Bill Penrose Sabject: Altamura #1 P&A Tom Z, Thanks for catching my error on displacement volume for the brine following the cement on the perforation squeeze. I inadvertently used the 4.5" liner capacity vs the tubing capacity. To leave the cement top at 8300 feet after displacement, 72.2 bbl of brine should be pumped after the cement. Also, regarding the estimated level of diesel in the 3.5" tubing, it is 4367'. I also have some questions from Tom Maunder regarding cement volumes and squeezing and will copy you on those when we respond to his questions. Please contact me with any additional questions. Thanks and Regards, ~~INED JUN ~ ~. 200$ Jesse Mohrbacher Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, AK 99507 907-258-3446 907-343-0320 direct 907-258-5557 fax 6/2/2008 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marlœr.doc Permit to Drill 2020100 MD 9100 .....'- REQUIRED INFORMATION J f ('It) Â- G U .., DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Well Name/No. ALTAMURA 1 5 (J ('LL I ") fV4v. Jv\~,z Operator ANADARKO PETROLEUM CORPORA API No. 50-103-20403-00-00 TVD 9014 - Completion Date 4/11/2002 ,-- Current Status SUSP Completion Status SUSP Mud Log Yes -~/ UIC N -----~ --- Samples No Directional Survey ..Ntr'" '/!;\. '- ~ DATA INFORMATION Types Electric or Other Logs Run: GR, RES, SONIC, NEUlDEN Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name =-eo- C ~ô955 ~pt 1- !v/ i Rpt CR( ,æ-- C j ~ vrOg U'Og tró'g L-Ø" D i ~Ð C L.'1"f454 Pds \-"'12235 Interval OH / Start Stop CH Received Comments 8557 8722 Case 8/5/2002 --o'igital Data of , Conventional Core Analysis 8557 8722 ~ 8/5/2002 Sample preparation and petrophysical measurements report 8557 8722 ~' 8/5/2002 Industry Abstract Article. "A rapid accurate unsteady state Klinkenberg Pereameter" Biostratigraphy Report Digital Data of Final Well Report Final Well Report Formation Log Drilling Dynamics Log Log Log Run Scale Media No 1 7480 9100 ~ 9/11/2002 107 9100 Open 5/30/2002 107 9100 Open 5/30/2002 2 Col 1 107 9100 Open 5/30/2002 2 Col 1 107 9100 Open 5/30/2002 2 Col 1 107 9100 Open 5/30/2002 C~~ 0 9100 Open 1 0/15/2002 8563 8651 Case 8/5/2002 tOg '-(2235 ¡rtôímâûQn~mêstêñ¡íí!¡iI¡ Blu 1 8563 8651 Case 8/5/2002 =---ÊD C Jpg 'T2236 NêûŒøn 25 107 9100 Case 8/5/2003 --~ ~" DML-MWD Combo Log Modular Dynamic Formation Tester - Disk has individual field file data on it. Modular Dynamic Formation Tester DGR,CNP,CTN,SLD- Disk #12237 has the same information in PDF FORMAT _I DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020100 Well Name/No. ALTAMURA 1 Operator ANADARKO PETROLEUM CORPORA API No. 50-103-20403-00-00 MD 9100 TVD 9014 Completion Date 4/11/2002 Completion Status SUSP Current Status SUSP UIC N ,...rED ,Æ2237 cãŠ'~- --~------ C Jpg 25 107 9100 8/5/2003 DGR, CNP, CTN, SLD - I Disk #12236 has the same I ~~\ information in PDF format ~~.- 9100 i\.é¡;u;é 8/5/2003 Log '- " 25 Blu 107 DGR, CNP, CTN, SLD L..---t=D C Jpg ~2236 B- 25 107 9100 C~ 8/5/2003 DGR,CNP,CTN,SLD- Disk #12237 has the same information in PDF FORMAT ~, :;./' ED C Jpg ~2237 25 107 9100 I ~ 8/5/2003 DGR,CNP,CTN,SLD- Disk #12236 has the same information in PDF format 1..- ~ 25 Blu 107 9100 Cas'é 8/5/2003 DGR, CNP, CTN, SLD I C Jpg &12236 9100 1, Gasé 8/5/2003 'î=ED 25 107 Rap, DGR, EWR - Disk ! #12237 has the same i information in PDF format ----ED C Jpg 11z237 , s. -" "- - 1 - " 25 107 9100 i ~ 8/5/2003 Rap, DGR, EWR - Disk I #12236 has the same i information in PDF format í ~g &,.-aä_-.... 25 Blu 107 9100 ¡ Caæ-- 8/5/2003 Rap, DGR, EWR Ç"...~.£ D C Jpg D-2236 , e 1 e §= 1 25 107 9100; ~ 8/5/2003 Rap, DGR, EWR - Disk \ #12237 has the same \ information in PDF format --ED C Jpg 12237. '. 1 e. § - .1 25 107 9100 \ Case-' 8/5/2003 Rap, DGR, EWR - Disk "..- ."""", \ #12236 has the same I 9100 ) CjJ8e information in PDF format ~. 25 Blu 107 8/5/2003 Rap, DGR, EWR ~~-- ~. ED C Jpg lJ.2236 25 107 9100 \ C;-- 8/5/2003 Rap, DGR, EWR - Disk ! #12237 has the same I ~~ information in PDF format CftD C Jpg \..12237 25 107 91 00 Ca~ 8/5/2003 Rap, DGR, EWR - Disk ! ¡ #12236 has the same i 9100 E 815'2003 information in PDF format I J;.ø~f i 25 Blu 107 ROP, DGR, EWR I I ~Myl ~g 107 91 00 ~ 8/5/2003 Formation Lo~____-~ Well Cores/Samples Infonnation: 0 rÎÁ..M- Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020100 Well Name/No. ALTAMURA 1 Operator ANADARKO PETROLEUM CORPORA API No. 50-103-20403-00-00 MD 9100 TVD 9014 Completion Date 4/11/2002 Completion Status SUSP Current Status SUSP UIC N Core Chips ,-' 8545 8722 1088 Cores andlor Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 1/29/2002. .-.,.,..-' Cuttings 107 9100 1088 --, ADDITIONAL INFORMATION Well Cored? GJN Chips Received? G\I N ð/N Daily History Received? (bN Q/N .~----""'- Formation Tops Analysis Received? -----~-- ---- -~--- Comments: Compliance Reviewed By: ~ Date: - /0 r1vì ~~ ".-=~, .(' il ao~OJO An..d..rI(p~ Petroleum Corporation Additional, Updated, or Replacement Information RECORD OF SHIPMENT DATE: October 14, 2002 TO: Ms. Bren Mciver Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 FROM: Tommy Thompson Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 99503 (907) 273-6302 ( X) Enclosed ( ) Under separate cover (X ) Via Courier Subject: Anadarko - Altamura #1, BLM Permit AA-081736/3160, NPRA Alaska API: 50-103-20403-00 Quantity Media Type I D~scr!i.ption 1 Floppy disk Deviation Survey Report (.pdf and .txt) D~ q,Cú cc: NOTE: Please verify and acknowledge receipt. by signing and returning a copy of this transmittal to the above address or fax to 907.563.9479. SignedébY: ',- jJ , I n C\ ~ )A~~OQr '" J Received by: Date: 10/14/02 Date: Remarks: RECEIVED OCT 1 5 2002 Alaske Œi & Gas Cons. Commi88ion AnchOflge ( ß~ V'. ~~7c' / ~\.\c An.. d.. rI(p 2 Petroleum Corporation aœ-o/O Additional, Updated, or Replacement Information RECORD OF SHIPMENT DATE: September 10, 2002 (prior information sent July 11, 2002 / August 2, 2002) TO: Mr. Thomas Maunder, PE Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 FROM: Tommy Thompson Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 99503 (907) 273-6302 ( X) Enclosed ( ) Under separate cover ( ) Via Courier Subject: End of Well Report for Anadarko Altamura #1, BlM Permit AA-081736/3160, NPRA Alaska API: 50-103-20403-00 Quantity Media Type 1 Report Description Biostratigraphy cc: NOTE: Please verify and acknowledqe receipt, by siqninq and returninq a copy of this transmittal to the above address or fax to 907-563-9479. Signed by: 6 "\:'~>----- ReceiV~ y ~0-). ",i Date: 9/10/02 Date: Remarks: ('i.. I 'j \~ - -:.;;:. ~!I ~ "'f'q..~, :~08-o10 An..d..rI(p~ Petroleum Corporation Additio~al, Updated, or Replacement Information RECORD OF SHIPMENT DATE: August 2,2002 (prior information sent July 11,2002) TO: Mr. Thomas Maunder, PE Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 10(] Anchorage, Alaska 99501 ( X) Enclosed ( ) Under separate cover Subject: End of Well Report for Anadarko Altamura #1 ~ BlM Permit AA-081736/3160, NPRA Alaskf FROM: Tommy Thompson Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 9950:3 (907) 273-6302 ( ) Via Courier API: 50-103-20403-00 Quantity Media Type 1 CD 1 Report 1 Article DescriPtion). . Conventional Core Analysis (with Digital Core Photography)-Rpt. #HOU-020315 Sampling Criteria Industry Abstract cc: ¡w,u ~~J'I! \;'t'II,,~\ 'if: ).:::: i~ .:"1 ,j ".) ,g t.;on:~~, (Ii \..'~ t)~ NOTE: Please verify and acknowledqe receipt. bv siQninQ and returninq a COpy of this transmittal to the above address or fax to 907-563-9479. Sign~d by: ~~of\';:711 J Received bY~~~ (~ Remarks: t~ J¡'JJJ.J'Ur~J ( Date: ~L-/oL- ~... A v¡ À (J a ).... Date: lJ{'t. r~ ~ ""'- ~ c ~ ( Ví!t II P(~. ÀlJkOi A [ore Lab f PETRDLEUM SERVICES f f f f l f f. [ f [ [ ( ( PETROLEUM SERVICES ðö9~ClO COMPLETE PETROGRAPHIC ANALYSIS Y OF SELECTED CORE SAMPLES FROM THE ANADARKO PETROLEUM ALTAMURA WELL ALASKA Prepared for Anadarko Petroleum Corporation The Woodlands, Texas I File: 020315G I \.~ (,. ~::' CONFIDENTIAL April, 2002 ,,' The anelytical results, opinions or interpretations contained In this report are besed upon information and material supplied by the client for whose exclusive and confidential use this report has been made. The analytical results, opinions or Interpretations expressed represent the best Judgment of Core Laboratories. Core Laboratories, however, makes no warranty or representation, express or Implied, of any type, and expressly disclaims same as to the productivity, proper operations or profitableness of any oli, gas, coal or other minerai, property, well or sand in connection with which such report Is used or relied upon for any reason whatsoever. This report shall not be reproduced, In whole or In part, without the written approval of Core Laboratories. ( t f I I I I I ( ( I ( r I I I I I I A [ore Lab PETROLEUM SERVICES (' ( Petroleum Services 6316 Windfern Houston, Texas 77040 USA Tel: 713-328-2673 Fax: 713-328-2170 WINW.corelab.com April 23, 2002 Mr. Don Kilgore Anadarko Petroleum Corporation 1201 Lake Robbins Drive The Woodlands, TX 77380 RE: Complete Petrographic Analysis with thin section petrography, XRD, and SEM Altamura Well Alaska Dear Mr. Kilgore: This letter presents the results of complete petrographic analysis of three (3) core samples from the Altamura Well from Alaska. Thin section petrography, X-ray diffraction (XRD) analysis and scanning electron microscopy (SEM) were performed on all three samples. XRD data are presented in Table 1 with thin section and SEM photomicrographs found in Plates 1-3 at the end of the report. The objectives of this study were to (1) determine texture, mineralogy, pore-filling constituents, pore types, and diagenetic features, and (2) evaluate the reservoir potential of the sandstones with respect to porosity development/preservation. I n order to meet these objectives, the following analytical program was undertaken: . The thin section samples were impregnated with blue-dyed epoxy to highlight pore space, and subsequently ground and polished to a thickness of 30 microns. The samples were then stained with Alizarin Red-S to highlight the calcite-bearing constituents and potassium ferricyanide, which adds a blue stain to iron-bearing calcite and dolomite. Thin section photomicrographs are presented in Plates 1 through 3. . SEM analysis was conducted on freshly broken rock surfaces to identify pore system properties and the types and modes of occurrence of pore-filling constituents. Semi- quantitative elemental analyses of selected phases observed during the SEM study were obtained through the use of an interfaced Kevex Energy Dispersive X-ray (EDS) unit. SEM photomicrographs are presented in Plates 1 through 3. . X-ray diffraction analysis was used to obtain semiquantitative mineralogical data. Rock samples were ground to 12 microns to ensure homogeneity and analyzed through standard XRD procedures. The <4 micron size-fraction of the samples was analyzed separately to determine the relative proportions of clay mineral species. XRD data are provided in Table 1. The three samples are moderately well to well sorted, lower very fine-grained sandstones. The vast majority of the framework grains range from subangular to subrounded in shape. Quartz and rock fragments are the principal framework CLB I....'.",. NYSE I ( ( I I I [ I I [ ( [ [ - ( ,( ( I I I constituents, with sig( antly fewer feldspar grains and ac( "'¡ory minerals. These samples were not stained for feldspar differentiation. Many of the feldspars do not show distinct twinning, but XRD shows that plagioclase is much more common than K- feldspar. Most of the rock fragments are chert, volcanic and sedimentary rock fragments. Glauconite is a significant accessory grain occurring in minor amounts in all samples. These sandstones classify as sublitharenites. All of these sandstones are heavily cemented. Authigenic clay, Fe-dolomite, and quartz overgrowths are the principal cementing agents. Siderite is particularly abundant (34 weight percent) in the sample from 8593.7 feet where it has replaced detrital clay matrix. Pyrite and titanium oxide are found in trace amounts. SEM and XRD analyses indicate that chlorite and mixed-layer illite/smectite are the most common authigenic clays occurring in both grain-coating and pore-filling modes. Detrital clay matrix is moderate to common in the samples from 8570.8 and 8593.7 feet, occurring in distinct laminae and as dispersed clay matrix respectively. Distinct bioturbation is evident in these two samples as well. Minor to trace amounts of pseudomatrix are present, as deformed argillaceous grains have been deformed around the more rigid framework grains. Compaction, cementation and detrital clay matrix have significantly reduced pore volume and interconnectivity in these sandstones. Most of the measured pore volume is dominated by ineffective micropores. In the deepest sample, intergranular porosity and secondary dissolution pores are slightly more common than in the other two samples, but these pores are still small and poorly interconnected (Plate 3). The slight increase in porosity corresponds to a liquid permeability of 0.021 md., compared to liquid permeability values less than 0.001 for the other two samples. Core Laboratories Job Number 020315G was assigned to this study. Any communications regarding this report should refer to this job number. One copy of the report has been forwarded to you and two (2) copies have been forwarded to Mike Beattie at this time. Additional copies of this report may be obtained for reproduction and assembly costs by contacting Core Laboratories. Please feel free to contact me at 713-328-2573 or dharville@corelab.com if you have any questions or comments concerning this report. Sincerely, /11 j Donald G. Harvill~-' Manager, Reservoir Geology Group ~ ~ - ~ ,..-..-. ~ - ~ ,-- ~ ---. - -"" - - Anadarko Petroleum Altamura Well TABLE 1. Mineralogy Determined by X-ray Diffraction File:020315G Whole Rock Mineralogy Relative Clay Abundance (Weight 0/0) (Normalized to 100%) Depth Quartz Plagioclase Calcite Fe-Dolomite Siderite Pyrite Total Clay Illite/Smectite * Illite & Mica Chlorite (feet) 8570.8 73 4 1 5 Tr 1 16 45 27 28 8593.7 45 4 1 2 34 0 14 37 24 39 -~ 8640.8 82 2 1 2 2 1 10 32 20 48 * Mixed-Layer Illite/Smectite Contains 25-30% Smectite Layers Tr = Trace ~ Core Lab Petroleum Services I ( THIN SECTION PETROGM ~Y I Company: Well: Location: Depth (ft): Anadarko Petroleum Altamura Well Alaska 8570.8 I I r I ( [ I ( 20x 1,Omm ° [ Plate 1 B r [ ( I [ I 100x 0 O.2mm I A [ore Lab PETRDLEUK SERVICES Trace «1%) Minor (1-5%) Moderate (5-10%) Common (10-20%) Abundant (>20%) *permeability measured at 2750 psi NOB Porosity (%)* Liquid Penn. (md)* Grain density (glee) n/a <0.001 nla Rock type Classification (Folk) Average grain size Sorting Compaction Grain shape Sedimentary structures Rock Name and Texture Sandstone Subl itharenite 80 microns Moderately well Strong/moderate Subangular-subrounded Laminated, bioturbated Detrital grains Monocrystalline quartz Polycrystalline quartz K-feldspar Plagioclase feldspar Chert Volcanic rock frags. Metamorphic rock frags. Sedimentary rock frags. Mica Glauconite Matrix Cements Quartz overgrowths Feldspar overgrowths Ferroan dolomite Ferroan calcite Pyrite Titanium oxide lIIitic clay Chlorite Kaolinite Pore types Intergranular Secondary intragranular Moldic/vuggy Microporosity Abundant Trace Minor Minor Minor Trace Minor Trace Minor Moderate Trace Trace Moderate Trace Trace Trace Minor Trace Trace Trace Common Photomicrograph Captions Intergranular porosity has been greatly reduced in thi sample by compaction and cementation. Pore-fillir chlorite and illiticclay is common. Much of the clay ma be detrital as evidenced by the compressed textul and micaceous and organic-rich composition. On limited amounts of open pores (red arrow) are presen with micropores more common than macropore~ Accessory grains of glauconite (G) and mica are note I l.,ANNING ELECTRON MICROi JPV I Company: Well: Location: Depth (ft): Anadarko Petroleum Altamura Well Alaska 8570.8 I I Plate 1 C r r I I ( I 'HARUILLE'85?88A.TIF 85?8.8 ~ee~ Log: 283~5 Mag=~88 FOU=988.888888 28.8KU 4- 5-2882 8~:48pM 288uM 1 Plate 1 D [- [~ [ 1- 1 ( 'HARUILLE'85788C.TIF 85?8.8 ~ee~ Log: 283~5 Mag=888 FOU=~~2.588888 28.8KU 4- 5-2882 8~:42PM 28.8uM I . Core Lab PETRDLEUK SERVICES Trace «1%) Minor (1-5%) Moderate (5-10%) Common (10-20%) Abundant (>20%) * permeability measured at 2750 psi NOB I Porosity (%)* Liquid perm.(md)* Grain density (glee) nffi <0.001 n/a Rock type Classification (Folk) Average grain size Sorti ng Rock Name and Texture Sandstone Sublitharenite 80 microns Moderately well Intergranular Secondary intragranular Moldiclvuggy Microporosity Pore types Trace Trace Trace Common Photomicrograph Captions Plate 1 C shows a moderately sorted, tightly compacted, very fine-grained sandstone, in which intergranular areas have been completely reduced by compaction, detrital matrix, and the precipitation of quartz, Fe-dolomite and clay cements. Plate 1 D shows a close-up view of pore-filling, iron-rich illitic or illite/smectite (liS) clay. Note the matted/micaceous texture of the clay denoting a detrital origin. A patch of pyrite (Py) is also present. f ( THIN SECTION PETROGRA( Y ( Company: Well: Location: Depth (ft): Anadarko Petroleum Altamura Well Alaska 8593.7 I Plate 2A r ~"':","~':1r,i'.~" '..";:'."~"" ;..~..,. ".. -' .~.~........ ~ ,~ "-'. ~.:~. -.. ..' - ... -..-. I ~ .;e8. . J '!..~., .' .": ' ~ .- .,It,.,,. ~ . . ..... . - '. '.., " ' .,. r "..:;.. .........' , i',,' ~~'.' ",' ~ ;'::.'~:;; -,;~..." ,~-~;.." :-..:- ~:~~f..:"~~,~:~. ;:~'~"-- '~;;!:f ,t'../¡:;~;f;'" ;~'"\.' " - ~~ '..'':'',. -... :-_1.' 'i' ,... ',' '~- - - . .-,- ---.. ':.1;";; ." ~ ,.~1" ;~ .. ~ ...-~ ..~,~...... - ~ ~:"::~---~:.";":; ),~ ...," .-; ;~~~,' ~.t:.,.:,..,..,:~' - ~ :'~O:.~'..:j¿':':-.'-"'::':',~" ;:¡"~',.....''''' < .'-~'" "..-.. -4' .,.\--, '.. .~' ,~,.¡.."-,,,,~tlr"""""'" ", ~ .._~!:, - '".'. .' -...:_~ ... "....,.4''''- .-. l1li"'" -, .~....... .... .-,.. I"~ -4. ',,.." .~... -..... ~.~. 4' ~~:~~".: -,: ¡..- ." .,';' ~', '~t .. ..(:. ~. 'ò: ~,-:': '-''''';I;';'~ '."'"..''' - .:~~~'."'\;' " . 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IP\:"'~~'.~,~~. .,~~. ?',...~-~.~~. ':': -,-'... '. ~: ",. .",,-.... ","'. . ....... ...,.....-. :":r,". -: ",11!""'- ~ ... --. . ... ',..."- ". .""...-.." . .... -',' .;-::t., '.. . ,'. "!.,', .'.~''''~''' ,.' ",,,,,,,,,¡,:,,.i', '~'''' ""r~ ...~!"-..:::r!'J-. .-' ~....._"...." 4 - ,. .' . --~.i~..~,':" '~.' \,: -.."-0'"..''' -,'I~- e. ro4W''':;;. I. ',..l._..;--_~...\-::.,. ~..--::...t,;. ~", - ,...','~ .' OIfI'-":''''''''.."--=:;oo",,,~~, -t ,. , ~.- ~ ;;.~.¡..",. . :;:.... <... ?o.~þ ;If,"'" ",t ,..". .". .-..J'" '.;....:,,_.~~.~:...~--*, ... ''''...: ."'" ~-k"'I.-"~~":.1i"" .. .,"". .,....-~~-- .1'''-. -,' .. --... ~' I :--:~; ;>..:.-IÌ:\~""i~ ~ ~.I*,;!'.~~i.' ,,~-,..~.':.t .,~" ,"",,"" 'Jo: '~"".",_....-.....' ,..''!; ..--: ':,::..II._;-(,,~;,"'}~..1l:,.:.'... "~.1~:"'.'- ,\-tI';~^~~j. <$1.., ~..J:¡;;~~'¿;, ~~.~~,..~.. .,., ~ .," «:.¡.. .....~ ,.." , ,; . - ,... ~., ~ "" '"., ~ -~JIt "--".', .t"~. .. ,"'...;,.¡~,;' ~. ~...":' ",' ~ .~.. ':."',".."'-'9..~:.';.-:tÇ~,'...~.....-., - .'."f.i~$ - "...-,.'Jt -~.~, ... ".._71"", "" r1'to~.;.~' :~ .- ~' ..~ 'tit ..- ."",...-... . ,,' .... ~ . -'.. ...,' ~...._...- .,,~ .,-... - # -.:: '!-. ~"'.-r...¡.: . '. - ~C't¡........ ": ,. ..-. . ,r., '. ' ~'t~. ... '4 '.:.. .~ ".;., ... ,. ,,¡ , ' ,~. ,""..: . r' ......' : . '1fß-".. .~... ,,~\'-:.~.~,,: ,.....,~.:,. "" . "'i.". ~....~ -,," !..~~ ~ ,. . J-"'."'~" "~fI¡, ...~,...~..~ ':l",-..$~ I .~.\.::. -...: ~..:.~..-....,. '"," ,'- .:';.~ .',': :... ~. ~~...~ "....... ~ ,....~~ ~~ :";'L~;. .-:"~:'l;" '-.'''' ~. ~.......,}=~ ,~:. .,.. .,('~~:"~'~:':~. .,: ........:~ ',.,...'-- "'- ,JiI' .' of4iIP....f ~q. " .. I.'.¡;¡' oI..~.,..,\..". -' ''''A''' 't. "i3' ~,,,~.... -~.."..~-r.~.' ~,"" t'. .,:..."" ....,P'--=, ~ ..",.." ':..'''''' ...,......-"J............ ..r .~... ~L >.»;1;,....,,': - ..,--~,,:~:~" ...,~.~\ ...'. .;..-_..'.~~....~ >:'~~:)'J.';'~",'.:-,':"<.;!I:l ~i:-.'-~. '-:«-:;;, :_~~ ~ '-- ..J' - ~." ,"""~~'~ ,..¡ :".-., :--, ..- '~:: ~ ¿it ~ -;'. ,,~, .~.. - ",.t .;- " ~,- '.- .4i\ -..:'" ~. ...- -'J... ,..'II.. ".: ...~ ..:r:~ ;...... .-.: ,". "fi . .. .. ...... '...... . .~.. ....,....., ~ . ,,~~,..... -¡' "~...:,~"..~.. '"..' ~'Ilè:',.~:~,"- ,~..:t ._0. '.I,.,"',,'r~. ".''i,'., ;.."'~o-." ~~..~: ,?:.....:... ':;~~.ì'~-:"::".:~.~ffl' : ~ ~!.,~"'1l-:~~,,:'.:._"!':: z--: .::...!:.:-,"::" "'-(':' j'. ..Þ .:-..": ..... ,1i~~.....~ II'" ~,.."f,~~... ...... Y.J~.~. Iril.l- """,,- "'. ' "".,.,,,..:-. .. .. ~',... .(¡:~~+:lJ~:~~~~~~~ (~{-;::"~-i~~4 -::. :-~~1;'7':.f=-fi.:;~ "~~~~;:,, ~~'~~:~~~~:~~:'I ¡~J.-t~:~:: r r [ I I 0 1.0mm 20x I Plate 28 I [ r ( [ 0 100x O.2mm A Core Lab PETRDLEUK SERVICES Trace «1%) Minor (1-5%) Moderate (5-10%) Common (10-20%) Abundant (>20%) *permeability measured at 2750 psi NOB Porosity (%)* Liquid Penn. (md)* Grain density (glee) n/a <0.001 nla Rock type Classification (Folk) Average grain size Sorting Compaction Grain shape Sedimentary structures Rock Name and Texture Sandstone Sublitharenite 80 microns Well Strong/moderate Subangular-subrounded Laminated, bioturbated Detrital grains Monocrystalline quartz Polycrystalline quartz K-feldspar Plagioclase feldspar Chert Volcanic rock frags. Metamorphic rock frags. Sedimentary rock frags. Mica Glauconite Matrix Cements Quartz overgrowths Feldspar overgrowths Ferroan dolomite Siderite Pyrite Titanium oxide "'itic clay Chlorite Kaolinite Pore types Intergranular Secondary intragranular Moldic/vuggy Microporosity Abundant Trace Minor Minor Minor Trace Minor Trace Minor Moderate Trace Trace Moderate Abundant Trace Trace Trace Minor Trace Trace Trace Common Photomicrograph Captions Intergranular porosity has been greatly reduced in thi: sample by compaction and clay/siderite-replace matrix. Pore-filling chlorite and illitic clay is common Much of the clay has been replaced by siderite Micropores (arrows) are the most prevalent pore tYPI in this sample. Accessory grains of glauconite (G) an noted. t JANNING ELECTRON MICRO~ JPV I Company: Well: Location: Depth {ft}: Anadarko Petroleum Altamura Well Alaska 8593.7 I I Plate 2C r r r [ [ I 'HARUILLE'85937A.TIF 8593.7 ~ee~ Log: 28315 Mag=108 FOU=900.080000 20.0KU 4- 5-2002 02:29PM 208uM . I Plate 2D [ [ ( [ 'HARUILLE'85937C.TIF 8593.7 ~ee~ Log: 28315 Mag=1588 FOU=60.008000 20.0KU 4- 5-2002 02:27PM 18.8uM A [ore Lab PETROLEUM SERVICES Trace «1%) Minor (1-5%) Moderate (5-10%) Common (10-20%) Abundant (>20%) * permeability measured at 2750 psi NOB Porosity (%)* Liquid perm.(md)* Grain density (glee) nJa <0.001 nla Rock type Classification (Folk) Average grain size Sorting Rock Name and Texture Sandstone Sublitharenite 80 microns Well Intergranular Secondary intragranular Moldic/vuggy Microporosity Pore types Trace Trace Trace Common Photomicrograph Captions Plate 2C shows a well sorted, tightly compacted, very fine-grained sandstone, in which primary pores have been completely reduced by detrital matrix and quartz, Fe-dolomite and clay cements. Plate 2D shows a close-up view of grain-coating illite/smectite (liS) clay. Platy iron-rich authigenic chlorite (Chi) fills pores. Siderite (8), 34 weight percent according to XRD, is often associated with clay in this sample. f [ Company: Well: ( Location: Depth (ft): I ( ( I ( ( I ( I I I (' .( THIN SECTION PETROGRAI, Anadarko Petroleum Altamura Well Alaska 8640.8 20x 0 1,Omm ( I 0 200x O.1mm ( A Core Lab PETROLEUK SERVICES Trace «1%) Minor (1-5%) Moderate (5-10%) Common (10-20%) Abundant (>20%) *permeability measured at 2750 psi NOB ., Porosity (%)* Liquid Perm. (md)* Grain density (glee) n/a 0.021 nla Rock type Classification (Folk) Average grain size Sorting Compaction Grain shape Sedimentary structures Rock Name and Texture Sandstone Subl itharenite 80 microns Well Strong/moderate Subangular -subrounded Laminated, bioturbated Detrital grains Monocrystalline quartz Polycrystalline quartz K-feldspar Plagioclase feldspar Chert Volcanic rock frags. Metamorphic rock frags. Sedimentary rock frags. Mica Glauconite Matrix Cements Quartz overgrowths Feldspar overgrowths Ferroan dolomite Siderite Pyrite Titanium oxide lIIitic clay Chlorite Kaolinite Pore types Intergranular Secondary intragranular Moldic/vuggy Microporosity Abundant Trace Minor Minor Minor Trace Minor Trace Minor Trace Minor Trace Moderate Minor Trace Trace Trace Minor Minor Trace/minor Trace Common Photomicrograph Captions Intergranular porosity has been greatly reduced in this sample by compaction and cementation. Pore-filling chlorite clay is common. Porosity (red arrows) is slightly more common in this sample compared to the previous ones, but is still composed of small intergranular pores which are poorly interconnected. Micropores are more common than open macropores. Accessory grains of glauconite (G) are noted. l~ANNING ELECTRON MICRO! ~py 1 Company: Well: Location: Depth (ft): Anadarko Petroleum Altamura Well Alaska 8640.8 I I Plate 3C I [ [ [ [ [ 'HARUILLE'86488A.TIF 8648.8 ~ee~ Log: 283~5 Mag=~88 FOU=988.888888 28.8KU 4- 5-2882 82:38PM 288uM [ Plate 3D I [ [ [ [ 'HARUILLE'86488C.TIF 8648.8 ~ee~ Log: 283~5 Mag=688 FOU=~58.888888 28.8HU 4- 5-2082 82:48PM 28.8uM A [ore Lab PETRDLEUK SERVICES Trace «1%) Minor (1-5%) Moderate (5-10%) Common (10-20%) Abundant (>20%) * permeability measured at 2750 psi NOS Porosity (%)* Liquid perm.(md)* Grain density (glee) n/a 0.021 nla Rock type Classification (Folk) Average grain size Sorting Rock Name and Texture Sandstone Sublitharenite 80 microns Well Intergranular Secondary intragranular Moldic/vuggy Microporosity Pore types Minor Minor/trace Trace Common Photomicrograph Captions Plate 3C shows a well sorted, tightly compacted, very fine-grained sandstone, in which primary pores have been completely reduced by compaction, and the precipitation of quartz, Fe-dolomite and clay cements. Plate 3D shows a close-up view of pore- filling quartz overgrowths (Q), iron-rich chlorite (Chi), clay-replacing siderite (S), and trace amounts of framboidal pyrite (Py). (, ( ~oa-o I a SAMPLE PREPARATION & PETROPHYSICAL MEASUREMENTS CORE EXTRUSION: Upon arrival at the lab, the cores were extruded from the aluminum liner sections onto a core layout table. The cores were wiped to remove excess drilling fluid, and labeled with depth marks and orientation stripes. CORE GAMMA: The natural total gamma radiation count of the core was recorded as a function of depth and was recorded in API units of gamma activity. The instrument was calibrated against API standards and adjusted for background. The core gamma log is presented in this report. CORE SLABBING: A band saw was used to cut the cores into 1/3-2/3 sections (dry cut). The 2/3 section was preserved in Saran wrap (6 layers) and aluminum foil (3-layers). CORE PHOTOGRAPHY: The 1/3 section of the slabbed core was photographed under white light (dry and wet), and U.V. light conditions. A "box" format, which displays an entire slab box in an 8 x 10 photo, was used. Digital files and hard copies containing the core photography images were previously distributed to Anadarko Petroleum Corporation. PLUG DRilliNG and TRIMMING: Conventional, Scal and vertical core plugs were drilled at points designated by Anadarko Petroleum Corporation representatives. The plugs were drilled using 4 % KCI brine as the drilling lubricant. The conventional plugs were placed overnight into a low temperature oven @ 150 0 F to drive off the water. After the overnight drying plugs were marked and submitted to the cleaning process. Scal and verti~ plug samples were faced (1 inch each side from the center point), using a diamond-facing tool to provide right circular cylinders. Trimmed ends and plugs were wrapped in several layers of Saran wrap and stored in a sealed plastic vial. Core sections were removed from the sides of the plugs holes and returned to the state of Alaska. A full inventory of the plugs and the core sections removed is included as an appendix in this report. PLUG CLEANING: The untrimmed conventional samples were batch cleaned of hydrocarbons and salts in a soxhlet extractor. Toluene was used as the refluxing solvent until clear. Samples were placed overnight into a low temperature oven, followed by batch cleaning with chloroform/methanol azeotrope. Extraction was continued until the returning solvent was clear. Samples were dried overnight in a low temperature oven and methanol was used to leach them of salts. Extraction was continued until a test of the returning solvent with AgN03 solution yielded no precipitate. Solvents were maintained at approximately 150 0 F during the extraction process. PLUG DRYING: Cleaned plugs were dried in a low temperature oven for 24 hours. At this point samples were faced using a diamond-facing tool to provide right circular cylinders. A 3/8" section from one end and %" section from the other end, were trimmed from the plug. End trims and plug samples were loaded into a humidity oven at 140 of and 40% relative humidity until weight stabilization was achieved. i (' (' GRAIN VOLUME: Direct grain volume measurements were made using a helium porosimeter. This instrument utilizes the principle of gas expansion as described by Boyle's Law. The instrument was calibrated daily and test standards were run to verify instrument accuracy. GRAIN DENSITY: Calculated grain density was obtained utilizing grain volume measurements and clean, dry sample weights. Grain density was checked against lithology standards. PLUG DIMENSIONS: Sample lengths and diameters were measured using digital metric calipers. CMS-300 PLUG ANALYSIS: (Please see references following for clarification of calculations) A. PERMEABILITY "k": Permeability was measured by flowing helium from a reference cell of known volume through the plug samples. The downstream end of the plug was maintained at atmospheric pressure. The upstream pressure was initially at 240 psig and was allowed to decay through the sample. The pressure decay vs. time was monitored and recorded digitally. The net confining stresses used for this project were 800, 1227, 1654, 2081 and 2510 psig, per electronic instructions dated April 22, 2002 as furnished by a representative of Anadarko Petroleum. 1. K-Klinkenberg: Unsteady state equations were used with time/pressure decay data to calculate the Klinkenberg slip corrected permeability at the designated net confining stresses. 2. K-air: Permeability to air at the designated net confining stresses was calculated from time/pressure decay data. B. POROSITY: A reference cell of known volume was initially pressurized with helium to approximately 240 psig. As the pressure was allowed to expand into the core sample, pressure decay was monitored. At pressure equilibrium, Boyle's Law was used to compute pore volume. Pore volume was measured at the designated net confining stress. Porosity was then calculated by using the pore volume from the CMS-30G and the grain volume from the automated porosimeter. The results of the plug analyses and average statistical data are presented in tabular format on pages 1 through 14 of this report. Graphical presentations of Permeability vs. Porosity, histograms of permeability and porosity, and depth plots of permeability, porosity and grain density are included in the Figures section. PROFILE PERMEABILITY: The Pressure - Decay Profile Permeameter was used to measure permeability on the face of the whole core. Measurements were made at approximately 0.1-ft intervals from 8561.17' to 8663.25'. The PDPK device measures permeability by flowing nitrogen gas through a portion of the sample. The nitrogen flows from a selected reference volume into the sample through a probe which seats on the sample face using an o-ring seal. The decay of the initial reference cell pressure (approximately 12 psig) was monitored vs. time. The permeability was calculated from the pressure decay/time data. A subset of 15 readings was re-measured on the slabbed surface of the core. The results of the profile permeability are presented in the figure section of this report. ii ( ( APPENDIX A: EXPLANATION OF CMS-300 TERMS "b", "Beta, and "Alpha" K:o = Kair = b = ß (Beta) = a (Alpha) = Hi = ø = ROI = ROI = Equivalent non-reactive liquid permeability, corrected for gas slippage, mD Permeability to Air, calculated using Kco and b, mD Klinkenberg slip factor, psi Forcheimer inertial resistance factor, ft-1 A factor equal to the product of Beta and Kco. This factor is employed in determining the pore level heterogeneity index, Hi. 10glO (aø/RQI) a, microns = 3.238E-9 ßKco Porosity, fraction Reservoir Quality Index, microns O.0314{K/ø)O.5 For further information please refer to: Jones, S.C.: "Two-Point Determination of Permeability and PV vs. Net Confining Stress" SEE Form~tion Fvalu~tion (March 1988) 235-241. Jones S.C.: "A Rapid Accurate Unsteady-State Klinkenberg Permeameter," Soc. Pet. Fng. J. (Oct. 1972) 383-397. Jones, S.C.: "Using the Inertial Coefficient, ß, To Characterize Heterogeneity in Reservoir Rock: SPF 1n~4~ (September 1987). Amaefule, J.O.; Kersey, D.G.; Marschall, D.M.; Powell, J.D.; Valencia, L.E.; Keelan, D.K.: "Reservoir Description: A Practical Synergistic Engineering and Geological Approach Based on Analysis of Core Data,: SPF Tp.chnic~1 ~onference (Oct. 1988) SPE 18167. iii ( (' APPENDIX B: REPORT DISTRIBUTION CORE LABORATORIES, INC. FILE NO. HOU-020315 Altamura - No.1 WELL North Slope, ALASKA FINAL REPORT Anadarko Petroleum Corporation 17001 Northchase Dr. Houston, TX 77060 Attn: Mr. Don Kilgore Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 99503 Attn: Mr. John Hartner iv I{ ,r~ " , ~Od-OJO { A Rapid Accurate Unsteady-State Klinkenberg_Permeameter STANLEY c. JONES MEMBER AIME ABSTRACT A simple, unsteady - state apparatus and appropriate theory. have been developed for measuring the Klinkenberg permeability, Klinkenberg slip factor, and Forchheimer turbulence factor of core plugs. The technique is fast and accurate and has replaced nearly all steady-state gas permeability determinations made in our laboratory, The theory of operation, capabilities and limitations of the apparatus are discussed. New data are presented for mOTe than 100 COTes, correlating slip and turbulence factor vs permeability. INTRODUCTION -.,.....' Permeability is usually measured with air at mean pressures just above 1 atm. This steady-state determination is rapid, bilt it can lead to serious errors. For example, the low-pressure air permeability of tight core often differs from its permeability to liquid or high-pressure gas by 30 to 100 percent or more. Correction factors (Klinkenberg slip factors) from correlations are available, but still, the corrected, low-pressure measurement can exhibit considerable error. These errors are avoided by determining gas permeabilities at two or three mean pressures such as 25, 50 and 100 psia, and then extrapolating to infinite pressure to obtain the equivalent liquid or Klinkenberg permeability. This method is generally reliable, but has two drawbacks - it requires tedious rate measurements with a soap bubbler or other device, and the back-pressured flow system requires several minutes to reach steady state. Typical throughputs are 8 to 12 cores per day. The desire to estimate accurately the injectivity into secondary and tertiary oil recovery prospects and to find the deliverability of very tight gas reservoirs has created a growing demand for reliable Klinkenberg permeability determinations in our laboratory. This demand made clear the need for a more rapid, yet accurate permeameter. On the premise that pressure measurements are made more conveniently and accurately than rate determinations, we developed a permeameter in which both rate and Original manuscript received in Society of Petroleum Engineers office July 26, 1971. Revised manuscript received April 6, 1972. Paper (SPE 3535) was presented at the SPE 46th Annual Fall Meeting, held in New Orleans, Oct. 3-6, 1971. @ Copyright 1972 American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. 1 Reference s given at end of paper. OCTOBER, 1972 MARATHON OIL CO. LITTLETON, COLO. pressure drop across a core can be derived from pressure measurements alone. The resulting unsteady-state instrument is fast and accurate. Transient permeability techniques have b.een discussed 1 and other unsteady-state permeameters have been built and reported,2-6 but to our knowledge the instrument described herein is the only practical one for routine measurement of Klinkenberg permeability that does not require an empirical correlation using cores of known permeability to construct calibration curves. It is also the only one from which Klinkenberg permeability, Klinkenberg slip factor and Forchheimer turbulence factor can be determined from a single run. THEORY OF OPERATION Fig. 1 shows the essentials of the unsteady-state permeameter. It consists of a tank and pressure transducer that can be pressurized with nitrogen. A core holder is attached to the tank, separated by a quick opening valve. To perform a run, the tank is charged with nitrogen to, an initial pressure of about 100 psig. If the valve at the bottom of the tank is opened, Qitrogen will flow through the core and the pressure in the tank will decline as illustrated in the inset of Fig. 1 - rapidly at first, then more and more slowly. The volumetric rate of nitrogen flow at the inlet face of the core, qo(t) , can be derived (see Appendix A) from the ideal gas law, since the compressibility factor (deviation factor) is unity for nitrogen at low pressure and room te~perature. The volumetric flow rate at any position, x, downstream from the inlet face of the core, at time t, is CEq. A-30): -Vt(l + 6f [C,g] ) dPO [t] q [X,t] = (p lx,t] + Pa) dt ........... . . . . (1) where ô and fCc,g) are correction factors that account for variable mass flow rate with position at any instant in time. The constant ô is given by: 6 = 2~LA . . . . . . , . . . . . . . . (2) 3Vt from Eq. 2, Ô is equal to two-thirds of the ratio of the pore volume of the core to the volume of the tank. Normally it is a small correction. For example, with I-in. long, I-in. diameter, 20 percent porosity 383 core, and a l,OOO-ml tank, Ô is only 0.0017. The function f(c,g), Eq. A-29, is a function of pressure and position in the core. Its value varies from 0 at the inlet end of the core to a maximum of 1.0 at the outlet end if a high injection pressure is imposed. Thus, for the above example, the maximum correction due to nonconstant mass flow rate throughout the core at any instant is less than 0.17 percent. The use of a smaller tank for the nitrogen reservoir would result in a larger correction, however. The apparent permeability of a porous medium to gas changes with gas pressure, becoming lower as the mean pressure increases. As the mean pressure becomes increasingly high, the apparent permeability approaches a value, kf, which pas been shown to be equal to the permeability of the porous medium to a nonreactive liquid.7 The phenomenon of variable apparent permeability is due to ««slip". Kundt and Warburg8 showed that, when a gas is flowing along a solid wall, the layer of gas next to the surface is in motion with respect to the solid surface. This slip results in a lower pressure gradient for a given rate of flow in a capillary tube than would be expected from Poiseuille's formula. Klinkenberg later showed that the same phenomenon occurs in porous plugs. ~ In an unsteady-state permeability determination, pressure in a core changes both with position (high at the inlet face to atmospheric pressure at the outlet face) and with time. Since apparent Pressure Transducer ~~ (~ ~ Nitrogen in <.!) <ñ a.. W 60- a::: => (J) - (J) l&.J g: 40- l&.J <.!) - => ~ 20- Tank Valve v "-"" Care Holder Core . :.:.: L ~~ Nitrogen Vents ot Atmospheric Pressure permeability is a function of pressure, it too must change with both position and time. Klinkenberg's relationship, expressed as a point function of both time and position, is: k[x,t] = kR.~ + b/(p[x,t] + Pa))..(3) DARCY FLOW Substituting Eqs. I and 3 into the Darcy equation and integrating with respect to length yields: -Vt(l + ôG[C]) polt] (dPO[t]\- dt )- kR,A ~ ) 29 ,390 J L ~ 0 [ t] + 2 ( P a + b) " (4) G (c) is the integrated form of the correction factor, f (c,g), that accounts for nonconstant mass flow rate. Its value, given by Eq. A-32, lies between 0.5 and 0.6 for pressures of interest. A plot of left-hand side of Eq. 4,vs poet), shown in Fig. 2, yields a straight line with slope m and intercept i, where ktA m = . . . . . . . . . . . (5) 29,390 lJl 100 f' Flowratp.. Tl1rOtJgI1 Core Is Proportional To Slope L~ 'Pressure Drop Across~e Is Equal To Gauge Pressure 0 I I I I 0 50 100 150 200 250 ELAPSED TIME AFTER OPENING VALVE, SECONDS 884 FIG. 1 - PRINCIPLE OF OPERATION OF UNSTEADY-STATE PERMEAMETER. ~, "",, SOCIETY OF PETROLEUM ENGINEERS JOURNAL and ~ I i = 2(p + b)m . a . . . . . . . . . . (6) Klinkenberg permeability, k f, and slip factor, b, can be determined from the slope and intercept, respectively, of Fig. 2. The correction factors for nonconstant mass velocity, BG( c), were negligible for the run illustrated and were omitted. Note also that poet) is replaced by P g in Fig. 2. This will be explained below. Evaluation of the left-hand side of Eq. 4 requires calculation of pressure-time derivatives. These can be found by taking slopes on the pressure falloff curve (such as the one shown in Fig. 1), but this procedure is neither conve.nient nor particularly accurate for routine measurements. If instead we define the variable y, y[po] " -V t' dPo[t]) : polt] \ dt ' . . . . (7) then y can be evaluated from two discrete values of pressure at the inlet core face, P1 and P2' and the corresponding times i1 and i2 by integrating Eq. A-8 with respect to time. The integration and subsequent multiplication by (Pg + i/m) results in: le,\ ::1 v t{ P + i 1m) Y[Pg] = (tz-fl){i/m) P1 (P2 + ; 1m) 1n P2(P1 + i/m)' . . . . . . . . . (8) ........ where P g is the geometric mean of pressures P1 and P2: Pg =ÝP1 P2 -J Po[t1] Po[t2] . . . . (9) = Inspection of Eq. 6 reveals that the parameter i/m is equal to 2(Pa + b). Atmospheric pressure, P a' can vary from less than 12 to more than 15 psia, depending on location and atmospheric conditions. The Klinkenberg slip factor, b, varies from nearly 0 for very permeable cores to more than 20 psi for tight cores. Thus, i/m can range from about 24 to 70 psi. Fortunately, within this range, Eq. 8 is almost totally insensitive to the value of ilm used, and for computational purposes, we arbitrarily use 30 psi. The maximum error introduced is about 0.05 percent. Alternatively, y can be approximated from: ce 'er ,tI' V t P1 y [p ] = t t 1 n - . . . . . . . (10) 9 2- 1 P2 with nearly as much accuracy as from Eq. 8. Whether y is calculated from Eq. 8 or Eq. 10, it is evaluated at the geometric mean pressure, Þ g' of OCTOBF.n, 1972 each pressure interval, and Eq. 4 becomes: Yc:: y(l + ôG[C]) = ; + mPg . . (11) Values of Yc should be plotted against corresponding values of Pg' This type of plot is shown in Fig. 2. Its linearity indicates that nitrogen flow through the core obeyed Darcy's law during the entire pressure falloff. Since the correction factors for nonconstant mass velocity, BG (c), were small (less than 0.001), y and Yc were used interchangeably in Fig. 2. NON-DARCY FLOW Darcy's law fails to describe flow behavior when high velocities cause non-negligible kinetic energy effects. The deviation from linearity of the y-vs-P g plot shown in Fig. 3 reflects the departure from Darcy flow. The dashed line drawn on Fig. 3 shows the limiting slope that corresponds to Darcy flow rate-pressure drop behavior. The slope of this line is proportional to the Klinkenberg permeability, k f, of the core, and the ratio of its inter~ept to slope, 4 I o.~ ..... 'à.~ t:«. No. SO-P.1C ~ : 12./$ pIif1 L=~Ø6 ØfI 0:2.44"" 3 k, :Œ.11Ifd :: - b:7.76¡n¡ ..... E ::- I :.. 2- 10 I 10 90 I 20 I 30 I 60 I I 40 50 PII' pIig I 10 I 80 FIG. 2 - UNSTEADY-STATE PERMEABILITY DETER- MINATION FOR CORE IN DARCY FLOW. 50 48- I l I " , , , , , , , , , , , , / ,/ I L.,,,,,,, Sitpr -...../ / ,/ / , , I ,/ 46 - Con Ab. SI!J2-C-S046.Z 44 - P.=llI/TpØø L=2.42 till ~ - O:l!Jf till 40 - k,= 270.111d b = I.S!J p," 38- . 36- ..... 'i 34- .:- 32 - ..... --: 30 - :f28- ... 2' - 24 - 22 - 20- 18 16 0 I 30 I 40 50 PII' ",ill 10 20 60 70 80 100 FIG. 3 - EXAMPLE OF NON-DARCY FLOW. 385 i/rn, is the parameter from which the Klinkenberg slip factor, b, is calculated. From a practical standpoint, Fig. 3 is not useful for finding permeability because the position of the limiting slope cannot be determined accurately. Instead, we resort to an equation suggested by Forchheimer9 that includes a kinetic energy term and satisfactorily relates high-rate flow to pressure gradient in core samples. The Forchheimer equation appears in differential form as: -dp/dL = }lV/k + ßpV2 . . . . . . . (12) Note that when ß, the "turbulence factor", is 0, Eq. 12 reduces to Darcy's law. With appropriate substitutions, Eq. 12 can be rigorously, integrated as shown in Appendix Band close.ly approximated by: 2 Ik -òp/L = }lVm/kR., + ap avg. V avg. R.,' . . . . . . . . . (13) ....... where v - VO(PO + Pa)(l + ðG[C]) m - 1/2( P + P + 2p + 2b)' . . (14) 0 R., , a Vo(po + Pa)(l + ôG[C]) V = . (15) avg. 1/2(p + Pð + 2p ) 0 ~ a ~4 52 - ClJn.- ~/9.2-C-»I6.2A Pg=H.87 p$/tf L =2.42 cm 0= 1.91 cm 3.4 5.0 - Or; 4.8- t¡ 0 Þo ~ ::;:: ~ ';00 4.4 - N 0 ; 4.2- 10 E. \ ~ 4.0- ::t. ~ ! 3.8- N -s,..=a//I, L/M= 2(pø+N, pli ItJ = 270 tfId b=lJ9,,; a =5.$0 IttiCf'anI 3.6 - 3,2 I 0 ~ ro ~ ~ 00 ~ ro X: lOp- v 2¡ (fLvm): 0.056691 POI (P"ti¡III)¡[02(p,~2Po)].IIId-"'icron-I-0a«;y ~ avQ. ~. . . FIG. 4 - PLOT OF FORCHHEIMER EQUATION SHOW- ING EFFECT OF KLINKENBERG FACTOR. 386 and P a V 9 . = 1/2 ( Po + P t + 2 P a) MI ( RT). (16) <f' The difference between vm and Vavg is subtle, but significant. The former, vm' is a slip-corrected mean velocity. The velocity, Vavg' that appears in the kinetic energy term has no connection with shear. Therefore, it is not slip-corrected. The mean density, Pavg' is also evaluated using the arithmetic mean pressure. Since Vo is equal to qol A, it follows that YP y. = g 0 A( P + P ) . . . . . . . . . (17) 9 a We can combine Eq. 17 with Eqs. 14 and 15, recognizing also that the outlet end of the core is at atmospheric pressure, so Pf = 0 and ð.p = Pg, and combine these equations and Eq. 16 into Eq. 13 to yield the working equation for non-Darcy flow: 1/2A(Pg + 11m) = 1000 + 14.695pLyc kR., lOaMy cP g( P.9 + i 1m} , (18) 14.695ART}lkR.,{Pg + 2Pa) which for nitrogen at ambient temperatUre reduces to 1.S184D2(p + 11m) 1000 . 9 = k + Ly c R., ~jO.05669YCPg(Pg + 11m} ~) D2(pg + 2Pa) (19) Eq. 19 assumes the form of a straight line: z = 1000 +( ~) x, . . . . . . . . (20) kR., \kR., This is the equation one would use for the graphical determination of k f' b and a (see Fig. 4). The intercept of a z-vs-x plot is (1,OOO/kf), and the slope is (a/kf). Both x and z contain the parameter i/rn. From Eq. 6 we see .that i/rn contains b, the Klinkenberg slip factòr. Thus, the three curves of Fig. 4 illustrate the dependence of non-Darcy permeability data on b. It is too high in the uppermost curve, causing a sharp uptUrn near the intercept. The parameter b is too low in the bottom curve, causing a downward trend at small values of x. The middle curve, which is best approximated by a straight line, employs the correct value of b. Fig. 4 was constructed from the same data as Fi~. 3. Whereas Fig. 3 displayed considerable SOCIETY OF PETROLEUM ENGINEERS JOURNAL r curvature and the limiting slope was difficult to ascertain, a z-vs-x plot like Fig. 4 leaves little uncertainty in the determination of the correct values of k, band a. Darcy-flow data can also be plotted in this form, and since a is 0, the correct line will be horizontal (zero slope). Since both z and x contain the unknown parameter Um, it is more convenient for purposes of machine computation to cast Eq. 19 into the form: p = -;/m + y 1m + C,y 2p (p + 9 c c 9 9 ; 1m) I ( P 9 + 2p a) . . . . (21) The plane that most closely passes through all sets of p , Yc' and Yc2p (p + i/m)/(p + 2Pa) values is f ga' I gg h.g h . oun usmg east-squares tec mques. T e regressiOn finds "best" values of (Um), m and Ct. The right- hand group of Eq. 21 still contains Um, but this difficulty is circumvented by assuming an initial value, calculating Um from the least-squares fit, and continuing to iterate until the change in i/m is less than 0.1 psi. Convergence is very rapid, usually requiring no more than two tries. The desired constants kf. b and a are found from: kl(md) = 658.6 Lm/D2 . . . . . (22) G b ( ps ;) = , ¡2 ( i 1m) - p ..... (23) a a(mi crans) = '7,640 c102m . . . . . (24) Certain constraints are imposed on the constants to insure physical reality: a~O . . . . . . . . . (25) . . . . . . b > 0 ............... (26) The Forchheimer equation adequately describes flow behavior in most, but not all rocks. Certain rocks, especially those that have high a factors, deviate from a linear z-vs-x plot, as shown by Fig. 5. The curve asymptotically approaches a limiting condition of Forchheimer flow, shown by the dashed line, at the lower flow rates. This is analogous to the approach to Darcy flow from Forchheimer flow at very low flow rates. Eq. 20 can be modified to account for non- Forchheimer flow behavior: oft, , Pa¡: ~eì z = 1000/kl + (a/kt)x - YX2/(1000kl) . . . . . . . . . . . . . . . . . . ( 27) Eq. 27 is illustrated by Fig. 6. For purposes of OCTOBER, 1972 45 ~ , , , , , , , , , , , , , , Limiting slop,:a/kJ-l , , I , , 1 , I. 1 1 , CORE NO. 309.3 p( : 11.92 psig L : 2.72 em 40 - 0 : 2.54 em 35 - "'j >- ~ e 0 Ñ 30- 20 0 FIG. 5 - -¡ >- U l- e 0 35- -;.. .:11: 0 0 Q .:::::: 30- N )( >-- + N 45 k.l : 41.9 md IJ : 1.54 psi a : 107 microns y : J280 Sq. microns I 2 I 7 8 I I I I 3 4 5 6 X, md-micron-I-Darcy-I CORE EXHIBITING DEVIATION FORCHHEIMER FLOW. FROM 40 - CORE NO. J09.3 Pa : 11.92 psia L : 2.72 em 0= 2.54 em k.t: 41.9 md IJ : 1.54 psi a : 107 microns r = J280 Sf/. microns - 20 0 I 7 8 I I I I I 2 3 4 5 6 11., md-micron-I-Darcy-I FIG. 6 --- CORRECTED FORCHHEIMER PLOT. 387 putting the equation into linear form, the right-hand member of Eq. 27 was transposed to the left side before plotting Fig. 6. If z and x are replaced by their equivalents (compare Eqs. 19 and 20), Eq. 27 becomes the final working equation that successfully describes unsteady-state flow in all cores tested. If both a and yare nonzero, flow is non-Forchheimer; if y is zero, but a is positive, Eq. 27 describes Forchheimer flow; and if both a and yare zero, it reduces to the Darcy equation. The correction for slip is made for all three types of flow behavior in Eq. 27. APPARATUS Fig. 7 shows the apparatus, including one-liter insulated nitrogen storage tanks, Hassler holders, associated calibration manometers, and valves on the left-hand panel, a large calibration gauge for the 100-psi transducer and electronic equipment on the right-hand side. Fig. 8 shows one of the nitrogen tanks and Hassler holder and only those valves and connections essential to the operation of the equipment. Portions of the hookup for calibrating tank volumes and the transducers have been deleted. { To operate in .. normal mode", a core is loaded into the appropriate Hassler core holder and the sleeve is pressurized to 250 psig. The tank is charged with dry nitrogen to approximately 95 psig, which is measured and indicated by a 100-psi Kaman Nuclear differential pressure transducer. The four thumbwheel switches on the electronic unit are set to 9, 8, 7 and 6, respectively. The valve between the tank and the core holder is opened, and the pressure in the tank declines at a rate that is a function of the core properties., When the pressure falls to 90 psig (corresponding to the 9 setting on the first thumbwheel), digital electronic output from the 100-psi transducer starts the first of three crystal-controlled electronic timers. These units display time in seconds and hundredths. When the pressure falls to the second preset value (80 psig in this case), the first timer stops and the second one starts. At 70 psig the second timer stops and the third one starts. By recording the registered time from the first timer, resetting it to zero, setting the second thumbwheel switch to 5, and turning the recycle switch to recycle mode, the time interval for the pressure to fall from 60 to 50 psig is indicated on the first timer display. As many :~ ~ ~~ , 388 FIG. 7 - UNSTEADY-STATE KLINKENBERG PERMEAMETER. SOCIETY OF PETROI.EUM E:\'CINEERS JOURNAL ~ pressure-time intervals as desired, down to 10 psig, may be taken by continuing this procedure on the three timers. If more data are required, the three-way transducer selector valve is turned to connect the 10-psi transducer with the tank. Then, time intervals corresponding to pressure intervals of 9 to 8, 8 to 7, etc., down to 1 psig can be measured. The pressure intervals to be measured are under control of the operator. The time required for any given pressure interval is roughly inversely proportional to the permeability of a core. Excessive times are required for the pressure to decline 10 psi (e.g., from 90 to 80 psig) with cores having permeabilities of less than 1 md. The time can be reduced by a factor of about 100 by measuring 0.1 instead of 10 psi declines. This is accomplished by operating the 10-psi transducer in ICdifferential mode". To effect differential operation, the ICshorting" valve (see Fig. 8) on the 10-psi pressure transducer is opened and the ICdifferential" valve, which normally vents the low-pressure side of the lO-psi transducer to atmospheric pressure, is closed. Then the three-way tr~nsducèr selector valve is turned to the lO-psi transducer position. These manipulations expose both sides of the 10-psi transducer to the same pressure, which may be as high as 100 psi. The transducer selector valve is quickly turned back to the 100-psi transducer position, then again to the 10-psi position. In this manner, the pressures on both transducers are equalized, and the pressure on either side of the diaphragm of the 10-psi transducer is indicated by the 100-psi transducer. The shorting valve is quickly closed. As the pressure in the tank decline,s (as nitrogen flows through a low-permeability core specimen), the change in tank pressure from the instant the shorting valve was closed is registered 9 FILL VALVE ~ )~ " (110 psig )- TANK PRESSURE @ nmllLATOR J NITR(){;EN--+- IN (250 psig) HASSLER SLEEVE GAUGE øfnc.. Papet; ~ìI 0 ~ 1l~- II / ~\- NITROGEN DISCHARGE HASSLER HOLDER TO CORE VACUUM <3 as a negative differential pressure on the transducer readout. Actual tank pressures at any time are found by algebraically adding the 100-psi and IO-psi transducer readings. The negative differential readings start and stop the electronic timers on preselected multiples of 0.1 or 1.0 psi. The differential technique permits accurate measurements of permeability in the micro-Darcy range in a reasonable length of time. Several experimental difficulties have been overcome in the present design of the apparatus. Probably the most critical is maintenance of constant temperature. The equations developed above assume isothermal nitrogen expansion. The observed expansion in early ve~sions of the apparatus was essentially isothermal for tight cores, but fell between isothermal and adiabatic for the more permeable cores. The nonisothermal expansion caused serious pressure errors, rendering permeability data useless. Gas temperature in the tank. dropped to -900 F (calculated from pressure measurements) in the extreme case of free expansion (no core in the Hassler holder). Furthermore, recovery time to reach within a fraction of a degree of ambient temperature required about 15 seconds. The cooling problem was eliminated by inserting a bundle of copper tubes into each gas reservoir. These ~-in. diameter copper tubes, .exceeding 8 in. in length and 100 in number, provide both heat capacity and heat transfer surface to maintain the nitrogen temperature constant. .In addition to the copper tubes, the gas reservoirs were also packed with several copper wire-mesh pads. The copper packing reduced temperature loss to less than lOF and recovery time to about 0.1 second for the free expansion, and virtually eliminated nonisothermal conditions for even the most permeable core plugs. 100 psi PRESSURE TRANSDUCER =ar / VENT VALVE -0=~TRANS. SELECTOR VALVE ''sHORTING'' VALVE FOR DIFFERENTIAL OPERATION "DIFFERENTIAL" -- : VALVE 10 psi PRESSURE TRANSDUCER -r-- INTERVAL TIMERS ) (ß RESET SWITCHES 0 G--RECrCLE SWITCH PRESSURE SELECTOR THUM8- WHEEL SWITCHES ( ) PRESSURE " \ 0 0 READOUT ~ PRESSURE TRANSDUCER CARRIER -DEMODULATORS ) ( 0 0 0000 OCTODF.It, 1972 FIG. 8 - SIMPLIFIED SCHEMATIC OF UNSTEADY-STATE PERMEAMETER. 389 A second thermal problem became evident in measuring tight (0.01 md or less) samples - small changes in ambient temperatUre caused large errors in penneability measurements. A quick calculation using the gas law shows that a 0.21-psi pressure change (at 100-psig tank pressure) occurs for each 10 F temperature chang-e. This means that to obtain accuracy of I percent or better using the differential technique and measuring O.I-psi pressure changes, the maximum tolerable temperature change in the nitrogen reservoir is 0.005°F during the period of the O.I-psi change. Heavy insulation comprised of Fiberglas, aluminum foil and foam, combined with the large heat capacity of the system has minimized the problem of short-term ambient temperature changes. Room temperature still must be reasonably constant for low permeability cores that require more than 60 seconds for O.I-psi declines. Another experimental improvement was the enlargement of the ports in the Hassler holder end-caps. The original 1/16-in. diameter holes were found to add flow resistance to runs involving high permeability cores. These small holes were enlarged to greater than ~-in. diameter and the error due to flow resistance is now unmeasurably small. Since pressure-time data must be essentially differentiated, high-quality pressure transducers are required. The Kaman Nuclear transducers employed have combined hysteresis and nonlinearity of about 0.3 percent, but the repeatability is better than 0.1 percent of full scale. The transducers were carefully calibrated using a Heise gauge for pressures above 45 psig, mercury manometers below 45 psig, and a manometer filled with "Unity Oil" for the 0- to 1.0- psi range. Tank volumes, including the transducer 'internal volumes, connecting lines, ball valve volumes and the Hassler holder volume to the inlet face of the core were determined to within 0.05 percent using Boyle's law technique with a carefully calibrated reference volume, mercury manometers, and a cathetometer. CAPABILITIES AND LIMIT A TIONS The present permeameter will accommodate }.4'-in. diameter core plugs up to 2 in. length and I-in. diameter plugs ranging in length from ~ in. to 3 in. The time required to obtain time-pressure data for a given core depends on its size and penneability and on the number of data points taken. It also depends on the mode of operation ~ differential or normal. Differential measurements are much faster for low permeability cores than normal mode measurements. Table I shows typical time require- ments for cores of different permeabilities, measured with different numbers of data points and with the two modes of operation. Run times generally range from 1 to 45 minutes, but most reservoir-grade rocks require from 2 to 10 minutes. Reproducibility of measurements (precision) is less than:!:: 2 percent for differential mode operation and generally less than:!:: I percent for normal operation. 390 TABLE 1 - TYPICAL TIME REQUIREMENTS FOR UNSTEADY-STATE PERMEABILITY DETE RMINA TIONS Cumulative Run Time (minutes) k f (md) 0.013 0.112 0.301 2.68 8.61 26.1 41.9 75.0 162.0 267.0 584.0 968.0 No. of Data Points Mode of Operation Differential Differential Di fferent i a I Normal Normal Normal Normal Normal Normal Normal Normal Normal 45.6 12.0 5.0 26.5 18.6 7.7 8.7 1.8 2.7 1.5 1.0 0.6 5 5 5 6 8 9 15 10 15 10 14 8 Accuracy depends on the number of data points measured, and the size and permeability of the sample. To check accuracy we compared permea- bilities of several ceramic, sandstone, and carbonate core plugs that w~re carefully measured on a conventional steady - state Klinkenberg permeameter. The average of the absolute deviations (29 core plugs total) was 2.0 percent. It is interesting to note that the repeatability on a number of steady-state determinations for several core plugs, was :t 2 percent, whereas the repeatability for unsteady-state detenninations was:!: I percent. Thus, the average absolute deviation of 2 percent between the two methods is within the repeatability of the standard method. . KLINKENBERG SLIP FACTORS Slip factors were determined for nearly 100 core plugs ranging in permeability from about 0.01 to 1,000 md. These factors are plotted against permeability in Fig. 9. The points scatter widely, but the general tendency is a decreasing b with increasing permeability. The equation of the line shown in Fig. 9 is: b(psi) = 6.9 kt-O.36 , . . . . . (31) where k e is the KI~nkenberg penneability in millidarcies. According to Klinkenberg's capillary tube analog, if a porous plug could be represented by a bundle of capillary tubes, then the mean 100:: '" , ""I , "." ."1 , ,.. ',.". , . """''WI1' , 1 "",.. ~.......... 0 ï~. ...." -4... ~ . . . -. ........ "!.. . . . . ~ 00" ""'" - : ..........~o ~o 0 . . ~. 11 . '. ~ "'. , .. 1.:"-......, r . .. '. 1., .;&0: :I : 5z . 0.1 01 J PI. jll1 tOOO I I .I . 1.111' 0.' ... . J ......1 .. I I i 11181 . .I ...11.1 100 10 IIJ' md FIG. 9 - CORRELATION OF KLINKENBERG FACTOR VS PERMEABILITY. SOCIETY OF PETROLEUM ENGINEERS JOURNAL ~ diameter of the tubes (in microns) is approximately 11/ b. This corresponds to mean diameters ranging from 0.3 [0 about 90 microns for the points shown in Fig. 9. McMahon 10 determined Klinkenberg b factors on 162 core plugs from a wide variety of reservoirs. A least-squares fit of his data (same units as above) yields b ( . ) -0 34 pS 1 = 6.2 k . """ (32) Rë~ ~~~ TURBULENCE FACTORS The turbulence factor, a, is a potentially interesting characteristic of reservoir rock. It is numerically equal to the product of ß (reported by Katz et al. 11) and permeability, k e (converted to the appropriate units). Besides being a useful parameter to calculate pressure drop-flow rate behavior in high pressure gas wells where turbulence is anticipated,12 a, from the analysis of the Forchheimer equation given in Appendix B, is the characteristic length in the Reynolds number. In pipeline calculations this characteristic length is the internal diameter of the pipe. By analogy a would be some sort of mean pore diameter. Unfortunately, the velocities used to calculate a in the Forchheimer equation are superficial velocities. If a were multiplied by the effective porosity of the rock, it would probably be somewhat more representative of the characteristic pore diameter. Furthermore, most cores are not completely homogeneous. Therefore, the mass velocity through one portion of the core may be different from that in other portions. One would expect kinetic energy effects to become evident first in those portions carrying the higher velocity flow. Thus, a may in part be a measure of core heterogeneity (increasing a with increasing heterogeneity). The variation of a with permeability is shown in 1000 . , ., "I , , , , , , ., , , . ., 't.. g b "Ë t:; A COORS CERAMIC PLlJ6$ .... 0 NATURAL R£S£RIIOfR ROCK, THIS »aM: . . ""............ . DATA OF CORNELL & KATZ ........ ............ 0 "'0.... ""........ 0 ........ . 8".... '.... .... 0 ........ . . -o...~ 100 ::- . . . 0 .0 .0 0 0 OJ'. 0 . 0 '000 ,ß° 0 0 0 .~ ~ 0 0 ~~~ g . '\ ~ -,,-. '. . . .". ...--.. - olio -. ""............ 0 0 0 000 ""'............ 0 A ............ ""'0.... ......... A- A .... .... .... ..... 4:. . 0 10 :- A Jlff1Ct,. ~ 1 I 100 . 1 1 . I " oJ . .I .I . I I I J I .I I II'. 10 1000 k.l' md FIG. 10 - CORRELATION OF TURBULENCE FACTOR, a, WITH PERMEABILITY. OCTOBER, 1972 Fig. IO~ The solid points are calculated from data of Cornell and Katz, 13 the open circles are natural reservoir rocks from the present work and the triangles represent Coors ceramic plugs, also measured in the present study. As may be expected from the foregoing discussion, the points scatter widely. In general, a decreases with increasing permeability. This is opposite to the expected trend if pore diameter were the controlling factor. The lines drawn in Fig. 10, which encompass all the data on the natural reservoir rocks, have slopes of -1/3. The ceramic plugs shown by the triangles have high porosities (about 45 percent) compared to the reservoir cores (5 to 25 percent) and are much more homogeneous. Correspondingly, their a's are significantly lower than those 9f the reservoir rocks. Too few of the secondary turbulence factors for non-Forchheimer flow, y were determined to make a meaningful correlation. However, for the values determined, y is roughly proportional to a2. SINGLE-POINT PERMEABILITY DETERMINATION A high degree of accuracy is not necessary for all permeability determinations. Where accuracies of :t 20 percent are acceptable, a rapid single-point detèrmination may be run with the present apparatus and permeability determined from the correlation shown in Fig. 11. To use the correlation, the core length and diameter are measured. Then, the time required for the pressure to fall from 50 to 40 psi is measured, and the value of the group L Vt/(D2ðt) is calculated. Finally, the Klinkenberg permeability, k t, is read from the graph. The two dashed lines drawn in Fig. 11 represent :t 20 percent deviations from the solid line. CONCLUSIONS A reliable instrument has been developed for the rapid measurement of core plug Klinkenberg 1000- I , 11' 1'1 I , I" III } -: . I "'3 100::- -: ..." 10::- I I J J I I I I" I I .I I lid I J J I III 1000 10 100 LVt/(D2At~-40), cmLltc'l FIG. 11 - CORRELATION FOR SINGLE POINT DETER- MINA TION OF k r permeabilities ranging from about 0.001 to 1,000 md. The unsteady-state technique also detennines one or two turbulence factors for cores that depart from Darcy flow behavior. The penneameter is absolute in the sense that no calibration curves are required, and it reproduces steady - state permeability determinations to within about:!: 2 percent. NOMENCLATURE a = ratio of intercept to slope, Urn, psi A = cross-sectional area of core, sq cm b = Klinkenberg slip factor, psi B = dimensionless group defined by Eq. B-10 c = dimensionless number, defined by Eq. A-22 C = dimensionless number, defined by Eq. B-8 C 1 = constant in Eq. 21 (= 0.03734 aL/ke04) d = differential operator used in derivatives 0 = core diameter, cm f(c, g) = function defined by Eq. A-29 f1(c,g,8) = function defined by Eq. A-34 g = dimensionless length, defined by Eq. A-19 G (c) = dimensionless function, defined by Eq. A-32 Gl(8,c) = dimensionless function, defined by Eq. A-38 h = corrected dimensionless length, defined by Eq. A-35 i = intercept of a Y-VS-Pg plot, ml/sec k = apparent permeability, md ke = Klinkenberg, or "liquid" permeability, md L = core length, cm rn = slope of a y-vs-P g plot, for core in Darcy flow, ml-sec-Lpsig-l M = molecular weight, gm/ gm-mole n = number of gram moles of nitrogen in tank at time t N = Reynolds number, defined by Eq. B-12 Pa = atmospheric pressure, psia Pg = geometric mean of pressures PI and P2, psig pressure at outlet face of core, psig arithmetic mean pressure in core, psia = pressure in nitrogen reservoir (same as pressure at inlet face of core), psig PI = pressure in nitrogen reservoir at time tl, psig P2 = pressure in nitrogen reservoir at time t2, psig ð.p = pressure drop across core, psi P (x, t) = pressure in the core that varies with both distance and time, psig P = dimensionless pressure, defined by Eq. Pe = Pm Po B-9 392 Pe = dimensionless pressure at outlet end of core q (x, t) = volumetric flow rate that varies with both distance and time, ml/sec qo(t) = volumetric flow rate at inlet face of core, ml/ sec R = gas law constant (= 82.05 ml-atm/ gm- mol-OK) time, seconds time when pressure in tank is PI' seconds time when pressure in tank is P2, seconds time difference (t2-tl)' seconds absolute temperature, oK average velocity in core based on arithmetic mean pressure in core, cm/ sec vm = slip corrected mean velocity in core, cm/ sec v 0 = velocity at inlet face of core, cm/ sec Vt = volume of tank (nitrogen reservoir), ml x = distance in core (= 0 at inlet end and L at outlet end), cm X = dimensionless distance, defined by Eq. B-11 t = tl = t2 = ð.t T Vavg - Y = volumetric rate function, defined by Eq. 7, ml/sec . Y c = volumetric rate function, ,corrected for nonconstant mass velocity, ml/sec z = function used to describe non-Darcy flow (Eq. 20), darcy-l Z = dimensionless function, defined by Eq. B-15 a = turbulence factor (= ßkf), microns ß = turbulence factor used in Forchheimer equation, ft-l y = turbulence factor, .sq microns 8 = correction factor for unsteady-state flow, defined by Eq. A-28 { = dimensionless number, defined by Eq. , A-37 IL = nitrogen viscosity (= 0.0177 cp at 23°CJ Pavg = average gas density in core bas~d or arithmetic mean pressure in core, gm¡ ml Po = gas density at inlet fac,e of core, gm/m: cþ = porosity ACKNOWLEDGMENTS The author gratefully acknowledges the contribu tions of W. J. Kunzman, W. O. Roszelle and R. A Steffa, and wishes to thank the Marathon Oil Co. fo permission to publish this paper. REFERENCES 1. Aronofsky, J. S.: J. Appl. Phys. (1954) Vol. 25, 48. 2. Wallick, G. C. and Aronofsky, J. S.: "Effect of Ga Slip on Unsteady Flow of Gas through Porous Medh SOCIETY OF PETROLEUM ENGINEERS JOURNA , . 't' ~ - ! ... - ì: ~ ... j i ¡ i ,:1 ':'u. ~ì I ~:"",,",I ,.;: \ '1 ~, I '~t 1.1 . I \ Experimental Verification," Trans., AIME (1954) Vol. 201, 322-324. 3. Champlin, Jerry B. F.: "Rapid Determination of Permeability in Porous Rock," RI 6098, USBM ( 1962). 4. Morris, W. L.: assignor, Phillips Petroleum Co., "Portable Permeameter," U. S. Patent No. 2,633,0 IS, March 31, 1953. 5. Aronofsky, J. S., et al.: assignor, Socony Mobil Oil, e'Method of Measuring Characteristics of Porous Material," U. S. Patent No. 2,867,116, Jan. 6, 1959. 6. 'Houpeurt, A., Delclaud, C., Curutchet, J. and Albert, P.: "Mesures de permeabilite," Revue de L'lnstitut du Petrole et Annales des Combustibles Liquides (June, 1951) Vol. VI, No.6, 180-190. I 7. Klinkenberg, L. J.: "The Permeability of Porous Media to Liquids and Gases," Drill. and Prod. Prac., API (1941) 200. 8. Kundt, A. and Warburg, E.: Poggendor{s Ann. Physik (1875) Vols. 155, 337, and 525. 9. Forchheimer, Ph.: Zeitz, Ver deutsch. Ing. (1901) Vol. 45, 1782. 10. McMahon, J. J.: "An Investigation of Air Permeabil- ities of Porous Media," MS thesis, The Pennsylvania State U., University Park (1949). 11. Katz, D. L., et ai.: Handbook o{ Natural Gas Bngi- neering, Mc!Cìraw-Hill Book Co., Inc., New York (1959). 12. Tek, M. R., Coats, K. H. and Katz, D. L.: "The Effect of Turbulence on Flow of Natural Gas Through Porous Reservoirs," J, Pet. Tech. (July, 1962) 799- 806. 13. Cornell, D. and Katz, D. L.: "Flow of Gases Through Consolidated Porous Media," Ind. Bng. Chem. (1953) Vol. 45, 2145. APPENDIX A DERIVATION OF UNSTEADY-STATE EQUATIONS FOR DARCY FLOW The volumetric isothermal flow rate of nitrogen, which behaves as an ideal gas, from a storage tank at pressure Po is: M q [t] = p [t] 0 0 f , dn - dt i -r~v t ,( dp , 0 POl t]RT crt . (A-I) \ ) = , But density is given by: r~p 0 [t] . . . . . . . . . . (A-2) P [ t] = RT 0 Therefore, -v t qo[t] = poltj I dp , (A - 3) 0...... ,dt ) Assume for the moment that at any instant in time the mass velocity throughout the length of the core is constant. (This is not rigorously true, and will be treated below.) As nitrogen flows through a core, it expands, such that OCTOBER. 1972 q[x,t] qo[t]po[t] -Vt (dPo\ = plx,tJ = plx,t] dt). . . . . . . . . . . '. . . . . . (A -4) Substituting Eq. A-4 and Klinkenberg's relationship, Eq. 3, into the Darcy equation for one-dimensional flow yields: .-YtPOI[t] plx,tJ = -k A(l + b/p[x,t]) ap[x,tJ t aX . . (A-5) ~ If Eq. A-5 is integrated with respect to length and divided by ~(Pf - Po)' it becomes -2Yt JJ Po'[t]L k t A (p 0 - P R. ) = P t + Po + . 2b . . (A -6) Pressures in all equations above have been absolute pressures, expr~ssed in atmospheres and permea- bility.in darcies. If we now switch to gauge pressure (psig),and express permeability in millidarcies, Eq. A-6 becomes (since P f = 0 psig): -Y P I[t] k A t 0 - t poltJ - 2000x14.696JJL (po[t] + 2p a + 2b). . . . . (A-7) Eq. A-7 is the equation of a straight line with intercept i and slope m: -YtPOI[t] . P [t] = 1 + mPO[t] 0 where m and i are given by Eqs. 5 and 6, respectively. Eq. A-8 can be rearranged and integrated with respect to time to give: , . . . . .(A-B) Yt Pl(P2 + i/m) rrm 1 n P2 (Pl + i 1m) = m (t2 - tl) . (A-9) Eq. A-9 could be used to compute m (hence kf), but the left-hand side contains the parameter, (i/m). Therefore, unless this parameter is known, 'Eq. A-9 is not useful. Note, howev,er, by combining 'Eqs. A-8 and A-9 that -Y tPo I [t] poltJ = m(PO[t] + i/m) = Vt(po[t] + i/m) Pl(P2 + ( t2 - t 1 ) ( i 1m) 1 n P 2 ( P 1 .............. i/m) + i 1m) . . . (A-IO) 893 The right-hand side of Eq. A-10 still contains the parameter Urn, but for some value of Po that lies between Pl and P2' we observe that the right-hand side of A-10 is almost totally insensitive to the value of i/rn used. Experimentally determined Urn values range from about 24 to 70 psi. Within this range, a Po that is equal to the geometric mean of Pl and P2' Po = Pg = ~ P1P2 , . . . . . (A-ll) will cause less than 0.1 percent error if 30 psi is arbitrarily used instead of the true value of i/m. Now we can calculate the left-hand side of Eq. A-8 using finite increments of pressure and time, rather than having to evaluate derivatives, Y[Pg] :: -v tPg' [t] = V t(-'lPl PZ' + 30) PgltJ 30(tZ-t1) P 1 (p Z + 30 ) . 1n P2(Pl + 30) . . . . . . . . . . . . . . . (A-12) and Eq. A-8 becomes y[p ] = ; + m p [t] . . . . . (A-13) 9 9 This is the equation (but uncorrected for nonconstant mass velocity) used for unsteady-state Darcy flow. It appears in graphical form in Fig. 2. CORRECTION FOR NONCONSTANT MASS- VELOCITY In the above derivation, we assumed a constant mass velocity, or equivalently that a(pv) = 0, aX ....... . . . . (A -14) but the continuity equation for one-dimensional flow requires that a(pv) = - 4> !.e. , . . . . . . . . (A-15) aX at and since pressure (hence, density) is changing with time, we have violated the continuity equation. To estimate the error introduced, we first approximate the density change with time (equivalent to the pressure surface) assuming steady-state flow, insert the approximation into Eq. A-15, then iteratively improve the approximation. Returning to absolute pressures, we integrate Eq. A-5 between the limits of L and x and the corre- sponding pressures of P e and P to give 3~ -2Vt}.lP'O[t](L-x) ktA(p-Pt) = Pt + P + 2b .(A- 6) :f) Elimination of -2VtJ1P;Ü)!CkeA) between Eqs. A-16 and A-6 results in: (L-x)(p -p )(p + P + 2b) = 0 R. 0 R. L(P-Pt)(p + Pi, + 2b) . . . (A-17) In terms of gauge pressures, recalling that ilrn = 2 Cp a + b) and that Pe = 0 psig, Eq. A-17 becomes: p(p + i/m) = P (p + i/m)(l-x/L) . 0 0 . . . . . . . . . . . . . (A-18) For brevity of notation, let 9 :: (l-x/L) . . . . . . . . . . . (A-19) and a :: i 1m = 2 (p + b) . . . . . . (A-20) a Taking the partial derivative of Eq. A-18 with respect to time yields: lQ. = g-{ c + 1 at """\rc + Q . p' [t] , . . . (A-21) ~ - 0 . where 2 c = a 4po{Po + a) ... . . . . (A-22) and pi [t] = dp I dt. . . . . . . . . (A-23) 0 0 Returning now to the continuity equation, sinçe p = Mp/(RT) and g = 1 - x/L, then 4>LMp' [t]lIc + 1 0 RT a(pv) ag g -V c + g' . . . . . (A-24) = . . . . . . . Eq. A-24 can be integrated with respect to length, g, from the inlet end (g = 1) to an arbitrary position in the core: p V - pV - 00- 24>U~P~ [t] [( c + 1) (1-2c) 3RT ~ + (2c-g)\j (c + 1) (c + g)] . (A-25) SOCIETY OF PETROLEUM EiI\GINEERS JOUR!'oIAL POVo = -MVtP~ [t]j(ART)' . . . (A-26) p v = p 0 V 0 (1 + ö f [ c ,g ]). . . . (A - 27) ô = 2~LAI (3V ) . . . . . . . . (A-28) t ~: f[c,9] = (C + 1)(1-2c) + (2c-g) . -V (c + 1) (c + g). . . . (A-29) Eq. A-27 represerits a considerable improvement over the initial assumption of constant mass velocity (i.e., pv = Povo). We can now improve Eq. A-4: q[x,t] -Vt(l + ôf[c,g]) p[X,tJ IdPO) ,dt = . . . . . . . . . . . . . . . (A - 30) prior to substitution into the Darcy equation. Upon integration with respect to length, the latter becomes - -VtP'o[t](l + ôG[C]) Yc = poltJ =.; + mPO[t] . . . . . . . . (A-31) where ~1 G[c] = [(c + ')(1-2c) + (2c-g) ~ 0 . V (C + 1) (c + g)] dg = '/5 (c + 1) (8C2_4c + 3) - 8/5 (c + 1)1/2 c5/2 . (A-32) . . . . . . . ........ Eq. A-31 is analogous to Eq. A-8, but does not assume constant mass velocity. G(c), given by Eq. A-32, is a function of tank pressure, poet), and i/m, since c (Eq. A-22) is a function of these variables. Values of G(c) range from 0.6 at infinite pressure, to 0.5 at Po = 0 psig. Of:TOHFH, 1<)72 -a (r ~ We may now repeat the procedure outlined in Eqs. A-17 through A-27, this time using the corrected equations, to see if process converges. The equation analogous to Eq. A-27 is: (pv)[x,t] = (p V )[t](1 + öfl[C,g,ô])' 0 0 . . . . . . . . . . . . . (A-33) where 1 r f,[c,9,ô] = 3/2 (h + EfV C + 1 -.¡ c + 1i dg . . . (A-34) ~ 9 . . . . . ........ h[ô ,c,g] = 9 + ôl[c,9] . . . . '(A-35) 1 + öGLc] 9 r I [c,g] = [(c + 1)(1-2c} + (2c-g) J 0 . ,{( c + 1) (c + g)] dg = (c + 1) ( 1- 2 c) 9 + 2/5(c + 1)1/2 [(c + g)3/2(4C-9) , -4c5/2] . . . . . . . . . (A-36) Md E = PO(PO + a) 2 p + a 0 ~. (A-37) dPO Normally { is small compared to h. The largest change in h with changes in Po occurs about midway in a core, at g = 0.5. With i/m = 30, g = 0.5, and ô = 0.05 (this is an order of magnitude larger than in the present equipment), { reaches its maximum value of 0.000427 at about Po = 10 psig. Under the same condition" h = 0.505419, so { at its maximum is only 0.084 percent of h. As ô becomes smaller (larger tank volume), { becomes even smaller and h approaches g. Finally, we must find how these changes affect Yc (see Eq. A-31) to see if the whole procedure is converging. If we define a new function 1 .r G1[C,ö] = f1[c,g,ô] dg ,. .(A-38) ~ 0 then Eq. A-31 becomes 395' . -Vop'o[t](l + öG1[c,ö]) Yc = po[tj - - ; + mPo[t] . . . . (A-39) Numerical integratÌon of Eq. A-38, for e = 0 and D = 0.05, yields a value for Gl(0,0.05) of 0.60133, compared with 0.60000 for G( 0) from Eq. A-32. Thus, the entire correction factor, 1 + DCl (c,a), is 1.03007 compared with 1.03000 for 1 + OG (c), when e = 0 and Ô = 0.05. Since these conditions (values of e and 8) are prob~bly the most severe one would expect to encounter, we consider the correction to have converged satisfactorily, and corrected. y values can be computed from Eq. A-31 using G(e) values from Eq. A-32, well within experimental accuracy. APPENDIX B INTEGRATION OF THE FORCHHEIMER EQUATION The Forchheimer equation for one-dimensional flow in differential form is -dn pV 2 (B-1) -=.r;.. e r.- + ßp V . . . . . . . . . . dx t<\ but k e'kt(l + b/p). p = Mp/ (RT) . . . . (B-2) ........ ......... .(B-3) n = ßk t . . . . . . . . . . . . . . (B-4) and for steady-state flow V = V p /p . . . . . . . . . . . .(B-5) 0 0 Therefore, 2 2 -dp = PoPoVa nMpvo Po dx pkl(l + b/p) + - ktRTP2 . . . . . . . . . . . . . . . . ( B.()) or in dimensionless form, -cdP- 1 N dX - P + B + P , . . . . . . . ( B-7) where c = ktPa L\1 V """"",,'" (B-8) 0 396 " ~ P = pIp, . . . . . . . . . . . . . (8-9) 0 B = b/p ,............ (B-10) a ~ x = x IL ,............ (B-11) and aV P M aV P N = 0 a = a 0 \l RT \l . . . . . . (B-12) Integrating Eq. B-7, r1 J1 (p2 + BP) N + 1 dX = dP , Z + P C ""0 Pt Po .. .. .. . . . . . . . . . . ( B-13) we obtain (N+ l)/C = (l-Pt) 8; 1/2(1 + Pt) + (B-Z) (1 - z- 1-Pg. )- . 10 1 + Z P R. + Z ..... . . . . . . . . . . (B-14) where Z = NB I (N + 1) . . . . . . . . . (B,-15) All pressures in the above equations are absolute. Note that N is a Reynolds number and that a is the characteristic length in this number. With Darcy flow, ~(Eq. 8-15) is zero. Z approaches the value of B for high flow rate, HtUrbulent" conditions. As B approaches zero, i.e., the effect of slip becomes negligible, the right-hand side of Eq. B-14 becomes independent of the Reynolds number. Eq. 8-14 is not convenient to use with experimental data 'to determine kf, b and a because these constants are not separable. The approximation In 1 + Z - 2(1-PR.) P R. + Z - 1 + P + 21 . . . . (B-16) t . SOCIETY OF PETROLEUM EI'\GINEERS JOURNAL . , coupled with some algebraic manipulation on Eq. B-14 yields PO-Pi - ~VOPo L - 1/2ki{PO + 'J'i. OCTOBER, 1972 + Pi + 2b) aM(PO + Pi}Vo2po2 1/2kiRT(PO + Pi)2 . (B-17) This integrated form of the slip-corrected Forchheimer equation approximates the more rigorous form, Eq. 8-14, to within 0.02 percent or less for most realistic combinations of the variables. As b, the Klinkenberg slip factor, approaches zero, the approximation becomes exact. Eq. .I?-17 is equivalent to Eq. 13 in the text,. except that' the velocities in the latter equation have been corrected for the unsteady-state case. *** 397 I I I I ¡ I ¡ I . I I ' j } II' I ¡ í I ¡ I : 1 ; 1"" I, j I J I. , j I I ~Á~ I ß'ß? J) 0:)- dO~-OJ(\ ANADARKO PETROLEUM CORPORATION ALTAMURA NO.1 N .P.R.A. NORTH SLOPE, ALASKA BI'OSTRA TIGRAPHY REPORT ¡ I I MICROPALEO I CONSULTANTS, INC. I ! I t ~' July 18, 2002 TO: ANADARKO PETROLEUM CORPORATION Alaska Exploration Group 1201 Lake Robbins Drive The Woodlands, Texas 77380 Attention: Mike Beattie I I [1 II I II i I i i II II II II II I i[ I I ~ SUBJECT: Biostratigraphic Analysis, Anadarko Altamura No. 1 Well, NPRA - North Slope, Alaska The attached report details our interpretations of the Foraminifera and palynomorph occurrences in ditch and conventional core samples from the Anadarko Altamura No.1 well below 7480 feet. Work on this project was done at the offices of Micropaleo Consultants, Inc. in San Diego, California. A total of 69 ditch and conventional core samples were processed and examined for Foraminifera and palynomorphs. There are two observations that the reader should note: 1) The Kimmeridgian/Oxfordian boundary could be placed too high at 8790 feet due to reworking. It probably belongs somewhere in the interval 8790-8970 feet. 2) A significant potential 3 rd or 4th Order Sequence Boundary is suggested within the Kimmeridgian between 8635C and 8655C. This would mean that the very fine grained sandstone above this 3 rd or 4 th Order Sequence Boundary would represent a basal transgressive sandstone and should exhibit the "best" reservoir characteristics associated with the sandy, silty Kimmeridgian interval in this well. 329 Chapalita Drive. Encinitas, California 92024 (760) 942-6082 . FAX (760) 942-9623 . elnail: micropaleo@home.com I I I I I I I I I I I I I [ I II I ,I[ If you have any questions regarding the data or interpretations presented in this report, give us a call. Sincerely, Ø/:D¡f~ Michael B. Mickey MICROP ALEO CONSULTANTS, INC. MBM:HH:be Attachment ~d¡ Hid~aga MICROP ALEO CONSULTANTS, INC. I f I / [ I I I I I I I r I r I ¡ I -a M~Ç!RXA~~2 ANADARKO PETROLEUM CORPORATION ALTAMURANO.l API #50-103-20403 SEC. 30, T9N/R2E UM N.P .R.A. NORTH SLOPE, ALASKA Prepared by: Michael B. Mickey - Foraminifera Hideyo Haga - Palynomorphs BIOSTRATIGRAPHY REPORT Job No. 22-107 July, 2002 ~ TABLE OF CONTENTS INTEGRATED SUMMARY................................................................................... FORAMINIFERA REPORT ............ .......................... ..... ..... ..... ..... ........ ... ...... ..... ... FO RAMINIFERA SUMMARY.............................................................................. INTRODUCTION.............. ...... .... ............ ......... ....... ....... .................... .................... Scope.. . . . . . . . . . . .. .. . .. . . . . . . .... ... .. . . . . ... . .. .. .. .. ... .. . .. . . .. . ... . . ..... .. .. .. ... ... . . .. . .. . . .. .. . . .. . ... ... Procedures. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . F orm.a t . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . .. . . .. . . .. .. .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . RES UL TS ................................................................................................................ CON CL USIONS...................................................................................................... PALYNOLOGY REPORT............. ........................ ................. ........................... ..... PAL YN 0 LOGY SUMMARY................................................................................. INTRODUCTION ........ ............. ...... ... ..... ............ ....... ........ ... ............ ....... ........ ... .... Purpose and Scope........................................................................................ Procedures. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . .. .. . .. . .. .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Report F orm.at .............. . ......... ... ........ ........ . .......... ....... ...... ................ ... ......... RESULTS................................................................................................................ 20 CONCLUSIONS...................................................................................................... 25 2 4 5 7 7 7 8 9 14 15 16 18 18 18 19 { I I I Figure B-1 Figure F-l I Figure P-l I l ¡ I I I [ [ 1 ¡ I I ILLUSTRATIONS (In pockets at back of report) High Resolution Biostratigraphy Plots Foraminifera Distribution Chart (7480-91 OOlT.D.) Palynomorph Distribution Chart (7480-91 OOlT.D.) 7480-7640' 7640-7720' 7720-7840' 7840-8450' . * Logs not available. INTEGRATED SUMMARY * Early Cretaceous Aptian to Early Albian Early Cretaceous Barremian KED Early Cretaceous Hauterivian KEH Early Cretaceous Probable Lower Valanginian KEVL 2 ! ) ! I I [ \ 1 I ,I I ( j I ',I' I ¡j I! 8450-8790'? Late Jurassic Kimmeridgian JLK 8790?-9100'T.D. Late Jurassic Probable Middle? to Upper Oxfordian JLou-oM? Discussion. Definite Oxfordian foram markers do not occur until 8940 feet. 3 j \ ~ ~ 0 ~ ~ ~ ~ ~ ~ ,.Q u .- ~ "C ~ ~ ..... = ~ ~ ;... ~ Co4 - ;... ~ 1-1 ~ ~ Z ..... ..= = u 1-1 Þ-I .- ~ ~ ~ 0 ~ FORAMINIFERA SUMMARY 7480-7640' Age. Early Cretaceous Aptian to Early Albian Zone. F-ll Environment. Middle to Lower Bathyal - Some Distal r (Middle to Lower Slope - Some Starved Basin) I I 7640- 7720' I Age. Early Cretaceous Barremian I Zone. F-12 I Environment. Marginal Marine to Inner Neritic (Transitional to Inner Shelf) ¡ I 7720- 7840' Age. Early Cretaceous I[ Hauterivian Zone. F-13a I Environment. Middle Neritic ,I (Middle Shelf) ¡ 5 ¡ t ¡ ~ I f I I ¡ I ~ I~ 7840-8450' Age. Zone. Environment. 8450-8790'? A~e. Zone. Environment. I: i II' 8790?-9100'T.D. ~ II ~ II ~ Age. Zone. Environment. Discussion. Early Cretaceous Valanginian (Probable Lower) F-13b Outer Neritic to Upper Bathyal (Outer Shelf to Upper Slope) Late Jurassic Kimmeridgian F -16a Middle to Outer Neritic (Middle to Outer Shelf) Late Jurassic Oxfordian (Probable Middle to Upper) F -16b Outer Neritic to Upper Bathyal (Outer Shelf to Upper Slope) Faunal change at 8790 feet. Definite Oxfordian foram marker species top at 8940 feet. 6 INTRODUCTION Scope Data from 69 Foraminifera samples from the Anadarko Altamura No.1 well were incorporated into this report. These samples consisted of 49 ditch and 20 conventional core samples covering the interval 7480 to 9100 feet total depth. This work was done as M.C.I. Job Number 22-107. Procedures I [ ¡ I [ [ I ¡ ,\ ! f Standard techniques were used to process the material. All samples were boiled in Quatemary-O and washed over 20 and 200 mesh screens. Frequency symbols correspond to the following numerical values: very rare (1), rare (2 - 4), frequent (5 -25), common (26 - 100), abundant (101 - 999) and prolific (1000+). Certain factors such as shelf widths, basin configuration and overall basin depths associated with Arctic Mesozoic basins are not completely understood at present. The paleoenvironments presented in this report reflect relative basinal position only and should not be tied to specific water depths. Generally, neritic corresponds to shelf or deltaic environments, while bathyal corresponds to slope or prodelta environments and bathyal (starved basin) corresponds to distal (far from the source) deposition. As an example, prodelta deposits could represent deposition as shallow as middle neritic or as deep as bathyal (slope) depending on the delta type and shelf width. With a narrow shelf, a river-dominated deltaic system could build across the shelf and the prodelta deposits would be in a bathyal ( slope) depth. A tide- dominated deltaic system associated with a wide shelf could result in middle neritic prodelta deposition. 7 Format A listing of the age, environment, fauna and occasional lithology comments for each biostratigraphic interval follows. A generalized summary of the well is presented in the Conclusions section at the end of the Foraminifera Report. A Foraminifera Distribution Chart (Figure F-1) and a High Resolution Biostratigraphy Plot (Figure B-1) containing foram diversity/abundance plots, a cumulative faunal plot and paleoenvironmental plot( s) are in pockets at the back of this report. I I I ! [ ¡ ( ¡ ./ 8 7480- 7 640' Age. Zone. Environment. Fauna. 7640-7720' Age. Zone. Environment. Fauna. RESULTS Early Cretaceous Aptian to Early Albian F-ll Middle to Lower Bathyal - Some Distal (Middle to Lower Slope & Some Starved Basin) Arenaceous spp., Gaudryina cf. tailleuri, frequent to common pyritized radiolaria including Lithocampe sp. N, and common to abundant paper shale below 7560 feet. Early Cretaceous Barremian F-12 Marginal Marine to Inner Neritic (Transitional to Inner Shelf) Thuramminoides sp., Haploph ragm 0 ides duoflatis, arenaceous spp. (large, coarse) and rare to frequent rounded frosted quartz floating sand grains. 9 7720-7840' Age. Zone. Environment. Fauna. I ¡ I ¡ r 1 /, ¡ l ¡ Earl y Cretaceous Hauterivian F-13a Middle Neritic (Middle Shelf) Bathysiphon granulocoelia, Gaudryina tappanae, G. tailleuri, Hap lop h ragm 0 ides du ofla tis, H. coronis, Lenticulina muensteri, L. sp. (raised sutures), arenaceous spp. (large, coarse), Glomospirella arctica, Lituotuba gallupi, Ammobaculites erectus, Nodosaria nana and rare to frequent rounded frosted quartz floating sand grains. 10 7840-8450' Age. Zone. Environment. Fauna. [ ! [ :1 I :1 i :! ~ II ! ~ r Early Cretaceous Valanginian (Probable Lower) F-13b Outer Neritic to Upper Bathyal (Outer Shelf to Upper Slope) Globulina canadensis, Ammobaculites erectus, A. reophacoides, arenaceous spp. (large, coarse), Hap loph ragm 0 ides coronis, H. duoflatis, H. inflatigrandis, H. goodenoughensis, Pseudobolivina sp., Gaudryina tailleuri, G. milleri, G. leffingwelli, Lenticulina muensteri, L. sp. (raised sutures), Trochammina conicominuta, T. squamata, Oolina apiculata, Saracenaria dutroi, S. valanginiana, Ammodiscus mackenziensis, Marginulina cephalotes,' Glomospirella arctica, Dentalina pseudocommunis, ostracods, pyrite, pyrite sticks and frequent to common rounded frosted quartz floating sand grains. 11 8450-8790'? Age. Zone. Environment. Fauna. ¡ \ I I I I I I ! ( ¡ 1 I [ Late Jurassic Kimmeridgian F-16a Middle to Outer Neritic (Middle to Outer Shelf) Arenaceous spp. (large, coarse), Globu/ina topagorukensis, Gaudryina leffingwelli, G. milleri, G. topagorukensis, G. dyscrita, Haplophragmoides spp., H. canui, Trochammina kosyrevae, T. instowensis, Nodosaria detruncata, Bathysiphon anomalocoelia, B. granulocoelia, Ammobaculites alaskensis, A. vetusta, A. barrowensis, Ammodiscus cheradospirus, A. asperus, Orientalia sp., Lenticu/ina toarcense, L. audax, pyrite, rare to frequent glauconite, rare to frequent rounded frosted quartz floating sand grains above 8585 feet, and frequent tar (dead oil staining?) below 8695 feet. 12 8790?-9100'T.D. Age. Zone. Environment. Fauna. I, l ! I [ ! ¡ ¡ ¡ I [ Discussion. Late Jurassic Oxfordian (Probable Middle to Upper) F-16b Outer Neritic to Upper Bathyal (Outer Shelf to Upper Slope) Ammodiscus asperus, A. orbis, A. cheradospirus, Trochamminoides sp. (small, thin), Haplophragmoides spp., H. canui, Ammobaculites barrowensis, A. alaskensis, Trochammina instowensis, Lenticulina audax, L. quenstedti, Marginulinopsis phragmites, M. carievalensis, Lingulina polita, Marginulina bergquisti, Astacolus dub ius, Vaginulina curva, V. sherborni, pyrite, pyrite sticks and frequent to common pyritized radiolaria. Faunal change at 8790 feet. Definite Oxfordian foram marker species top at 8940 feet. 13 l I {' I I I I ¡ l [ I I ! [ ! I I I CONCLUSIONS The Anadarko Altamura No.1 well penetrated the following biostratigraphic sequence based on foraminiferal analysis: . 360+ feet (7480-7840') of Hauterivian to Aptian or Early Albian age (Early Brookian & Beaufortian - Rift Sequence) marginal marine to middle shelf deposition overlain by middle to lower slope foresets and bottomsets. . 1260+ feet (7840-9100'T.D.) of Middle? or Upper Oxfordian to probable Lower Valanginian age (Beaufortian - Incipient Rift Sequence) middle shelf to upper slope sedimentation. 14 ~ 0 ~ ~ > ~ 0 ~ 0 ~ ~ ~ - ~ ..c ~ Q) ....... Q) - c.. - Q) ....... = ~ t'd b1) t'd == = ~ Q) ~ == ¡ PALYNOLOGY SUMMARY I I 7480-7560' I Age. Early Cretaceous Aptian - Early Albian ( Zone. P-MI8 Environment. Marginal Marine I l 7560-7720' [ Age. Early Cretaceous Barremian - Aptian I Zone. P-MI8a Environment. Marine ! I 7720- 7840' I Age. Early Cretaceous Hauterivian I Zone. P-MI9 Environment. Marine [ I I 16 ! f l 7840-8450' I Age. Early Cretaceous Valanginian I Zone. P-M20 I Environment. Marine - Marginal Marine I 8450-8790'? I Age. Late Jurassic Kimmeridgian l Zone. P- M21 I Environment. Marine [ 8 790? -91 OO'T.D. I Age. Late Jurassic Probable Oxfordian I Zone. Probable P-M22 I Environment. Marine I Remarks. Relatively weak evidence for Oxfordian. ! I [ 17 I f \ INTRODUCTION Purpose and Scope Micropaleo Consultants, Inc. (M.C.I.) conducted palynological analyses on a total of 69 samples from the Anadarko Altamura No.1 well. The samples consisted of 49 ditch cutting composites and 20 core samples taken between 7480 feet and 9100 feet total depth. Based on the palynomorph assemblages observed, an age and generalized environment of deposition were interpreted for each palynostratigraphic subdivision. The environments, as interpreted from the palynological preparations, are simply categorized as nonmarine, marginal marine or marine. The categories are based on the absence or the presence and diversity of microplankton cysts. Procedures The sample material was processed by Global Geolab Ltd., in Medicine Hat, Alberta, Canada. The samples were sent to the laboratory with coded depths. The analysis results are reported in actual depths. The samples were processed with standard palynologic techniques using hydrochloric acid, hydrofluoric acid and nitric acid treatments. The resultant kerogen residues were further concentrated by heavy liquid separation, sonification and a sieving/panning technique. Each sample slide has a mount of two coverslips. One slip contains the greater than 20 micron fraction and the second slip contains the 10-20 micron fraction. As each sample was examined, an estimate of abundance for each palynomorph taxon was recorded in a microcomputer. These data form the basic elements of the species distribution chart. 18 I I I I I I [ I I I I [ I I I I I [ Report Format The following Results section gives the age, environment of deposition and significant palynomorphs for each palynological subdivision. This is an expansion of the brief Summary at the beginning of the report. After the Results, some generalized interpretations are outlined in the Conclusions section. A Palynomorph Distribution Chart (Figure P-I) is located in the pocket. This chart records the occurrence and abundance of individual taxa in each sample. Included on this chart are the diversity and abundance curves for spore-pollen and microplankton cysts. High Resolution Biostratigraphy Plots-Foraminifera/Palynomorphs (Figure B-1) is also provided. Additional palynology parameters are shown in the form of a cumulative plot that illustrates the relative abundance of nonmarine, marine and miscellaneous palynomorph constituents. 19 l I I I I [ I I I I I I I I I I 7480-7560' Age. Zone. Environment. Palynomorphs. RESULTS Early Cretaceous Aptian to Early Albian P-M18 Marginal Marine This uppermost interval is assigned an Aptian - Early Albian age based mainly on negative evidence. The palynomorph assemblage is quite sparse. The forms recorded include the spores Deltoidospora and Gleicheniidites senonicus, and the dinocysts Cyclonephelium distinctum and Palaeoperidinium cretaceum. The absence of typical Middle - Late Albian marker species is used as evidence. 20 ! l I I I r ! I I I I I I I I I I I I 7560-7720' Age. Zone. Environment. Palynomorphs. Discussion. 7720-7840' Age. Zone. Environment. Palynomorphs. Early Cretaceous Barremian to Aptian P-M18a Marine An increase in dinocyst diversity and abundance marks this interval. The assemblage includes Fromea amphora, Micrhystridium sp., A, Gardodinium, Odontochitina operculata, Oligosphaeridium complex, Palaeoperidinium cretaceum and Senoniasphaera microreticulata. The organic recoveries in the upper part of this interval included an abundance of amorphous kerogen. Early Cretaceous Hauterivian P-MI9 Marine The Hauterivian interval recovered numerous marker dinocysts. These fonns included the species Florentinia cooksoniae, Herendeenia a laskens is , 1mbatodinium micropodum, Oligosphaeridium complex (thick-wall), Prionodinium alaskense, Pseudoceratium nudum and Tubotuberella uncinatum. 21 [ I I I I I I .1 I ,I ,! :1 I I :[ :1 :1 I 'I 7840-8450' Age. Zone. Environment. Palynomorphs. Early Cretaceous Valanginian P-M20 Marine to Marginal Marine The Valanginian section reflects an increase in spore- pollen abundance and includes numerous reworked fOnTIs. Recorded were fOnTIS such as Cicatricosisporites, Classopollis classoides, Densosporites (reworked), Endosporites (reworked), Gleicheniidites senonicus, Po do carp idites , Taeniaesporites (reworked) and Trilobosporites. The key dinocyst species are Gochteodinia villosa, G. verrucosa and Tubotuberella apatela. 22 \ I I I I I I I I I I I ! I [ I I I [ 8450-8790'? Age. Zone. Environment. Palynomorphs. Late Jurassic Kimmeridgian P-M21 Marine The spore-pollen assemblage of the Kimmeridgian interval remains similar to the Valanginian above; although, there is a reduction in occurrences. Rare occurrences of a few more reworked Paleozoic spores were also recorded. The dinocyst assemblage includes the fonns Chytroeisphaeridia pericompsa, Endoscrinium galeritum, Gonyaulacysta cladophora, G. jurassica, Pareodinia osmingtonensis, Sirmiodinium grossi and Tubotuberella apatela. Scattered occurrences of one Oxfordian and one Early - Middle Jurassic dinocyst species were noted. These fonns are deemed to be reworked into the Kimmeridgian interval. 23 I I ¡ I I I I I I ( I ( I I I I /, I 8790?-9100'T.D. Age. Zone. Environment. Palynomorphs. Discussion. Late Jurassic Probable Oxfordian Probable P-M22 Marine The probable Oxfordian interval is marked by a general decrease in palynomorph recoveries. The dinocyst species are most important to the age assignment. This assemblage includes Chytroeisphaeridia pericompsa, Endoscrinium galeritum, Gonyaulacysta cladophora and Nannoceratopsis pellucida. The age for this interval is qualified due to the rare occurrences of the marker species, Nannoceratopsis pellucida. 24 I l I I I I II II 1 II I .I :1 I II II II I I CONCLUSIONS Palynological analysis of the Anadarko Altamura No.1 well provides the following generalized palynostratigraphic succession: II II . Marginal marine Aptian - Early Albian strata occur from the top sample examined at 7480 feet to 7560 feet. . Marine Barremian - Aptian age strata are identified between 7560 feet and 7720 feet. . Marine Hauterivian age strata occur from 7720 feet to 7840 feet. . Marine to marginal marine strata of Valanginian age are seen between 7840 feet and 8450 feet. . Marine Late Jurassic, Kimmeridgian, strata occur between 8450 feet and 8790? feet. . Marine strata of probable Oxfordian age are interpreted to occur from 8790? feet to the base of the examined section at 9100 feet total depth. The Oxfordian assignment is based on weak palynomorph evidence. 25 doa-O/O . Core Petrophysics A ClIE IAllIAIVIIIS CDIIWIY ~ I" July 17, 2002 Anadarko Petroleum Corporation 17001 Northchase Dr. Houston, TX 77060 Attn: Mr. Don Kilgore Final Core Analysis Report Altamura NO.1 North Slope Alaska CPI File No. HOU-020315 Dear Mr. Kilgore Please accept my apology for the corrupt Excel file furnished with the final report as issued on June 26, 2002. The problem is not anything we have seen before. The current file is free of the problem; whatever may have caused it previously. The documentation, which precedes the data in the report, should be replaced with the accompanying pages. I have made the changes you suggested to Tom Swisher in your email of July 12, 2002. Calculation of the Klinkenberg permeability from the CMS-300 data is not a simple equation. In place of furnishing six pages of equations I have furnished the paper written by Stan Jones for SPE which explains the theory and gives mathematical support for the measurements as made with the CMS-300. Sincerely, Þ Art Curby Core Analysis Manager CORE LABORATORIES, INC. ~t2/ Ù- 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 ao;)~ 0/0 :í ( ANADARKO PETROLEUM CORPORATlv,'o MAIN 907/273-6300 3201 ...; STREET, SUITE 603. ANCHORAGE, ALASKA 99503 "1 J Anadi1r1(p~ .- ~ ~ ~ \ ,~ij~~:\S Ù¡ -\~"; ~\,' \\~,.ì '. , ,,:I¡"lISSlon DATE: TO: RECORD OF SHIPMENT May 14, 2002 FROM: Tommy Thompson Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 99503 (907) 273-6302 Mr. Thomas Maunder, PE Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 ( X) Enclosed ( ) Under separate cover ( ) Via Courier Subject: End of Well Report for Anadarko Altamura#1, BlM Permit AA-081736/3160, NPRA Alaska Quantity 2 2 2 2 1 1 1 2 cc: Well Name Description Well Completion or Recompletion Report and log (Forms 10-407a,b) Survey plat Final Wellbore Sketch Summary of Daily Drilling Operations Sepia, reproduction, and digital copy of mud log Complete set of washed, dried, and labeled drill cuttings Lithologic description of conventional cores Copy of core sample receipt NOTE: Please verify and acknowledge receipt. bv siqning and returning a coPY of this transmittal to the above address or fax to 907-563-9479. Signed b~1p~ -- Received ~~. t ",\0... \..J .~<c \ Date: kÁ, \ W ê) 00,' ,-\o.'{ 'l t 'Ø-.. Date: ~ .W ':"\ l'l;\. 0', 9- rt' \., q-V t7~' Remarks: ANADARKO PETROLEUM CORPORATI( 32'~ \ MAIN 907/ 273-6300 TREET. SUITE 603 . ANCHORAGE, ALASKA 99503 Anadarl(p! May 13, 2002 D f"'r'~"""!r:1f', ~~ ~;,.' l ~".. ~ ~!; r !} ~ ~'-.~ ,,~~ ~"I: i; ~ .~...,~ '1.- Mr. Thomas Maunder, PE Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 M,/\\,I "1 ,I ?U~OÎ ¡ l'.-.I I ""I' L. I... Alaska OH & Gas Cens" GomH\ìSSiDï Al1ch(tr~(le RE: End of Well Report for Anadarko Altamura #1, AOGCC Permit 202-010, NPRA Alaska Dear Mr. Maunder: Anadarko Petroleum Corporation hereby submits the End of Well Report for the above referenced well. Please be reminded that Anadarko Petroleum considers this information Proprietary and Confidential. Pertinent information attached to this filing includes the following: 1. Well Completion or Recompletion Report and Log (Foffi1s 10-407a,b) 2. Survey plat 3. Final Wellbore Sketch 4. Summary of Daily Drilling Operations 5. Sepia, reproduction, and digital copy of mud log (20 AAC 25.071 (b 1)) 6. Complete set of washed, dried, and labeled drill cuttings (20 AAC 25.071 (b2)) 7. Lithologic description of conventional cores (20 AAC 25.071 (b3)) Core chips, in accordance with 20 AAC 25.071 (b4), have been subn1itted per the attached receipt. Due tQ the LAS format, the verification listing required by 20 AAC 25.071 (b7), is unnecessary. The following information will be filed by August 1, 2002 pending further analysis (20 AAC 25.071 (b8)). 1. Core analysis 2. Fluid analysis 3. Reproduction and digital fonnat of LWD and E-Line logs Gr/Res/Dens/Neut/Sonic, MDT, USIT 4. Record of BOP drills Sincerely, ~i~' " Q ~~.-.J . ommy Thompsòn Drilling Superintendent enclosures , STATE OF ALASKA i ALASKA ðlL AND GAS CONSERVATiON ,-,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~r_.., OIL: GAS: 2. Name of Operator SUSPENDED: X ABANDONED: ,) . 7. Permit Number 202-010 Anadarko Petroleum Co. 3. Address 8. API Number 50- 103-20403-00 3201 C St., Suite 603, Anchorage, Ak 99503 4. Location of well at surface X = 284,420.30 E Y = 5,888,899.91 N CASING SIZE Conductor 9.625 -~,' v>, ~ ~l..ß, , - , . Unit or Lease Name . - 1/-..:-:-:::::=;:::-' Altamura ~:.':";¡ ~;:."'_';'L~ '0 r: ) ,:":- ~,. '~ 10. Well Number . ,¡.í)';z ~' 1 X = 284,589.26 E Y = 5,888,368.15 N : :i;:i,;iq;'_~'~-'~ t 11. Field and Pool "~,'-I.' " ~J ¡ 5. Elevation in feet (indicate KB, OF, etc.) 16. Lease Designation and Serial No. ~'''-'-'n,~_,",_".~.:,:J Rig Floor 29' 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 03/10/2002 04/02/2002 0~2002 ß Þ feet MSL 1 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9100 md/9014 tvd 9010 md/8924 tvd Yes: X No: 1539 feet MD 649 22. Type Electric or Other Logs Run Gr, Res, Sonic, NeutlDens MDT, USIT CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surf 105 Surf 2750 Surf 8501 8308 9096 At Top Producing Interval X = 284,582.41 E Y = 5,888,367.51 N At Total Depth 23. WT. PER FT. 65 40 26 12.6 GRADE H40 L-80 L-80 L-80 HOLE SIZE 7" 20" 12.25 8.5 6.125 CEMENTING RECORD Batch to surf 1846 ft3 to surf 196 ft3 class G 168 ft3 Lite Crete AMOUNT PULLED 41/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25. SIZE 3.50 TUBING RECORD DEPTH SET (MD) 8308 PACKER SET (MD) 8321 8557/8471 - 8575/8489 8590/8504 - 8655/8569 0.32 inch perfs, 6SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) NA Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 04/19/2002 17 TEST PERIOD => 0 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press. 0 0 24-HOUR RATE => 0 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Cut 180' (8545-8725). Recovered 178' (8545'-8723) See Core Report for more information. NA WA TER-BBL 0 WA TER-BBL 0 CHOKE SIZE I GAS-OIL RATIO 128/64 NIA OIL GRAVITY-API (corr) NIA E r::: r~ ~¡T\I f~ K: iL~.. "1 i!. 2:002 tÜaska 8;: G;:~~:~ C,I){Hi¡¡\¡,';SHi¡ , ;~neh(J;r~iue ORIGiNAL JUN 2 7 2002 Form 10-407 Rev. 7-1-80 R B OMS BF l CONTINUED ON REVERSE SIDE Submit in duplicate d~ 29, { 30. Ij' \ FORMATION TESTS GEOLOGIC MARKERS Base Permafrost TI Nanushuk T/HRZ B/HRZ TI Jurassic J-4 Unconformity MEAS. DEPTH 649 2854 7566 7719 8554 8656 Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR. and time of each phase. 649 2854 7480 7633 8468 Tested no flow 8570 NAME "'I. 'I £', 7:':,;'1 'L~ ::;~; f ~ -~ f'Ci i S S ~. U ,1 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe~\.~ Title~\ê M.6Q Date s( .4/07- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". OR I IN L Form 10-407 '~ dOd.-OJO a i:;,;;::S;("i ¡~:, ~~ ~. .::;i:::':J\.:i~)i~~;;" ANADARKO PETROLEUM CORP. ALTAMURA #1 SEC 30, T9N, R23 UM EXPLORA TION - NPRA NORTH SLOPE, ALASKA ( APRIL, 02, 2002 BRIAN 0 'FALLON - SENIOR LOGGING GEOLOGIST ANDREW BUCHANAN - SENIOR LOGGING GEOLOGIST ) 4~~ ALTAMURA#1 'ß .~ ANADARKO PETROLEUM CORP. AL TAMURA #1 SEC 30, T9N, R23 UM EXPLORA TION - NPRA NORTH SLOPE, ALASKA TABLE OF CONTENTS WELL RESU ME............................................................................................................. 2 LITHOLOGY AND CORE DESCRIPTIONS ................................................................... 3 SHOW REPORTS........................................................................................................ 31 DAILY ACTIVITY SU M MARY.. .............................................................. ............. ......... 37 ( GAS SA MPLES............................................................................................................ 39 SURVEY RECORD .. ......... ....... ..... ....... ......... ........ ......... ....... ..... .................................. 40 MUD REPORT.............................................................................................................. 42 BIT RECORD............................................................................................................... 43 SHIPPI NG MAN I FEST................ ................................................................................. 44 MORNING REPORTS............. .............. ............... ....... ........... ...... ........... ..................... 45 WELL LOGS................................................................................................ ..APENDIX 1 ( [=I EP()C-:H 1 " ~ Operator: Well Name: Location: Co-ordinates: Field: Borough, State: AFE Number: API index Number: Elevation: RKB: GL: Ice Pad: Spud Date: Surface Casing: Intennediate Casing: ( Total Depth: Core Interval: Company Representatives: Contractor: Rig: Epoch Personnel: Company Geologist: MWD Company: Driectional Driller: Wire Line Company: Cement Company: Mud Company: ( A-------a RA #1 .....~~ ALTAMU ""!oOIIÞI.rn-......., 'i 1\ WELL RESUME Anadarko Petroleum Corp. Altamura #1 Sec. 30, T9N, R23, UM 331'FSL, 22S8'FVVL Exploration - NPRA North Slope, Alaska 24272 50-1 03-20403-00 115' 82' 86' 03/10/2002 9 5/8" landed at 2748' Drilled to 8510' landed at 8500' 9100' 8545' to 8725' Darrel Green I Mike Whitely Nabors Alaska Drilling Inc. 14E Brian O'Fallon I Andrew Buchanan Tim Smith I Brady Kilmer Doug Beserescht, John Hartner Sperry Sun John Buckley Schlumberger Dowell/Schlumberger Baroid ~ EPOCH 2 -, ALTAMURA#1 ( LITHOLOGY AND CORE DESCRIPTIONS 105'-175' Sand = light gray overall; very fine to medium grained; predominantly subround; moderate sphericity; composed of 80% quartz, 20% lithies; very argillaceous in part; predominantly unconsolidated with occasional cuttings consolidated with clay matrix; common iron staining visible; common carbonaceous material in part (woody material); estimate fair to good intergranular porosity. 175' - 215' Clav = very light gray to light brownish gray; cohesive; hydrofissile; pasty consistency; mushy tenacity; predominantly amorphous cuttings; no visible fracture; commonly carbonaceous; common visible iron staining; abundant woody/coaly inclusions; no visible structure. 215' - 275' Sand = light gray to whitish gray; very fine to fine with rare coarser grains; angular to subround; low to moderate sphericity; moderately to well sorted; composed of 60% quartz, 30% lithics, 10% assorted minerals and carbonaceous material; occasional micO and pyrite; unconsolidated with occasional cuttings consolidated with clay matrix; estimate poor to fair intergranular porosity. 275' - 340' . Clay/Clavstone = medium gray to light brownish gray; soft and hydrophilic; some slightly firm, moderately silty and slightly hydrophilic; smooth to silty texture; occasional very light gray clays mostly with silty (ashy) texture; slight dark brownish gray carbonaceous disseminated matter, flak.es, and clasts; very slight micas; rare disseminated iron stained matter; trace possible chlorite; trace coal; non-calcareous. ( 340' - 390' Siltstone = very light gray to light brownish gray; soft to slightly firm; hydrophilic to slightly hydrophilic; very slight to slight finely disseminated carbonaceous matter; rare grading carbonaceous shale; some slightly sandy; mostly grading claystone to tuffaceous claystone. 390' - 470' Conalomeratic Sand/Conalomerate = light gray to grayish brown; very fine to coarse with abundant bit shattered very coarse and pebble size grains; angular to subround; poorly sorted; low to moderate sphericity; composed of 70% quartz, 20% lithies, 10% chert; occasional mica and pyrite; common disseminated carbonaceous material; rarely occurs as laminations; predominantly unconsolidated with rare to occasional well indurated with siliceous cement; common clay/ash matrix; occasional laminations of ash; estimate very poor to rare poor intergranular porosity. 470' - 530' Siltstone/Tuffaceous Siltstone = light gray to grayish white; predominantly hydrophilic; very soft to rare hard; predominantly amorphous cuttings; trace finely disseminated carbonaceous material; grades to and interbedded with clay; common visible glass shards in part; occasionally grades to welded tuff @ approximately 520'; rare grading to very fine sandstone; common laminations of tuffaceous ash. 530' Note: chips in 540' sample show shell fragments and calcite layers (slickensides?) with abundant carbonaceous material and pyrite. ( 555' - 605' Tuffaceous Ash = white to very light beige; predominantly very hydrophilic; very soft to occasional hard; predominantly occurs as amorphous lumps and as laminations in clay/silt/sand; occasional grades to welded tuff. [::I.EP()C=H 3 "A.....,..",~-..£~~ TAMURA #1 ~...~~~ AL ~'~:~:";~:-,~'''11.."- ~ 605' - 655' Clavstone/Tuffaceous Clavstone = very light gray to medium gray; predominantly hydrophilic; cohesive and adhesive in part; curdy to lumpy; predominantly occurs as amorphous lumps; earthy to matte luster; smooth to silty texture; common laminations of ash and silt; 582'-590' very cohesive, adhesive and malleable. 655' - 700' Siltstone/Tuffaceous Siltstone = light gray to grayish white; predominantly hydrophilic; very soft to rare hard; predominantly amorphous cuttings; trace finely disseminated carbonaceous material; grades to and interbedded with c'ay; occasiona' visible glass shards; common laminations of tuffaceous ash. 700' - 740' Clavstone/Tuffaceous Clavstone = very light gray to medium gray; predominantly hydrophilic; cohesive and adhesive in part; curdy to lumpy; predominantly occurs as amorphous lumps; earthy to matte luster; smooth to silty texture; common laminations of ash and silt. 740' - 785' Tuffaceous Ash = white to very light beige; predominantly very hydrophilic; very soft to occasional hard; predominantly occurs as amorphous lumps and as laminations in clay/silt/sand; waxy to sparkly luster; smooth to occasional gritty texture. 785' - 845' Claystone/Clay = medium gray with brownish hue to occasionally very light gray; soft to occasionally slightly firm; hydrophilic to moderately hydrophilic; smooth to earthy to slightly silty texture; slightly organic overall including very finely disseminated carbonaceous matter; very slight finely disseminated micro pyrite and possible micas; rare streaks and thin beds ash fall tuff. ( 845' - 910' Claystone/Organic Claystone = medium gray to medium dark gray; soft to moderately soft; hydrophilic to moderately hydrophilic; smooth to earthy to slightly silty texture; slightly to some moderately organic including very finely disseminated carbonaceous matter; very slight micro pyrite and possible micas; massive with occasional streaks and thin beds of ash fall tuff grading tuffaceous claystone; slight gas bubbles on fresh broken organic claystone. 910' - 965' Ash Fall Tuff = very light gray to yellowish gray to occasionally greenish gray; soft to very firm; smooth to slightly silty texture; dull to greasy luster; mushy to flaky in softer ash, to irregular angular fracture in dense ash; hydrophilic to non-reactive in water; massive to interbedded with slightly organic claystone to tuffaceous claystone. 965' - 1035' Clavstone/Oraanic Clavstone = medium dark gray to grayish brown to brownish gray; slightly firm to soft; moderately hydrophilic overall; earthy to smooth to slightly silty texture; flaky with incipient fissility to amorphous slightly to moderately organic including slight disseminated carbonaceous matter; slightly to very slightly scattered micro-pyrite speckles; massive to occasionally grading to tuffaceous claystone with interbedded ash fall tuff; non-calcareous. 1035' - 1090' Clavstone/Organic Claystone = medium dark gray to grayish brown; soft to slightly firm; hydrophilic to moderately hydrophilic; earthy to smooth texture; slight incipient fissility to amorphous; slightly organic overall with very slight visible disseminated carbonaceous matter and micro-pyrite speckles; some slightly tuffaceous with rare streaks volcanic ash; non-calcareous. ( [:I I:~P()( ~H 4 A!~~~~ Al TAMURA #1 ( 1090' -1160' Claystone/Organic Claystone = brownish gray to dark grayish brown; soft to occasionally slightly firm; hydrophilic to occasionally slightly hydrophilic; earthy to smooth to slightly silty texture; amorphous to slight incipient fissility; mostly slightly organic with very slight disseminated carbonaceous matter to moderately organic with streaks dark brown to rusty brown carbonaceous matter; some grading to tuffaceous claystone with occasional streaks ash fall tuff; non- calcareous. 1160' - 1215' Tuffaceous Siltstone = light brownish gray to very light gray; hydrophilic; very clayey grading to claystone: slightly sandy including very fine to fine grains; grading ash fall tuff and thinly bedded in claystone; slightly organic overall including disseminated matter and rare streaks; predominantly non-calcareous to thin streaks grading hard calcareous tuffaceous sandstone. 1215' - 1270' Tuffaceous Claystone = light brownish gray to medium dark gray to very light gray; soft to slightly firm; hydrophilic to moderately hydrophilic; silty to earthy texture; amorphous to slightly flaky; grading to tuffaceous siltstone and very fine angular grained ashy slightly calcareous sand; mostly slightly organic to occasionally grading organic claystone. 1270' - 1325' Silt/Sandstone = light brownish gray to very light gray; soft clayey silt grading to hard calcareous tuffaceous very fine grained angular sandstone and fine crystalline slightly calcareous tuff; silt mostly clayey grading to tuffaceous claystone and slightly organic claystone; locally moderately to very organic claystone with thinly bedded lignite. ( 1325' - 1365' Tuffaceous Siltstone = light brownish gray to very light gray; soft to slightly firm; very clayey grading to tuffaceous claystone; slightly to very slightly organic overall; hydrophilic; often coarse silt grading very fine to fine sand; non-calcareous. 1365' -1425' Claystone/Siltstone = medium gray with brownish hue to light brownish gray to light gray; moderately soft; hydrophilic; amorphous to flaky incipient fissility; slightly silty to silty texture; slightly to occasionally moderately tuffaceous; slightly organic overall with. very slight disseminated to flaky carbonaceous matter; trace micas and micro-pyrite; rare grading to tuff and organic claystone. 1425' - 1470' Claystone = medium gray with brownish hue; moderately soft and hydrophilic; very slightly to moderately silty texture; amorphous to flaky with incipient fissility; very slightly to slightly organic with very slight disseminated carbonaceous matter; slight disseminated very fine mica flakes and micro- pyrite. 1470' - 1540' Claystone = medium gray to medium light gray, often with brownish hue; smooth to silty texture; soft to slightly firm; hydrophilic to moderately hydrophilic; amorphous to slight incipient fissility; mostly very slightly organic; occasionally grading dark gray organic claystone and brownish gray moderately organic siltstone; slight disseminated carbonaceous matter and flakes increasing in organic siltstone; very slight to slight micro-pyrite and micas; locally interbedded lignite. ( 1540' - 1595' Sand = light gray; very fine to fine grains; angular; poorly sorted in ashy clay matrix; some grading to siltstone and claystone; non to some slightly calcareous to locally very calcareous hard sandstone; 75% quartz, and 25% carbonaceous matter, white to tan clay to pink and green grains; very poor visible porosity; no on indicators. [:I t~P()(:H 5 ~~~ AL TAMURA #1 ( 1595' -1655' SiltstonefTuffaceous Siltstone = light gray to grayish white; predominantly hydrophilic; very soft to rare hard; predominantly amorphous cuttings; matte to sparkly luster; silty to gritty texture; common visible coarser volcanic fragments; trace finely disseminated carbonaceous material; grades to and interbedded with clay; occasional visible glass shards; common laminations of tuffaceous ash; grades to and interbedded with sandstone. 1655' -1740' Sandstone = light gray to rare brownish gray; very fine to fine with occasional medium grains; angular to subangular; well to moderate sorting; moderate to low sphericity; composed of 80%-90% quartz, 10%-20% lithics and rare carbonaceous material; 50% matrix supported; poorly consolidated matrix and rarely siliceous cement; porosity predominantly infilled with clay ash matrix; rare cuttings show open porosity; occasional laminations of coaly material and ash; trace calcareous matrix; increasingly matrix supported and silty with depth; estimate predominantly very poor grading to fair intergranular porosity; no visible oil indicators. 1740' -1815' SiltstonefTuffaceous Siltstone = very light gray to occasional grayish brown; slightly to very hydrophilic; cohesive; soft to firm; irregular to massive cuttings; commonly eroded surfaces; matte to earthy to occasional sparkly luster; gritty texture; occasional visible bedding; common laminations of ash; trace disseminated carbonaceous material; commonly grades to very fine sandstone; very argillaceous in part; occasionally grades to carbonaceous siltstone; interbedded with clay and very fine sandstone. ( 1815' - 1860' Clavstone = light gray to medium grayish brown; hydrophilic; predominantly soft with occasional firm; crumbly and occasional dense and malleable; predominantly amorphous with occasional incipient fissility; trace to occasional carbonaceous material; common laminations of ash; grading to siltstone in part. 1860' - 1960' Sandstone = light to medium gray with occasional whitish gray; predominantly very fine to fine with rare medium grains; subangular to angular; well to moderate sorting; moderate sphericity; composed of 70% quartz, 30% lithics with rare assorted minerals and carbonaceous material; easily friable to firm; predominantly clay cement with trace siliceous cement; predominantly matrix supported with occasional grain supported; porosity infilled with clay/ash matrix, trace open porosity; grades to siltstone; interbedded with clay and silt; estimate very poor intergranular porosity with no visible oil indicators. 1960' - 2025' Siltstone = very light gray to light gray; slightly to very hydrophilic; predominantly cohesive; very soft to firm; irregular to massive cuttings, commonly eroded surfaces; dull earthy to occasional sparkly luster; gritty to abrasive; gritty texture; occasional visible bedding; occasional laminations of ash; trace disseminated carbonaceous material; rarely grades to very fine sandstone; very argillaceous in part; interbedded with claystone. 2025' - 2070' Claystone = light gray to medium grayish brown; hydrophilic; predominantly soft with occasional firm; crumbly and occasional dense and malleable; predominantly amorphous with occasional incipient fissility; trace to occasional carbonaceous material; rare laminations of ash; grading to siltstone in part. ( [:I ,EP()(:H 6 ~~~ AL TAMURA #1 l' ~ 2070' - 2135' Siltstone = very light gray to light gray; slightly to very hydrophilic; predominantly cohesive; very soft to firm; irregular to massive cuttings, commonly eroded surfaces; dull earthy to occasional sparkly luster; gritty to abrasive; gritty texture; occasional visible bedding; rare laminations of ash trace disseminated carbonaceous material; occasionally grades to very fine sand; very argillaceous; interbedded with and grading to claystone. 2135' - 2195' Claystone = light gray to medium gray to occasional brownish gray; slightly to very hydrophilic; crumbly to brittle with occasional firm and malleable; predominantly mushy consistency; usually occurs as amorphous lumps with occasional visible irregular to blocky fracture; massive cuttings habit; dull earthy to matte luster; smooth to gritty texture; occasional visible bedding; trace carbonaceous material. 2195' - 2255' Claystone = light gray to medium gray to occasional brownish gray; slightly to very hydrophilic; crumbly to brittle with occasional firm and malleable; predominantly mushy consistency; usually occurs as amorphous lumps with occasional visible irregular to blocky fracture; massive cuttings habit; dull earthy to matte luster; smooth to gritty texture; occasional visible bedding; trace carbonaceous material. 2255' - 2305' Claystone = light gray to medium grayish brown; hydrophilic; predominantly soft with occasional firm; crumbly and occasional dense and malleable; predominantly amorphous with occasional incipient fissility; trace to occasional carbonaceous material; common laminations of ash; grading to siltstone in part. ( 2305' - 2390' Claystone = medium light gray to occasionally medium dark gray and light gray; soft to rare firm; amorphous to some slightly flaky with incipient fissility; clayey to some fine silty texture; occasionany grading to siltstone and silty very fine grained clayey sandstone; trace hard calcareous sandstone; very slight finely disseminated carbonaceous matter to occasionally moderate with minor flakes and partings, especially siltstone and sandstone, and becoming light grayish brown; trace scattered micropyrite and micas; occasionally slightly calcareous especially firm dark gray clay. 2390' - 2465' Claystone = medium gray to some medium dark gray and light gray, some with brownish hue to light brownish gray; soft to occasionally firm, mostly moderately soft; smooth to slightly silty texture rare grading to siltstone; moderately hydrophilic to hydrophilic; amorphous to some flaky with slight incipient fissility grading shale; non to slightly calcareous; very slight to occasionally moderate finely disseminated carbonaceous matter and minor flakes; very slight scattered micropyrite and micas. 2465' - 2535' Sandstone = very light gray to light gray; very fine to fine and locally scattered medium grains; angular to subangular; poorly sorted and poorly consolidated in mostly matrix supported ashy clay matrix, to occasionally moderately well consolidated with calcareous clay cement; 50% quartz, and 50% gray to dark brownish gray to green to tan to white to pink grains and lithics to trace gold mica flakes; estimate very poor to occasionally poor porosity and permeability; no oil indicators. ( ~ EI'()(~l{ 7 ~.~) L TAMURA #1 ':':'~)¡:"~oJr¡'~ .~..;t."V, A ( 2535' - 2600' Siltstone = medium light gray to light gray some with brownish hue; slightly firm to moderately soft; moderately hydrophilic; intertaminated with claystone to grading to and interbedded with claystone and sandstone; amorphous to flaky with incipient fissility especially thinly laminated; overall slightly to very slightly organic including disseminated carbonaceous matter; very slightly scattered micropyrite and trace gold mica flakes. 2600' - 2640' Ash Fall Tuff = yellowish gray; slightly firm; malleable to crunchy; greasy to waxy luster; subplanar flaky fracture; lightly speckled carbonaceous matter and micropyrite; non-calcareous; slightly hydrophilic and very light gray when hydrated. 2640' - 2700' Claystone = medium gray with brownish hue; moderately soft to slightly firm; hydrophilic; amorphous to flaky with incipient fissility grading to shale; smooth to some moderately silty texture; common thin laminations of siltstone and minor light gray ashy sandstone partings; slightly organic overall; lightly speckled micropyrite and carbonaceous matter, non to slightly calcareous. 2700' - 2770' Claystone = medium gray with brownish hue; moderately soft to slightly firm; hydrophilic; amorphous to flaky with incipient fissility grading to shale; mostly smooth to slightly silty with thin laminations of siltstone; locally grading siltstone including some light gray and ashy; locally some thin streaks and beds of ash fall tuff; slightly organic overall including lightly speckled carbonaceous matter and traces micropyrite. ( 2770' - 2830' Claystone = light gray to medium gray to occasional brownish gray; slightly to very hydrophilic; crumbly to brittle with trace firm and malleable; predominantly mushy consistency; usually occurs as amorphous lumps with occasional visible irregular to blocky fracture; predominantly massive cuttings habit; dull earthy to matte luster; smooth to gritty texture; occasional visible bedding; commonly grades to and interbedded with siltstone. 2830' - 2905' Siltstone = very light gray to light gray; slightly to very hydrophilic; predominantly cohesive; very soft to firm; irregular to massive cuttings! commonly eroded surfaces; dull earthy to occasional sparkly luster; gritty to abrasive; gritty texture; occasional visible bedding; rare laminations of ash; rare trace grading to very fine sand; predominantly very argillaceous; interbedded with and grading to claystone. 2905' - 2965' Claystone = light gray to medium gray to occasional brownish gray; slightly to very hydrophilic; crumbly to brittle with trace firm and malleable; predominantly mushy consistency; usually occurs as amorphous lumps with occasional visible irregular to blocky fracture; predominantly massive cuttings habit; dull earthy to matte luster; smooth to gritty texture; occasional visible bedding; commonly grades to and interbedded with siltstone. 2965' - 3050' Sandstone = light gray of off white; very fine commonly grading to siltstone; predominantly subangular; moderate sphericity; predominantly well sorted; composed of 60% quartz; 40% lithics and assorted minerals with occasional carbonaceous material; consolidated with matrix binding the grains; 70%-80% grain supported; porosity predominantly infilled with clay matrix; rare cuttings show open porosity; interbedded with siltstone and clays; estimate very poor with trace poor intergranular porosity; occasional grains show dull yellowish orange fluorescence with a negligible cut; oil observed on shakers 3000'-3020'. ( [:I ,EP()(~H 8 ( ~~~ ALTAMURA#1 '~r:~'\;;";:\,.1.'~¡""~" ( ( 3050' - 3115' Siltstone = very light gray to light gray; slightly to very hydrophilic; predominantly cohesive; very soft to firm; irregular to massive cuttings, commonly eroded surfaces; dull earthy to occasional sparkly luster; gritty to abrasive; gritty texture; occasional visible bedding; rare laminations of ash; rare trace grading to very fine sand; predominantly very argillaceous; interbedded with and grading to claystone. 3115' - 3170' Claystone = medium light gray to medium gray; slightly firm to soft; slightly hydrophilic and crumbly to hydrophilic and mushy; often flaky to irregular sub splintery fracture; earthy to some silty fracture; trace to slight disseminated carbonaceous matter and associated trace to very slight micropyrite; trace micas; very slightly calcareous; rare waxy texture and tuffaceous. 3170' - 3235' Siltstone = medium gray to medium light gray; soft to some moderately firm; amorphous to flaky; very clayey; occurs as streaks and thin laminations in claystone; moderately hydrophilic overall; slight to very slight disseminated carbonaceous matter and traces of micropyrite~ slightly scattered very fine sand grains rare grading clayey sandstone; very slightly calcareous overall to locally soft white calcareous matter included (calcite). 3235' - 3310' Siltstone = medium gray to medium light gray; moderately firm to soft; flaky to amorphous; mostly clayey occurring as mostly thin laminations to thin beds in claystone; moderately hydrophilic; slight to very slight disseminated carbonaceous matter and traces of micropyrite; slightly scattered very fine sand grains to occasionally moderately clayey silty sandstone slightly speckled with very fine carbonaceous matter; non to very slightly calcareous; occasionally lightly speckled green grains possibly epidote. ( 3310' - 3370' Claystone = medium gray to medium light gray; soft to slightly firm; amorphous to flaky with slight incipient fissility and occasionally sub splintery some grading to shale; earthy to moderately silty texture with thinly interbedded siltstone and minor sandstone; very slight finely disseminated carbonaceous matter increasing slightly in siltstone very slightly calcareous increasing siltstone/sandstone. 3370' - 3425' Sandstone = light gray to medium light gray; moderately soft to firm; very fine grained to silty grading siltstone; very fine subangular grains; poorly sortéd in clay matrix; some slightly to moderately calcareous; mostly lightly speckled carbonaceous matter decreasing slightly when calcareous; rare lightly speckled green grains; estimate very poor to poor porosity; no oil indicated. 3425' - 3490' Claystone = medium \ight gray to medium dark gray with faint brownish hue; soft to s\ightly firm; flaky to amorphous to sub platy grading shale; earthy to silty texture with thin beds and laminations of clayey siltstone and minor very fine grained sandstone; hydrophilic decreasing with increasing silt; slight disseminated carbonaceous matter and flakes; very slight to trace to trace clustered micropyrite; non to very slightly calcareous. 3490' - 3550' Claystone = medium light gray some with faint brownish hue to medium dark gray; slightly firm to soft; sub platy to flaky with some incipient fissility grading to shale; moderately hydrophilic to hydrophilic; slightly to moderately silty texture with common thin laminations of siltstone; slightly organic overall including lightly speckled carbonaceous matter and micropyrite; non to slightly calcareous; rare very light gray ash. ( [:I ,EP()C:H 9 ~!~~~ ALTAMURA#1 ~'l.~\;,~,:-:,,~"'q ,.~Ií¡; 3550' - 3610' Siltstone = medium gray to medium light gray; slightly firm to soft; mostly very clayey and thinly bedded to thinly laminated in claystone; some moderately clayey and grading very fine grained sandstone with trace fine grains; very slight to trace moderate disseminated carbonaceous matter and flakes and associated very slight to slight scattered micropyrite; estimate some very poor to poor porosity; no oil indicated. 3610' - 3660' Sandstone = medium gray to medium light gray; very fine subangular to angular grains grading siltstone; poorly sorted slight to moderate clay matrix; slightly to some moderately calcareous; slight to occasionally moderate carbonaceous matter and traces micropyrite; estimate some poor to poor porosity due to clay infilling; no oil indicators. 3660' - 3730' Claystone = medium light gray to medium dark gray; slightly firm to soft; silty to earthy texture; moderately hydrophilic to hydrophilic; amorphous to sub platy to flaky with some subplanar incipient fissility grading to shale; often grading to and interlaminated with siltstone to very fine grained sandstone; very slight to slight disseminated carbonaceous matter and traces of micropyrite and possible mica; slightly calcareous overall especially siltstone. 3730' - 3805' Clavstone = medium light gray to medium dark gray with faint brownish hue; soft to slightly firm; hydrophilic to moderately hydrophilic; amorphous to sub platy to flaky with some subplanar incipient fissility grading to shale; moderately silty to earthy texture some grading to and interlaminated with siltstone to very fine grained sandstone; very slight to slight disseminated carbonaceous matter and traces of micropyrite and possible mica; non to some slightly calcareous especially siltstone. ( 3805' - 3855' Sandstone = medium to medium-dark gray; very fine grained grading to coarse silt dominantly angular quartz wI significant pale feldspars and lithics; dominantly clay matrix, generally poorly sorted; weak micro-bedding in places, generally massive texture; significant fine to medium scattered pyrite; little to no porosity; no oil indicators noted. 3855' - 3920' Clavstone = light gray to medium gray to occasional brownish gray; slightly to very hydrophilic; crumbly to brittle with trace firm and malleable; predominantly mushy consistency; usually occurs as amorphous lumps with occasional visible irregular to blocky fracture; predominantly massive cuttings habit; dull earthy to matte luster; smooth to occasional gritty texture; occasional visible bedding; occasional disseminated carbonaceous material; common pyrite in part. 3920' - 3985' Siltstone = light gray to light brownish gray; slightly to very hydrophilic; predominantly cohesive; very soft to firm; irregular to massive cuttings, commonly eroded surfaces; dull earthy to occasional sparkly luster; gritty to abrasive texture; occasional visible bedding; trace laminations of ash; rare trace grading to very fine sand; predominantly very argillaceous; interbedded with and grading to claystone; common disseminated carbonaceous material; occasional pyrite. 3985' - 4050' Clavstone = light gray to medium gray to occasional brownish gray; slightly to very hydrophilic; crumbly to brittle with trace firm and malleable; predominantly mushy consistency; usually occurs as amorphous lumps with occasional visible irregular to blocky fracture; predominantly massive cuttings habit; dull earthy to matte luster; smooth to occasional gritty texture; occasional visible bedding; occasional disseminated carbonaceous material; common pyrite in part. ( EI ,EP()C:H 10 ~~ ALTAMURA#1 C':::.h":,~~..t-1\:.,,-.,. .. 4050' - 4115' Sandstone = light to medium gray; very fine grading to siltstone; moderate sorting; moderate sphericity; composed of 60%-80% quartz; 20%-40% lithics, assorted minerals and carbonaceous material; interbedded with and grading to siltstone; loosely consolidated by matrix; grain and matrix supported; porosity predominantly infilled with clay matrix; occasional visible bedding; estimate very poor intergranular porosity; no visible fluorescence or cut. 4115' - 4195' Siltstone = light gray to light brownish gray; slightly to very hydrophilic; predominantly cohesive; very soft to finn; irregular to massive cuttings, commonly eroded surfaces; dull earthy to occasional sparkly luster; gritty to abrasive texture; occasional visible bedding; trace laminations of ash; rare trace grading to very fine sand; predominantly very argillaceous; interbedded with and grading to claystone; common disseminated carbonaceous material; occasional pyrite. 4195' - 4260' Clavstone = light gray to medium gray to occasional brownish gray; slightly to very hydrophilic; crumbly to brittle with trace finn and malleable; predominantly mushy consistency; usually occurs as amorphous lumps with occasional visible irregular to blocky fracture; predominantly massive cuttings habit; dull earthy to matte luster; smooth to occasional gritty texture; occasional visible bedding; occasional disseminated carbonaceous material; common pyrite in part. 4260' - 4330' Siltstone = light gray to light brownish gray; slightly to very hydrophilic; predominantly cohesive; very soft to finn; irregular to massive cuttings, commonly eroded surfaces; dull earthy to occasional sparkly luster; gritty to abrasive texture; occasional visible bedding; trace laminations of ash; rare trace grading to very fine sand; predominantly very argillaceous; interbedded with and grading to claystone; common disseminated carbonaceous material; occasional pyrite. ( 4330' - 4405' Claystone = medium gray with faint brown hue to some medium dark gray; soft and hydrophilic to slightly finn and moderately hydrophilic; amorphous to some slightly flaky to sub platy rare grading shale; earthy to slightly silty texture occasionally grading to siltstone; very slightly organic overall including very lightly speckled very fine carbonaceous matter to rare with moderate flakes and partings; trace micropyrite; mostly non calcareous to occasionally slightly calcareous and occasional calcite, possible fracture fill. 4405' - 4465' Shale = medium dark gray; slightly finn; slightly to moderately hydrophilic; slightly silty texture occasionally grading to siltstone; uneven sub platy cuttings with some visible fissility to incipient fissility grading to claystone; occasionally slightly calcareous especially siltstone; slightly organic including faintly speckled carbonaceous matter and micropyrite and possible mica. 4465' - 4520' Siltstone = medium gray with brownish hue and soft to slightly finn and hydrophilic, to some medium light gray and calcareous and non to slightly hydrophilic; moderately clayey grading to and occurring as thin beds and laminations in claystone; slightly organic overall including lightly speckled organic matter and traces micropyrite; trace pyrite cluster. 4520' - 4585' Claystone = medium gray with faint brown hue to some medium dark gray; soft and hydrophilic to slightly firm and moderately hydrophilic; amorphous to some slightly flaky to sub platy rare grading shale; earthy to silty texture some grading to siltstone; slightly to very slightly organic overall including very lightly speckled very fine carbonaceous matter to rare with moderate flakes; lightly scattered micropyrite; non to occasionally slightly calcareous. j \ [:I ,EP()C:H 11 A~;¡ AL TAMURA #1 4585' - 4645' Claystone = medium dark. gray to medium gray, with brownish hue; sub platy to amorphous cuttings with occasional incipient fissility grading to shale; moderately silty to slightly sparkly texture; slightly organic overall including lightly speckled disseminated carbonaceous matter and flakes; very slightly to occasionally moderately speckled micropyrite and possible micas. 4645' - 4710' Claystone = medium dark. gray to medium gray, with brownish hue; sub platy to amorphous cuttings with occasional incipient fissility grading to shale; moderately silty to earthy texture; some siltstone; slight\y sparkly luster; lightly speckled disseminated carbonaceous matter and flakes; overall slightly organic clays; lightly to very lightly speckled micropyrite and possible micas. 4710' - 4770' Siltstone = medium to occasional dark gray; soft to occasional finn; irregular cuttings with eroded edges; indetenninate fracture; predominantly quartzose with abundant disseminated laminar carbonaceous material; very argillaceous in part; occasional visible bedding; commonly grades to very fine sandstone; gritty to abrasive texture; earthy to occasional vitreous luster; interbedded with clays. 4770' - 4840' Sandstone/Sand = light gray to rare medium gray; very fine grading to silt to fine with trace medium grains; angular to occasional subangular; moderate to well sorted; low to moderate sphericity; composed of 60%-80% quartz, 20%-40% lithies, assorted minerals and carbonaceous material; 80%-90% poor consolidated with matrix, 10%-20% unconsolidated; porosity predominantly infilled with matrix; estimated very poor intergranular porosity; 30% of sandstone cuttings show pale whitish yellow fluorescence (matrix?); with no visible cut. ( 4840' - 4900' Claystone = medium dark gray to medium gray, with brownish hue; sub platy to amorphous cuttings with occasional incipient fissility grading to shale; moderately silty to earthy texture; some siltstone; slightly sparkly luster; lightly speckled disseminated carbonaceous matter and flakes; overall slightly organic clays; lightly to very lightly speckled micropyrite and possible micas. 4900' - 4965' Siltstone = medium to occasional dark gray; soft to occasional firm; irregular cuttings with eroded edges; indetenninate fracture; predominantly quartzose with abundant disseminated laminar carbonaceous material; very argillaceous in part; occasional visible bedding; commonly grades to very fine sandstone; gritty to abrasive texture; earthy to occasional vitreous luster; rare cuttings show a faint whitish yellow fluorescence «3%, mineral?); no visible cut. 4965' - 5030' Claystone = very light gray to medium dark gray with brownish hue; moderately to very hydrophilic; crumbly to occasional malleable; predominantly amorphous to sub blocky cuttings; dull earthy to matte luster; smooth to occasional silty texture; interbedded with and commonly grading to siltstone; common disseminated carbonaceous material; common to abundant disseminated and granular pyrite; rare visible mica; common visible banding; rare laminations of tuffaceous ash. 5030' - 5110' Siltstone = medium to occasional dark gray; soft to occasional finn; irregular cuttings with eroded edges; indetenninate fracture; predominantly quartzose with abundant disseminated laminar carbonaceous material; very argillaceous in part; occasional visible bedding; commonly grades to very fine sandstone; gritty to abrasive texture; earthy to occasional vitreous luster; rare cuttings show a faint whitish yellow mineral fluorescence. ( I " (:I ,El--'( )C:H 12 \:'~:tc.~,~J'1'\ l~Of~~r~pIILr:-1 AL TAMURA #1 5110' - 5180' Sandstone = very light to light gray; very fine to fine with very rare medium grains; angular; moderately to well sorted; moderate sphericity; composed of 60% to 80% quartz, 20%-40% lithies, assorted minerals and carbonaceous material; 70%-90% consolidated with matrix and minor calcareous cement; matrix and grain supported; commonly grades to siltstone; porosity predominantly infilled with clay/ash; estimate very poor intergranular; common pale whitish yellow mineral fluorescence from matrix. 5180' - 5245' Siltstone = medium to occasional dark gray; soft to occasional firm; irregular cuttings with eroded edges; indeterminate fracture; predominantly quartzose with abundant disseminated laminar carbonaceous material; very argillaceous in part; occasional visible bedding; commonly grades to very fine sandstone; gritty to abrasive texture; earthy to occasional vitreous luster; rare cuttings show a faint whitish yellow mineral fluorescence. 5245' - 5310' Claystone = very light gray to medium dark gray with brownish hue; moderately to very hydrophilic; crumbly to occasional malleable; predominantly amorphous to sub blocky cuttings; dull earthy to matte luster; smooth to occasional silty texture; interbedded with and commonly grading to siltstone; common disseminated carbonaceous material; common to abundant disseminated and granular pyrite; rare visible mica; common visible banding; rare laminations of tuffaceous ash. ( 5310' - 5380' Siltstone = medium to occasional dark gray; soft to occasional firm; irregular cuttings with eroded edges; indeterminate fracture; predominantly quartzose with abundant disseminated laminar carbonaceous material; very argillaceous in part; occasional visible bedding; commonly grades to very fine sandstone; gritty to abrasive texture; earthy to occasional vitreous luster; abundant disseminated pyrite through out clays and siltstone in samples. 5380' - 5440' Claystone = medium gray to medium dark gray, with brownish hue; soft to slightly firm; sub platy with wedge shaped to rounded edges and slight visible fissility grading shale; silty to earthy texture; often grading to siltstone and minor very fine grained sandstone; slightfy organic overall including very lightly to lightly speckled carbonaceous matter and micropyrite; trace micas; non-calcareous. 5440' - 5515' Siltstone = medium light gray to brownish gray; soft to slightly firm; moderately to very clayey; often sandy grading poorly sorted sandstone with very fine to fine angular grains in a silty to clayey and slightly calcareous matrix; lightly to some moderately spotted to speckled carbonaceous matter and flakes; traces of pyrite to micropyrite; very poor to poor visible porosity and permeability; possible fracture porosity; 5-10% dull yellow fluorescence possible mineral on light gray sandstone; trace faint diffuse cut. 5515' - 5585' Siltstone = medium light gray to brownish gray; soft to slightly firm; moderately to very clayey; slightly sandy to poorly sorted sandstone with very fine to fine angular grains in a silty to clayey and slightly calcareous matrix; lightly to some moderately spotted to speckled carbonaceous matter and flakes; traces of pyrite to micropyrite; very poor visible porosity and permeability; 5% dull to very dull yellow possible mineral fluorescence with trace faint diffuse cut. ( 5585' - 5635' Claystone = medium gray to medium dark gray, with brownish hue; soft to some slightly firm; moderately silty to earthy texture; hydrophilic; some grading to siltstone and minor very fine grained sandstone; very slightly organic overall including very lightly speckled carbonaceous matter and traces of micropyrite; non-calcareous. ~~'I~(')(~H'- ~ I~ M .~... 13 ~~ ALTAMURA#1 5635' - 5705' Sandstone = medium light gray; very fine grains with scattered fine grains grading to coarse siltstone; angular; poorly sorted in clay/possible ashy matrix; occurs as mostly thin beds and laminations in claystone; poorly consolidated to friable; 70% quartz, and 30% lithics including mostly carbonaceous flakes and fines; traces of micropyrite; non to occasionally very poor visible porosity; very dull yellow fluorescence possibly mineral with trace faint diffuse cut. 5705' - 5770' Clavstone = medium gray with brownish hue to medium dark gray; soft and hydrophilic to slightly finn and slightly hydrophilic; sub platy with rounded to wedge shaped edges with occasional incipient fissility; smooth to silty texture often grading to siltstone; parts readily on rare light gray sandstone lamination; slightly organic overall including very lightly speckled carbonaceous matter and traces of micropyrite; non-calcareous. 5770' - 5835' Siltstone = medium gray with brownish hue to medium light gray; slightly finn to moderately soft; often coarse silt grading very fine grained sandstone; slightly to some moderately hydrophilic; thinly interlaminated with and often grading to claystone; very lightly speckled carbonaceous matter and flakes and traces micropyrite; very slightly to slightly calcareous; light gray color possible due to ash in matrix. 5835' - 5900' Claystone = brownish gray to medium gray; soft to slightly finn especially moderately soft; hydrophilic; silty to earthy to smooth texture; sub platy with rounded edges and faint incipient fissility grading to shale; some grading to siltstone and minor sandstone including thin beds and laminations; probably slightly ashy overall; slightly organic overall including lightly speckled carbonaceous matter and traces of micropyrite; non-calcareous. ( 5900' - 5960' Siltstone = medium light gray to brownish gray; very friable to slightly finn; some grading to very fine grained sandstone with white clay/ possibly ashy matrix; grading to and interbedded to interlaminated with claystone; mostly very slightly to slightly organic with lightly scattered carbonaceous matter, trace thin carbonaceous partings; very poor porosity, 5% fluorescence and diffuse cut. 5960' - 6045' Sandstone = light gray to medium gray; salt and pepper appearance; very fine to medium grains; very poorly sorted; very angular overall; low to moderate sphericity; composed of 70% quartz, 30% lithics, assorted minerals with abundant carbonaceous material; >95% consolidated; predominantly poorly matrix cemented with common well siliceous cemented grains; 70% grain supported; porosity infilled with matrix with very rare cuttings showing open porosity; estimate very poor intergranular porosity; rare grains show dull pale yellow mineral and organic fluorescence; no visible cut; rare trace bleeding gas. 6045' - 6105' Siltstone = medium to occasional dark gray; soft to occasional firm; irregular cuttings with eroded edges; indetenninate fracture; predominantly quartzose with abundant disseminated laminar carbonaceous material; very argillaceous in part; occasional visible bedding; commonly grades to very fine sandstone; gritty to abrasive texture; earthy to occasional vitreous luster; occasional pyrite. ( ~ :EP()C::H 14 .~.i¡i MURA #1 - - C"""""" AL T A ...'r~~'I~\~,;~r!~ ,...,... 6105' - 6185' Sandstone = light to medium gray with a salt and pepper appearance; very fine to medium grains; very angular to sub angular; moderately to low sphericity; very poor to moderately sorting; 60% quartz 40% lithics, assort minerals and abundant carbonaceous material; poor to moderately consolidated with matrix; matrix hydrophilic and rapidly hydrates; predominantly grain supported with predominantly long grain contacts; occasional well cemented with siliceous cement; porosity predominantly infilled with matrix; very rare open porosity; estimate very poor intergranular porosity; dull pale yellow fluorescence with a very slow, weak, light greenish yellow fluorescence; observed very minor oil on shaker; faint petroliferous odor. 6185' - 6245' Claystone = very light gray to medium dark gray with brownish hue; moderately to very hydrophilic; crumbly to occasional malleable; predominantly amorphous to sub blocky cuttings; dull earthy to matte luster; smooth to occasional silty texture; interbedded with and occasional grading to siltstone; occasional disseminated carbonaceous material; trace pyrite; rare visible mica; common visible banding; rare laminations of tuffaceous ash. 6245' - 6330' Sandstone/Sand = light to medium gray; salt and pepper; very fine to fine grained; moderate sorting; sub angular overall; moderate sphericity; composed of 50%-60% quartz; 40%-50% lithics, assorted minerals, mica, carbonaceous material; 60%-70% consolidated; whitish clay/ash matrix infilling . porosity; 70% grain supported; abundant unconsolidated grains assoc with clay matrix visibly breaking down; abundant disseminated pyrite; porosity; entirely infilled with matrix; estimated very poor intergranular porosity; 40% shows pale yellow fluorescence; very slow, very weak, yellowish green fluorescent cut; minor free oil observed while washing; trace petroliferous odor. ( 6330' - 6405' Siltstone = medium to occasional dark gray; soft to occasional firm; irregular cuttings with eroded edges; indeterminate fracture; predominantly quartzose with abundant disseminated laminar carbonaceous material; very argillaceous in part; occasional visible bedding; commonly grades to very fine sandstone; interbedded to interlaminated with claystone; occasional very poor visible porosity in sandstone; 1 % very dull yellow green fluorescence; very faint diffuse cut. 6405' - 6460' Claystone = brownish gray to medium gray; soft and very hydrophilic to slightly firm and slightly hydrophilic; smooth ashy texture to silty; common interlaminated siltstone to minor sandstone; slightly organic overall with lightly scattered carbonaceous matter to occasional flakes and partings; very lightly speckled micropyrite; slight calcareous streaks. 6460' - 6535' Sandstone = light gray overall; salt and pepper grains; very fine angular grains grading siltstone; poorly sorted in ashy clay matrix; slight overall calcareous cement; moderately well to poorly consolidated; matrix slightly soluble overall; 60% quartz, and 40% mostly black and minor tan lithics including carbonaceous matter; thinly bedded and interlaminated in claystone and siltstone; non to very poor visible porosity and permeability; 5% very dull green yellow fluorescence and trace diffuse cut. ( 6535' - 6630' Shale = medium dark gray to medium gray, with brownish hue; moderately soft to slightly firm; moderately hydrophilic overall; sub platy wedge shaped cuttings with slight visible fissility; occasionally thinly laminated and flaky with very thin carbonaceous partings; slightly organic to occasionally moderately organic grading to carbonaceous shale; overall poorly developed structure grading to claystone; earthy to slightly silty texture with some thin zones and laminations of siltstone and sandstone; claystone slightly ashy overall occasionally grading tuffaceous claystone; very slight micropyrite associated primarily with carbonaceous partings and matter; non-calcareous. [:;I ,EP()(~H 15 ~~~ AL TAMURA #1 ~ ~;¡.t::'\;4ir~>:1'Ll-:",I .V 6630' - 6720' Claystone = medium gray to medium light gray to occasionally medium dark gray, mostly with faint brownish hue; slightly firm and slightly hydrophilic to soft and hydrophilic; mostly slightly ashy some grading tuffaceous claystone and occasional thin laminations of ash; common incipient fissility grading shale; earthy to some fine silty texture; dull to slightly sparkly luster; occasional grading to and interlaminated siltstone; slightly to very slightly organic overall including very lightly speckled to rare flakes and partings of carbonaceous partings; slight very finely disseminated micropyrite and possible micas; no calcareous. 6720' - 6800' Shale = medium gray to some medium dark gray, with faint brownish hue; slightly firm to moderately soft; sub platy with slight incipient fissility to some fissile with very thin to remnant carbonaceous partings; faintly speckled micropyrite with matte luster on partings; dull luster overall; earthy to some very fine silty texture; slightly to moderately hydrophilic; often slightly ashy; poor structure grading to claystone especially ashy; some light gray tuffaceous claystone and occasional thin ash laminae; slightly to occasionally moderately organic; no calcareous 6800' - 6865' Siltstone = medium gray to medium light gray; friable to firm; thin beds and laminations in claystone and shale; often coarse siltstone grading to very fine angular grained sandstone; very slightly calcareous reacting slowly in HCI as probably slightly siliceous; lightly speckled carbonaceous matter and traces of pyrite; mostly grain supported in ashy clay matrix; trace dull green yellow fluorescence and trace diffuse cut. ( 6865' - 6940' Sandstone = medium light gray to some medium gray; very fine subangular to angular grains grading to siltstone; locally slight loose angular fine to medium lower grains; poorly sorted to some moderately well sorted in mostly clay; trace calcareous cement; friable to moderately consolidated; mostly grain supported; lightly speckled to slight flakes and very thin partings of carbonaceous matter and traces of micropyrite; grains mostly quartz to some brown tuff in coarser sand; estimate very poor to some fair porosity; very dull yellow green fluorescence and no cut. 6940' - 7005' Claystone = medium gray to medium light gray to occasionally dark gray; soft to slightly firm; common incipient fissility grading to shale; slightly to some very hydrophilic grading tuffaceous claystone; earthy to fine silty texture locally with laminations and thin beds of siltstone and sandstone; lightly speckled carbonaceous matter and traces pyrite to some with remnant flakes and very thin partings partially altered to micropyrite; non-calcareous. 7005' - 7065' Siltstone = light gray to medium gray; irregular to sub blocky to occasional planar fracture; massive to sub tabular cuttings; easily friable to occasional stiff; predominantly quartzose; very argillaceous; occasional carbonaceous streaks; common disseminated pyrite; occasional ashy laminations; commonly grades to very fine sandstone. 7065' - 7130' Claystone = very light gray to medium dark gray with brownish hue; moderately to very hydrophi\ic; crumbly to occasional malleable; predominantly amorphous to sub blocky cuttings; dull earthy to matte luster; smooth to occasional silty texture; interbedded with and occasional grading to siltstone; occasional disseminated carbonaceous material; trace pyrite; rare visible mica; common visible banding; commonly grades to silty shale in part; common laminations of tuffaceous ash. ( [1 Er'()(~H 16 ~;'i TAMURA #1 '~'~'\,I ~~-;''.'_Jn~ ::"''1~:VrI\f, c. AL 7130' - 7200' Sandstone = light to medium gray with salt and pepper appearance; very fine to fine grading to lower medium; moderately sorting; very angular to subangular; low to moderately sphericity; 50% quartz, 50% lithics with abundant mafics, common carbonaceous material; predominantly consolidated with increase unconsolidated with depth; predominantly easily friable with matrix cement and occasional moderately hard with trace calcareous and siliceous cement; interstices entirely infilling with clay/ashy matrix; estimated very poor approaching nil porosity in part shows very wk dull yellow-green fluorescence with very slow, very wk, milky greenish white cut; trace oil on shakers. 7200' - 7265' Sandstone/Sand = light gray with salt and pepper appearance overall; very fine to fine with increasing medium grains; moderately to occasional well sorted; angular to subround; moderately sphericity; composed of 60% to 80% quartz, 40%-60% lithics with common carbonaceous material; decreasingly consolidated with depth; predominantly unconsolidated by 7230'; consolidated cuttings rapidly disaggregates; consolidated cuttings infilled with matrix; estimated very poor intergranular porosity; very weak dun greenish fluorescence with a negHgible cut. 7265' - 7335' Sandstone = light gray overall with occasional salt and pepper appearance; very fine to fine with rare medium grains; predominantly subangular; well to moderately well sorted; moderately sphericity; 70% quartz, 30% lithics with abundant carbonaceous material; consolidated; matrix and grain supported; increasingly matrix supported with depth 7300'-7400'; friable; matrix moderately hydrophilic; common visible bedding; common laminations of carbonaceous material; estimated very poor intergranular porosity; very faint greenish fluorescence with no discernable cut. ( 7335' - 7395' Sandstone = light to medium gray with salt and pepper appearance; very fine to fine grading to lower medium; moderately sorting; very angular to subangular; low to moderately sphericity; 50% quartz, 50% lithics with abundant mafics, common carbonaceous material; predominantly consolidated with increase unconsolidated with depth; predominantly easily friable with matrix cement and occasional moderately hard with trace calcareous and siliceous cement; interstices entirely infilling with clay/ashy matrix; estimated very poor approaching nil porosity in part shows very weak greenish fluorescence. 7395' - 7455' Claystone = very light gray to medium dark gray with brownish hue; moderately to very hydrophilic; crumbly to occasional malleable; predominantly amorphous to sub blocky cuttings; dull earthy to matte luster; smooth to occasional silty texture; interbedded with and occasional grading to siltstone; occasional disseminated carbonaceous material; trace pyrite; rare visible mica; common visible banding; rare laminations of tuffaceous ash. 7455' - 7500' Siltstone = light gray to medium gray; irregular to sub blocky to occasional planar fracture; massive to sub tabular cuttings; easily friable to occasional stiff; predominantly quartzose; very argillaceous; occasional carbonaceous streaks; common disseminated pyrite; occasional ashy laminations; commonly grades to very fine sandstone. 7500' - 7545' Shale = light to medium gray; firm to stiff; fissile; irregular to wedge like cuttings; sub planar to splintery cuttings; dull earthy luster; smooth texture; occasionally grading to clay; rare carbonaceous material; silty in part; occasional disseminated micro pyrite. ( " l:;S :EP()C=H 17 :~, ~"o,;",,,1',C<,~'-'ç¡<,, AL TAMURA #1 ( 7545' - 7615' Carbonaceous Shale = medium dark gray with slight brownish hue; slightly firm and slightly malleable to crunchy; very fissile with abundant to moderate very thin carbonaceous clay partings in variably organic tuffaceous claystone; earthy to velvety luster as carbonaceous matter mostly altered to clay with faint sheen of micropyrite; occasional black flakes on partings; occasionally grading to tuffaceous siltstone; trace calcareous; slight bleeding gas on partings. 7615' - 7690' Shale = medium gray to brownish gray; slightly firm and crunchy and slightly malleable; fissile to wedge shaped; velvety to earthy texture with moderate to abundant very thin organic clay partings mostly with sheen to faint sheen of micropyrite and trace pyrite clusters; often grading to carbonaceous shale with decreasing pyrite; occasional thin zones and laminations of light gray to slightly pyritic light bluish gray to yellowish gray tuffaceous shales and siltstone; trace calcareous; slight bleeding gas on partings. 7690' - 7755' Shale = dark brownish gray to medium gray with brownish hue; slight\y firm and crunchy; fissile to wedge shaped to splintery; earthy to very slightly velvety texture; moderately organic to organic grading carbonaceous shale with mostly moderate to abundant very thin partings of dark organic clay and carbonaceous matter; very lightly speckled to occasional faint sheen of micropyrite; some grading hydrophilic tuffaceous claystone; trace calcareous. 7755' - 7800' Claystone = brownish gray; soft and hydrophilic; moderately ashy grading to tuffaceous claystone; moderately to slightly organic grading to and inter laminated with carbonaceous shale; common very thin organic partings; smooth to earthy texture; traces pyrite; non calcareous. ( 7800' - 7870' Shale = medium dark gray to brownish gray to occasionally medium gray; slightly firm and crunchy, to soft and hydrophilic grading tuffaceous claystone; abrasive very fine silty texture to earthy; sub platy to wedge with some incipient fissility to occasionally fissile with carbonaceous partings grading carbonaceous shale; mostly slightly organic with slight to moderate fine silt and slight disseminated pyrite; slightly calcareous including trace siderite. 7870' - 7930' Siltstone = brownish gray to medium dark gray; slightly firm to friable; very fine silty texture; sub platy with slight incipient fissility; clayey grading to shale and minor tuffaceous claystone; slightly organic overall including lightly speckled carbonaceous matter and micropyrite to pyrite; some gritty occasionally grading to very fine grained sandstone; very slightly calcareous. 7930' - 7990' Shale = brownish gray to medium dark gray; moderately soft to slightly firm; some hydrophilic grading to tuffaceous claystone; abrasive fine silty to some earthy texture; grading to siltstone and minor very fine to fine grained sandstone; slightly organic overall including slight disseminated carbonaceous matter and occasional flakes; non-calcareous. 7990' - 8060' Shale = brownish gray to medium dark gray; moderately soft to slightly firm; occasionally grading to hydrophilic claystone; abrasive fine silty to some earthy texture; grading to siltstone in part; slightly to occasionally very organic; grades to carbonaceous shale in part; rare disseminated pyrite and common granular occasionally occurring as borrow casts; occasional laminations of tuffaceous ash; abundant visible degassing of shale and tuffaceous clay observed in the 8020' sample. ( [:I F~P()(~H 18 þ~] ALTAMURA#1 ~ìt:'~,:~.:'::..;:n .. '" I { 8060' - 8110' Siltstone = light gray to brownish gray; finn to occasionally moderately hard; irregular to sub planar fracture; predominantly massive to sub tabular cuttings; earthy to occasional vitreous luster; gritty grading to abrasive texture; occasional ashy laminations; common pyrite laminae; rare carbonaceous material; occasional tuffaceous ash laminae; grades to shale. 8110' - 8175' Shale = brownish gray to medium dark gray; moderately soft to slightly finn; rarely grading to hydrophilic claystone; abrasive to silty to earthy texture; very rarely; grading to siltstone; slightly to occas\onaUy very organic~ commonly grades to carbonaceous shale~ abundant dissem\nated and granular and laminae of pyrite; common pyrite infilling borrow; very rare laminations of tuffaceous ash; trace visible degassing of shale. 8175' - 8230' Shale = brownish gray to medium dark gray; moderately soft to slightly finn; rarely grading to hydrophilic claystone; abrasive to silty to earthy texture; very rarely; grading to siltstone; slightly to occasionally very organic; commonly grades to carbonaceous shale; abundant disseminated and granular and laminae of pyrite; common pyrite infilling borrow; very rare laminations of tuffaceous ash. 8230' - 8290' Tuffaceous Claystone = light tan to medium brown; moderately hydrophilic; soft to crumbly; irregular blocky fracture; massive eroded cuttings; matte to earthy luster; smooth to rare gritty texture; trace carbonaceous material; abundant ashy laminations; grading to and interbedded with shale; non-calcareous; abundant granular pyrite in samples. ( 8290' - 8360' $hale = brownish gray to medium dark gray; moderately soft to slightly firm; rarely grading to hydrophilic claystone; abrasive to silty to earthy texture; very rarely; grading to siltstone; slightly to occas\onaUy very organ\c; commonly grades to carbonaceous shale; abundant d\ssem\nated and granular and laminae of pyrite; decreasing laminations of tuffaceous ash. 8360' - 8415' Shale = brownish gray to medium dark gray; moderately soft to slightly firm; rarely grading to hydrophilic claystone; abrasive to silty to earthy texture; very rarely; grading to siltstone; slightly to occasionally very organic; commonly grades to carbonaceous shale; abundant disseminated and granular and laminae of pyrite; occasional laminations of tuffaceous ash. 8415' - 8470' Tuffaceous Claystone = light tan to medium brown; moderately hydrophilic; soft to crumbly; irregular blocky fracture; massive eroded cuttings; matte to earthy luster; smooth to rare gritty texture; trace carbonaceous material; abundant ashy laminations; grading to and interbedded with shale; non-calcareous; abundant granular pyrite in samples. 8470' - 8565' Shale = brownish gray to medium dark gray; moderately soft to slightly firm; rarely grading to hydrophilic claystone; abrasive to silty to earthy texture; very rarely; grading to siltstone; slightly to occasionally very organic; commonly grades to carbonaceous shale; abundant disseminated, granular and lam\nat\ons of pyrite; common laminat\ons of tuffaceous ash. ( 8565' - 8580' Sandstone = very light gray to some light brownish gray; very fine to fine grains; subangular to some sub- rounded; moderately to some well sorted; slight to some moderate clay matrix grading to tuffaceous claystone; 85-95% quartz and 5-15% dark gray to black and minor green lithics; often with very slight to occasional moderate brown intergranular clayey matter probably organic with [:I EP()C:H 19 ~~~~ ALTAMURA#1 t.,~~1-\';'~':-l~.TI ~ t rare traces of micropyrite and associated with higher gas; estimate some fair porosity; no fluorescence or cut. 8580' - 8665' Sandstone = medium light gray to medium gray; very fine to fine to some slightly scattered medium lower grains; sub-rounded to subangular; well to moderately well sorted; slight calcareous cement and slight quartz overgrowth; moderately well consolidated to friable; slight loose grains in sub- rounded overall; very slight to slight clay matrix; 90-85% quartz and 10-15% glauconite very poor visible to estimate some poor to fair porosity; 20-70% dull to moderate bluish green fluorescence; diffuse yeUow cut. 8665' - 8750' Sandstone = brownish gray to medium gray; very fine to fine and some silty; increasing argillaceous matter; slight to traces of glauconite; very poor visible porosity; rare fluorescence; slow diffuse cut. 8750' - 8760' Sand = clear to translucent to light gray overaU; very fine lower to very fine upper and fine upper; moderately sorted; sub-angular to sub-round; moderate to high sphericity; no visible surface abrasion; trace to common pyrite and slight trace of glauconite nodules; no visible fluorescence. ( 8760' - 8790' Clavstone = brownish gray; soft and hydrophilic; moderately ashy grading to tuffaceous claystone; moderately to slightly organic grading to and interlaminated with carbonaceous shale; common very thin organic partings; smooth to earthy texture; traces pyrite; non-calcareous. 8750' - 8850' Siltstone = light gray to brownish gray; firm to occasionally moderately hard; irregular to sub-planar fracture; predominantly massive to sub-tabular cuttings; earthy to occasionally sub-vitreous luster; gritty, sandy to abrasive texture; trace locally ashy laminations; common pyrite inclusions; rare carbonaceous material. 8850' - 8940' Siltstone = light gray to brownish gray; firm to occasionally moderately hard; irregular to sub-planar fracture; predominantly massive to sub tabular cuttings; earthy to occasional vitreous luster; gritty grading to abrasive texture; occasional ashy laminations; common pyrite laminae; rare carbonaceous material; occasional tuffaceous ash laminae; grades to shale. 8910' - 8940' Shale = brownish gray to medium dark gray; moderately soft to slightly firm; rarely grading to hydrophilic claystone; abrasive to silty to earthy texture; very rarely; grading to siltstone; slightly to occasionally very organic; commonly grades to carbonaceous shale; abundant disseminated, granular and lams of pyrite; common laminae of tuffaceous ash. ( 8940' - 9000' Siltstone = light gray to brownish gray; firm to occasionally moderately hard; irregular to sub planar fracture; predominantly massive to sub tabular cuttings; earthy to occasional vitreous luster; gritty [:1J EP()C:H 20 ( ( ~" ,~~;J ALTAMURA#1 è.¡¡'~!~.'¡¡"'::"IP} ......,:,. ¡.;...; grading to abrasive texture; occasional ashy laminations; common pyrite laminae; rare carbonaceous material; occasional tuffaceous ash laminae; grades to shale. 8940' - 9060' Tuffaceous claystone = light tan to medium brown; moderately hydrophilic; soft to crumbly; irregular blocky fracture; massive eroded cuttings; matte to earthy luster; smooth to rare gritty texture; trace carbonaceous material; abundant ashy laminations; grading to and interbedded with shale; non-calcareous; abundant granular pyrite in samples. 9090' - 9100' Shale = dark to medium dark gray; firm; silty; sub-blocky fracture; tabular cuttings habit; dull to earthy luster; gritty to silty texture; thick bedding with interbedded and graded to siltstone; 10% pyrite. [1 ,EP()(::H 21 ~~~!,~ ALTAMURA#1 CORE #1 8545' Shale = dark gray; moderately hard to hard; brittle; splintery fracture; earthy to frosted luster; smooth texture; fissile; micromicaceous; noncalcareous. 8548 ' Shale = overall as above; less micromicaceous. 8551 ' Shale = overall as above; 1-5% disseminated glauconite grains; micropyritized worm tubes. 8554' Shale = overall as above; trace glauconite grains; rare micropyrite. 8557' Shale = overall as above; increasing trace glauconite grains; increasing micromicaceous. 8560' Sandstone = olive gray to medium gray; lower very fine to upper very fine; well sorted; subangular to subrounded; moderate to high sphericity; hard to moderately hard; moderately calcareous cemented with possible siliceous overgrowths; grain supported with heavy argillaceous matrix; point contact fabric; irregular laminae pale yellowish brown carbonaceous material; 80-90% quartz, 10-20% glauconite, micropyrite fracture filling; no discernible petroleum odor; no visible staining; no sample fluorescence; slow very pale light yellow to medium yellow crush cut; no visible cut. ( 8563' Sandstone = light olive gray to medium gray; very fine with scattered fine lower grains; well sorted; subangular; high to moderate sphericity; moderately well to well consolidated; slightly calcareous cement with slight siliceous overgrowth as effervesces slowly in HCL; grain supported with slight light gray to grayish brown argillaceous matrix; 85% quartz; 15% light to dark green glauconite; trace micropyrite fracture filling; very poor visible intergranular porosity; no odor; no staining; no fluorescence; diffuse light yellow to medium yellow crush cut. 8566' Sandstone = light olive gray to brownish gray; very fine with scattered fine grains; well sorted; subangular; high to moderate sphericity; moderately well to well consolidated; slightly calcareous cement with slight siliceous overgrowth as effervesces slowly in HCL; grain supported with slight to moderate grayish brown to light gray argillaceous matrix; 85% quartz; 15% light to dark green glauconite; very poor visible intergranular porosity; no odor; no staining; no fluorescence; slow diffuse light yellow to medium yellow crush cut. 8569' Sandstone = overall as above; trace micro thin carbonaceous partings. ( 8572.3' Sandstone = olive gray; very fine to fine lower grains; well sorted; subangular; high to moderate sphericity; moderately well to well consolidated; very slightly calcareous with slight siliceous overgrowth; grain supported with slight to moderate light gray to grayish brown argillaceous matrix; irregular laminae with faint to very thin brownish carbonaceous partings; 85% quartz; 15% light to dark green glauconite; very poor visible intergranular porosity; no odor; no staining; no fluorescence; very slow diffuse light yellow to medium yellow crush cut. 8576' [:JEP()C:H 22 p,~~~:~,~~~ ,','1-: ~'i ~V1i.:!,;",,'I~ :¡ù AL TAMURA #1 Sandstone = overall as above, faint carbonaceous partings on irregular laminae. 8579' Sandstone = medium dark gray; very fine to fine grains; subangular to angular; moderate to high sphericity; moderately well sorted; well consolidated; trace calcareous cement with moderate quartz overgrowth; grain supported in slight to moderate brownish gray argillaceous matter including traces silt sized disseminated brown to black carbonaceous matter; thin irregular laminae with shades of light gray to brownish gray; 85-90% quartz, 5-10% glauconite, 5-10% clay and carbonaceous material; some thin burrows filled with soft clayey micropyrite; non to very poor visible intergranular porosity; no odor; no staining; no fluorescence; very slow diffuse light yellow to medium yellow cut and crush cut. 8582' Sandstone = medium dark gray; fine to very fine grains; subangular to angular; moderate to high sphericity; moderately well sorted; well consolidated; very slight calcareous cement with quartz overgrowth and trace brown pebble sized siliceous nodule; grain supported in slight to moderate brownish gray argillaceous matter including traces silt sized disseminated brown to black carbonaceous matter; trace very thin dark brownish gray parting on micro fracture; 85-90% quartz, 5-10% glauconite, 5-10% clay and carbonaceous material; rare thin burrows and clasts filled with soft clayey micropyrite; non to very poor visible intergranular porosity; no odor; no staining; no fluorescence; very slow diffuse light yellow to medium yellow cut and crush cut. ( 8585' Sandstone\siltstone = medium dark gray to olive gray; very fine to fine lower grains and coarse silt; subangular to angular; moderate to high sphericity; moderately well sorted; well consolidated; very slight calcareous cement with slight quartz overgrowth; moderate brownish gray argillaceous matter; 90% quartz, 10% glauconite; trace very finely disseminated micas and pyrite; trace burrows and clasts filled with soft clayey micropyrite; no visible porosity; no odor; no staining; no fluorescence; trace very slow diffuse faint light yellow cut and crush cut. 8588' Sandstone\siltstone = overall as above, moderately well consolidated. 8591 ' Sandstone = olive gray to medium dark gray; very fine to fine lower grains; subangular to angular; moderate to high sphericity; moderately well to well sorted; moderately well consolidated; very slight calcareous cement with slight quartz overgrowth; grain supported and lightly frosted light gray clay matrix with traces and common micro partings and micro laminations of carbonaceous matter; 90% quartz, 10% glauconite; and trace very finely disseminated micas; non to very poor visible intergranular porosity; no odor; no staining; no fluorescence; very slow diffuse light yellow to medium yellow cut and crush cut. 8594' Sandstone = light olive gray to olive gray; very fine to fine lower grains; subangular to angular; high to moderate sphericity; very well to well sorted; well consolidated; very slight calcareous cement with slight quartz overgrowth; grain supported and lightly frosted slightly organic clay matrix; occasional faint grayish clasts with slight micropyrite; 90% quartz, and 10% glauconite; very poor visible intergranular porosity; no odor; no staining; no fluorescence; very slow diffuse light yellow to medium yellow cut and crush cut. ( 8597' Sandstone = light olive gray to medium light gray; very fine to fine grains; subangular; high to moderate sphericity; well sorted; well to moderately well consolidated; slightly calcareous with moderate quartz overgrowth; grain supported and frosted slightly organic clay matrix; faintly mottled ¡:-.;.rI 'F'''''l')( ')( 'YR" It::'ii, ,.;', ,I", 23 ~~~ ALTAMURA#1 ~i:'l~"~I.i.,I.'a 1...- " brownish gray with increased organics from possible burrow traces; trace micropyrite clusters in organic clays; 85% quartz, and 15% glauconite; very poor visible intergranular porosity; no odor; no staining; no fluorescence; slow diffuse light yellow to medium yellow cut and crush cut. 8600' Sandstone = light olive gray; very fine to fine grains; subangular to subrounded; high to moderate sphericity; well sorted; moderately well consolidated; slightly calcareous cement with slight siliceous overgrowths; grain supported and frosted with slightly organic clay matrix; lightly mottled from thin brownish gray micropyritic organic clay partings from possible burrow traces in part; 85% quartz, and 15% glauconite; very poor visible intergranular porosity; no odor; no staining; no fluorescence; slow diffuse light yellow to medium yellow cut and crush cut. 8603' Sandstone = overall as above, lightly mottled to weakly banded with thin brownish gray organic clay partings. 8605' Sandstone = light olive gray to medium gray; upper very fine to lower fine; well sorted; subangular to subrounded; moderate to high sphericity; hard to moderately hard; moderately calcareous cemented with possible siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; irregular laminae pale yellowish brown carbonaceous material; 85-90% quartz, 5- 10% glauconite, 5-10% clay and carbonaceous material, trace micropyrite; no discernible petroleum odor; no visible staining; no sample fluorescence; pale light yellow to dull medium yellow moderate crush cut; no visible cut. ( ( [:I EP()C:H 24 A:~;\ ALTAMURA#1 f CORE #2 8605' Sandstone = light olive gray to medium gray; upper very fine to lower fine; well sorted; subangular to subrounded; moderate to high sphericity; hard to moderately hard; moderately calcareous cemented with possible siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; poor visually estimated porosity; irregular laminae pale yellowish brown carbonaceous material; 85-90% quartz, 5-10% glauconite, 5-10% clay and carbonaceous material, trace micropyrite; no discernible petroleum odor; no visible staining; very dull yellow to gold sample fluorescence; pale light yellow to dull medium yellow moderate crush cut; no visible cut. 8608' Sandstone = overall as above; 10% glauconite. 8611' Sandstone = overall as above; increasing glauconite (10-15%); possible trace dead oil; spotty pale yellow sample fluorescence; pale light yellow to dull medium yellow moderate crush cut; no visible cut. 8614' , Sandstone = overall as above with the following exceptions: firm friable to moderately hard; moderately calcareous cemented with trace of possible siliceous overgrowths; decreasing irregular laminae brownish gray carbonaceous material; spotty yellow white sample fluorescence; pale light yellow to dull medium yellow moderate crush cut; no visible cut. ( 8617' Sandstone = overall as above with the following exceptions: lower fine to upper very fine; moderately hard to firm, friable; moderately to weakly calcareous cemented with rare possible siliceous overgrowths; grain supported with increasing argillaceous matrix; poor estimated porosity; sparse spotty yellow white sample fluorescence. 8620' Sandstone = overall as above; sparse spotty pale yellow sample fluorescence; pale bluish white to light yellow fast crush cut. 8623 ' Sandstone = light olive gray to olive gray to medium gray; lower fine to upper very fine; well sorted to very well sorted; subangular to subrounded; moderate to high sphericity; moderately hard to hard, locally firm friable; moderately to weakly calcareous cemented; grain supported with argillaceous matrix; point contact fabric; poor estimated intergranular porosity; irregular laminae of brownish gray carbonaceous material; 85-90% quartz, 10-15% glauconite, trace light bluish gray siliceous fragments, trace micropyrite; no discernible petroleum odor; no visible staining; no discernible sample fluorescence; very slow dull dark yellow streaming cut, pale light yellow to dull medium yellow moderate crush cut; no visible cut. 8626' Sandstone = overall as above; no sample fluorescence; very slow dull dark yellow streaming cut, pale light yellow to dull medium yellow moderate crush cut; no visible cut. ( 8629' Sandstone = overall as above; abundant spotty pale yellowish sample fluorescence; very slow dull dark yellow streaming cut, pale light yellow to dull medium yellow moderate crush cut; no visible cut. 8632' fJEP()(-:H 25 A....-..~ -~1 TAMURA #1 ~WfII~""" AL °4~t,\;~~~,~ ,"." '" ( Sandstone = as above with the following exceptions: light olive gray to medium light gray; hard to moderately hard; moderately calcareous cemented; 80-90% quartz, 10-20% glauconite; no sample fluorescence; pale light yellow to dull medium yellow moderate crush cut; no visible cut. 8635 ' Sandstone = as above except decreasing glauconite content (5-10%); near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yellow residual ring; no visible cut. 8638 ' Sandstone = light olive gray to olive gray to medium gray; lower fine to upper very fine; well sorted; subrounded to subangular; high spheroidal sphericity; moderately hard to firm friable; moderately calcareous cemented; grain supported with moderate argillaceous matrix; point contact fabric; poor visually estimated intergranular porosity; abundant irregular laminae light brownish gray carbonaceous material; 85-90% quartz, 10-15% glauconite, very slight trace micropyrite; very slight petroleum odor; no visible staining; near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yellow residual ring; no visible cut. 8641 ' Sandstone = overall as above; near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yellow residual ring; no visible cut. 8644' Sandstone = overall as above except the following: upper very fine grained, occasionally lower fine; 5- 10% glauconite; near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yellow residual ring; no visible cut ( 8647' Sandstone = as above; near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yellow residual ring; no visible cut. 8650' Sandstone = olive gray to medium gray; upper very fine to lower fine; well sorted; subangular to subrounded; moderate to high sphericity; hard; moderately calcareous cemented; grain supported with increasing argillaceous matrix; point contact fabric; poor estimated intergranular porosity; spotty brownish gray carbonaceous material (rare laminae); 85-90% quartz, 10-15% glauconite; no discernible petroleum odor; no visible staining; near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yenow residual ring; no visible cut. 8653' Sandstone = olive gray to medium gray; upper very fine to lower fine; well sorted; subangular to subrounded; moderate to high sphericity; hard to moderately hard; moderately calcareous; grain supported with argillaceous matrix; point contact fabric; poor to possibly fair visually estimated porosity; spotty brownish gray carbonaceous material; 80% quartz, 20% glauconite, no discernible petroleum odor; no visible staining; near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yellow residual ring; no visible cut. ( 8656' Sandstone = light olive gray to medium gray; lower fine to upper very fine; well to very well sorted; subangular to subrounded; moderate to high sphericity; hard to moderately hard, locally firm friable; moderately calcareous cemented; grain supported with argillaceous matrix; point contact fabric; poor to fair visually estimated intergranular porosity; decreasing spotty brownish gray carbonaceous material; 75-80% quartz, 20..25% glauconite; no discernible petroleum odor; no visible staining; near solid moderately bright yellow sample fluorescence; milky bluish white slow streaming cut; pale light yellow residual ring; no visible cut. [1 ,EP()C:H 26 ( ( ( "t,.---'~I~ URA #1 ~I~~ ALTAM I;¡'f:,'~~".::.nl,,',~ ... 't 8659' Sandstone = light olive gray to medium gray; upper very fine to lower fine; well sorted; subangular to subrounded; moderate to high sphericity; hard to moderately hard; moderately to slightly calcareous cemented with siliceous overgrowth and fracture fill; grain supported with moderate argillaceous matrix; point contact fabric; poor visually estimated porosity; increasing carbonaceous material content, spotty, rarely irregular laminae; 85-90% quartz, 5-10% glauconite, trace micropyrite; possible bioturbation; no discernible petroleum odor; no visible staining; no sample fluorescence; very weak light yellow to dull medium yellow crush cut; no visible cut. 8662' Sandstone = mottled light olive gray to medium gray; lower fine to upper very fine; well to fair sorted; subangular to subrounded; moderate to high sphericity; hard; moderately calcareous cemented with siliceous overgrowths; grain supported with slight argillaceous matrix; point contact fabric; poor to fair estimated intergranular porosity; very irregular laminae brownish gray carbonaceous material; 85-90% quartz, 10-15% glauconite; no discernible petroleum odor; no visible staining; no sample fluorescence; very weak light yellow to dull medium yellow crush cut; no visible cut. 8665 ' Sandstone = light olive gray to brownish gray; predominantly lower fine, occasionally ranges to upper very fine; well to very well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to moderately hard; moderately calcareous cemented, possible trace siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; abundant brownish gray , carbonaceous material, including possibly dead oil; 70-80% quartz, 10-20% chert, 5-10% other siliceous lithic fragments, less than 5% glauconite, trace micropyrite; possible very slight petroleum odor; very dull bluish green sample fluorescence; pale light yellow to dull medium yellow moderate to fast crush cut; medium yellow residual ring; no visible cut. !!r-l1 L'I)(")("YH' It:tI .L..J.,. j, . 27 " '~~~;¡ì ALTAMURA#1 t>t'..:v¡'~.~r:I..,'~':Y ( CORE #3 8665' Sandstone = light olive gray to brownish gray, mottled to grayish hues; predominantly lower fine, occasionally ranges to upper very fine; well to very well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to moderately hard; moderately calcareous cemented, possible trace siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; poor estimated porosity; abundant brownish gray carbonaceous material, including possibly dead oil; 80-90% quartz, 5-10% chert, 5-10% other siliceous lithic fragments, less than 5% glauconite, trace micropyrite; possible very slight petroleum odor; very dull bluish green sample fluorescence; slow streaming pale light yellow to dull medium yellow cut; medium yellow residual ring; no visible cut. 8668' Sandstone = mottled light olive gray to medium gray to brownish gray; upper very fine to lower fine; well sorted; subangular to subrounded; moderate to high spheroidal sphericity; hard; moderately calcareous cemented with siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; poor estimated intergranular porosity; very irregular laminae brownish gray carbonaceous material; 95% quartz, less than 5% glauconite; no discernible petroleum odor; no visible staining; no sample fluorescence; very slow streaming light yellow to dull medium yellow cut; no visible cut. 8671 ' Sandstone = as above, slight increase in glauconite; no discernible sample fluorescence; very slow leaching cut. ( 8674' Sandstone = brownish gray to olive gray; predominantly lower very fine grading to silt, occasionally ranges to upper very fine; well sorted; subangular to subrounded; moderate spheroidal sphericity; hard to moderately hard; moderately calcareous cemented, possible trace siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; poor visually estimated porosity; abundant brownish gray carbonaceous material; 100% quartz, trace glauconite, trace micropyrite; no discernible petroleum odor; no sample fluorescence; very slow streaming pale yellow to dull medium yellow cut; no visible cut. 8677' Sandstone = overall as above except increased micropyritized replacement (possibly worm tubes); trace spotty dull yellow sample fluorescence; very slow streaming pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. 8680' Sandstone = as above; no discernible sample fluorescence; slow leaching pale yellow cut; milky yellow residual ring; no visible cut. 8683 ' Sandstone = overall as above; trace spotty bluish white sample fluorescence; very slow streaming pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. ( 8686' Sandstone = brownish gray to olive gray; upper very fine to lower very fine grading to silt; well to very well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard with localized thin layers of firm friable; moderately calcareous cemented, possible trace siliceous overgrowths; grain supported with increasing argillaceous matrix; point contact fabric; poor visually estimated [=I F~P()(:H: 28 At~~i~: LTAMURA#1 '~~¡:j'\~!':-\'I~\ Cj,,"'I'I~J 1;,.." A ( " intergranular porosity; abundant brownish gray carbonaceous material; 95-100% quartz, trace to 5% glauconite, trace micropyrite; no discernible petroleum odor; no discernible sample fluorescence; very slow streaming pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. 8689' Sandstone = overall as above; no discernible sample fluorescence; slow streaming pale yellow to dull medium yellow cut; medium yellow residual ring; no visible cut. . 8692' Sandstone = overall as above; no discernible sample fluorescence; slow leaching pale yellow white cut; milky yellow residual ring; no visible cut. 8695' Sandstone = as above except more siliceous cementation/intergranular overgrowth; abundant spotty very weak yellow sample fluorescence; slow streaming moderate light yellow to medium yellow cut; no visible cut. 8698' Sandstone = olive gray to brownish gray, mottled with light olive gray to medium gray; lower very fine to upper very fine, moderate silt content; well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to moderately hard; moderately calcareous cemented, possible trace siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; poor estimated porosity; moderately abundant irregularly laminated brownish gray carbonaceous material; 95% quartz, 5% glauconite, trace micropyrite; abundant spotty very weak yellow sample fluorescence; slow streaming moderate light yellow to medium yellow cut; medium yellow residual ring; no visible cut. ( 8701' Sandstone = light olive gray to olive gray to brownish gray; predominantly upper very fine to lower very fine, grading to silt; well sorted; subangular to subrounded; high spheroidal sphericity, occasional low discoidal (possibly due to siliceous overgrowth on otherwise spheroidal grains); hard to moderately hard; moderately calcareous cemented, moderate siliceous overgrowths; grain supported with argillaceous matrix; point contact fabric; poor to very poor estimated porosity; abundant bioturbated brownish gray carbonaceous material; 95-100% quartz, less than 5% glauconite, increased trace micropyrite replacement; no discernible sample fluorescence; moderate leaching pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. 8704' Sandstone = light olive gray to brownish gray, mottled with various brownish and grayish hues; predominantly lower very fine to silt, occasionally upper very fine; well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to moderately hard; moderately calcareous cemented with siliceous overgrowths; grain supported with increased argillaceous matrix; point contact fabric; poor to very poor intergranular porosity; abundant brownish gray carbonaceous material; 100% quartz, trace glauconite, trace micropyrite; no discernible sample fluorescence; moderate leaching pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. 8707' Sandstone = as above. ( 8710' Sandstone = olive gray to brownish gray to medium dark. gray; lower very fine to silt, occasionally upper very fine; well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to very hard; moderately calcareous cemented with moderate siliceous overgrowth; grain supported with slight argillaceous matrix; point contact fabric; very poor to poor visually estimated porosity; [=I :EP()(:H 29 '~. ,~ t 1I;,;tJ~~',;,":',~'~'¡' (:.~Ni..'' ,(. ~ I AL TAMURA #1 \ very abundant brownish gray to olive black carbonaceous material; 90-95% quartz, 5-10% glauconite, abundant micro pyrite replacement; no sample fluorescence; moderate leaching pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. 8713' Sandstone = overall as above; very slight trace very weak yellow sample fluorescence; moderate leaching pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. 8716' Sandstone = olive gray to brownish gray to medium dark gray; lower very fine to silt, occasionally upper very fine; well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to very hard; moderately calcareous cemented with moderate siliceous overgrowth; grain supported with slight argillaceous matrix; point contact fabric; very poor to poor visually estimated porosity; very abundant brownish gray to olive black carbonaceous material; 90-95% quartz, 5-10% glauconite, abundant micropyrite replacement; no sample fluorescence; moderate leaching pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. 8719' Sandstone = olive gray to brownish gray; lower very fine to silt, occasionally upper very fine; well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to very hard; moderately calcareous cemented with moderate siliceous overgrowth; grain supported with slight argillaceous matrix; point contact fabric; very poor to poor visually estimated porosity; moderately abundant brownish gray to olive black carbonaceous material; 90-95% quartz, 5-10% glauconite, abundant micropyritized worm tube and plant debris replacement; no sample fluorescence; moderate leaching pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. ( 8725.25' Sandstone = light olive gray to brownish gray; lower very fine to silt, occasionally upper very fine; well sorted; subangular to subrounded; high to moderate spheroidal sphericity; hard to very hard, localiz,ed lenses of firm friable; moderately calcareous cemented with decreasing siliceous cementation/overgrowth; grain supported with moderate argillaceous matrix; point contact fabric; very poor to poor visually estimated porosity; moderately abundant brownish gray to olive black carbonaceous material; 95% quartz, less than 5% glauconite, moderately abundant micropyritized plant debris replacement; intercalated sandstone and siltstone laminae; trace dull bluish white sample fluorescence; moderate leaching pale yellow to dull medium yellow cut; milky yellow residual ring; no visible cut. ( ,..,;.g L'])()('"1'H It:1I .1':';. , , j" 30 Show No.: 1 Depth Interval: 6094 To 6125 6008 To 6039 Á4%... ., ~~~, RA #1 '~~~¡~'Yr'"'¡''' AL T AMU SHOW REPORTS (MD) (TVD) Total Footage: 31 Bit Hours: 42,8 Bit Information Bit Type: STC S88HPX After Maximum Averages: Before ROP (fph) WOB RPM Mud Wt. 86.8 7.1 74 10.2 Total Gas C1 (ppm) C2 (ppm) C3 (ppm) C4 (ppm) C5 (ppm) 148 23489 1468 692 305 112 ( Cuttings Fluorescence%: 25 Intensity: Poor Mud Fluorescence: none During 88.6 7.2 79 10.2 97.3 7.8 83 10.2 99.8 8.0 81 10.2 436 74947 4951 2214 817 300 180 30093 2122 1145 486 274 660 111721 7391 3144 1100 376 Color: Dull pale yellow Cut: Very slow, very weak, greenish yellow Formation Description: Sandstone = light to medium gray with a salt and pepper appearance; very fine to medium grains; very angular to subangular; moderately to low sphericity; very poor to moderately sorting; 60% quartz 40% lithics, assort minerals and abundant carbonaceous material; poor to moderately consolidated with matrix; matrix hydrophilic and rapidly hydrates; predominantly grain supported with predominantly long grain contacts; occasional well cemented with siliceous cement; porosity predominantly infilled with matrix; very rare open porosity; estimate very poor intergranular porosity; dull pale yellow fluorescence with a very slow, weak, light greenish yellow fluorescence; observed very minor oil on shaker; faint petroliferous odor. Logging Geologist: Andrew Buchanan ( [:I EP()C=H 31 ( j~i! AL TAMURA #1 ' .',¡.t::'¡.";'¡'i;'\#!H CQ:. Show No.: 2 Depth Interval: 6255' To 6293' 6255' To 6207' (MD) (TVD) Total Footage: 38' Bit Information Bit Type: STC S88HPX Bit Hours: 44.0 Averages: Before During After Maximum ROP (fph) WOB RPM Mud Wt. 90.4 7.0 94.5 10.2 89.3 5.4 76.2 10.2 79.5 4.6 78.7 10.2 139 7.0 78 10.2 Total Gas C1 (ppm) C2 (ppm) C3 (ppm) C4(ppm) C5 (ppm) 156 24941 1714 553 297 132 618 104130 8851 2471 664 247 269 46836 3618 1092 350 130 1523 260464 23051 6328 1558 607 Cuttings Fluorescence%: 50 Intensity: Moderate Mud Fluorescence: None Color: Pale yellow Cut: Very slow, very weak, yellowish green Formation Description: Sandstone/Sand = light to medium gray; salt and pepper; very fine to fine grained; moderate sorting; sub angular overall; moderate sphericity; composed of 50%-60% quartz; 40%-50% lithics, assorted minerals, mica, carbonaceous material; 60%-70% consolidated; whitish clay/ash matrix infilling porosity; 70% grain supported; abundant unconsolidated grains assoc with clay matrix visibly breaking down; abundant disseminated pyrite; porosity; entirely infilled with matrix; estimated very poor intergranular porosity; 40% shows pale yellow fluorescence; very slow, very weak, yellowish green fluorescent cut; minor free oil observed while washing; trace petrolifero us odor. Logging Geologist: Andrew Buchanan ( [=I :EP()C::H 32 .~ ~~~ ALTAMURA#1 ~ Show No.: 3 \. Depth Interval: 6895' To 6911' (MD) Total Footage: 16 6810' To 6826' (TVD) Bit Information Bit Type: STC S88HPX Bit Hours: 52.0 Averages: Before During After Maximum ROP (fph) 101.7 109.6 89.6 147 WOB 8.1 8.9 10.1 10 RPM 90.4 89.2 96.9 93 Mud Wt. Total Gas 372 620 318 772 C1 (ppm) 62710 105125 49756 131879 C2 (ppm) 4589 7767 4090 9741 C3 (ppm) 1065.5 1728 1022 2130 C4 (ppm) 347 480 338 554 C5(ppm) 136 162 158 179 ( Cuttings Fluorescence%: Trace Color: Very dull yellow green Intensity: Very weak Cut: none Mud Fluorescence: None Formation Description: Sandstone = medium light gray to some medium gray; very fine subangular to angular grains grading to siltstone; locally slight loose angular fine to medium lower grains; poorly sorted to some moderately well sorted in mostly clay; trace calcareous cement; friable to moderately consolidated; mostly grain supported; lightly speckled to slight flakes and very thin partings of carbonaceous matter and traces of micropyrite; grains mostly quartz to some brown tuff in coarser sand; estimate very poor to some fair porosity; very dull yellow green fluorescence and no cut. Logging Geologist: Brian Q'Fallon ( [=I f~P()(~H 33 A,,_,-~.:i AMURA #1 ~='(:'","),"!<JO AL T Show No.:4 Depth Interval: 7130' To 7226' (MD) Total Footage: 96' 7044' To 7136' (TVD) Bit Information Bit Type: STC S88HPX Bit Hours: 55.5 Averages: Before During After Maximum ROP (fph) 72 99.9 88.7 187 WOB 9.0 7.3 3.8 12 RPM 99.2 90.9 89.0 105 Mud Wt. Total Gas 176 467.7 458 1176 C1 (ppm) 27922 79087 84976 202482 C2(ppm) 2692 6807 6594 17294 C3(ppm) 807 1840 1861 4845 C4(ppm) 275 558 644 1594 C5 (ppm) 186 165 305 433 ( Cuttings Fluorescence%: 20-50 Color: Dull yellow green Intensity: Very weak Cut: Very slow, very weak, milky greenish white Mud Fluorescence: None Formation Description: Sandstone = light to medium gray with salt and pepper appearance; very fine to fine grading to lower medium; moderately sorting; very angular to subangular; low to moderately sphericity; 50% quartz, 50% lithics with abundant mafics, common carbonaceous material; predominantly consolidated at beginning of interval and becoming increasingly unconsolidated with depth to predominantly unconsolidated by 7220'; predominantly easily friable with matrix cement and occasional moderately hard with trace calcareous and siliceous cement; interstices entirely infilling with clay/ashy matrix; estimated very poor approaching nil porosity in part shows very wk dull yellow-green fluorescence with very slow, very wk, milky greenish white cut; trace oil on shakers. Logging Geologist: Andrew Buchanan ( " [=lE:P()(~H 34 """",,,,,~,~,,,,,,;~~: AL TAMURA #1 \ Show No.:5 Depth Interval: 7260' To 7366' (MD) Total Footage: 106 7174' To 7280' (TVD) Bit Information Bit Type: STC S88HPX Bit Hours: 57.1 Averages: Before During After Maximum ROP (fph) 55.5 88.4 100.4 131.5 WOB 5.2 4.6 5.8 6.0 RPM 72.1 83.8 93.5 98 Mud Wt. Total Gas 274 664 285 1052 C1 (ppm) 44679 126473 53747 200912 C2 (ppm) 3827 9606 4434 14995 C3(ppm) 1216 2608 1355 4044 C4(ppm) 498 822 593 1242 C5 (ppm) 139 381 367 695 Cuttings Fluorescence%: 30% - 60% Color: Faint greenish Intensity: Very poor Cut: Nil Mud Fluorescence: None Formation Description: Sandstone = light to medium gray with salt and pepper appearance; very fine to fine grading to lower medium to the end of the interval; well to moderately sorting; very angular to subangular; low to moderately sphericity; 50% - 70% quartz, 30% - 50% lithics with abundant mafics, common disseminated and laminar carbonaceous material; predominantly consolidated with increase unconsolidated with depth; increasingly matrix supported with depth 7300'- 7 400'~ predominantly easily friable with matrix cement and occasional moderately hard with trace calcareous and siliceous cement; interstices entirely infilling with clay/ashy matrix; matrix moderately hydrophilic in part; estimated very poor approaching nil porosity in part shows very weak greenish fluorescence; with no discernable cut. Logging Geologist: Andrew Buchanan ( '- [:I I~P()(::H 35 ~!;i TAMURA #1 ~""";V~'" " AL Gt~t;,,*.1''1~~...,. '" Show No.: 6 Depth Interval: 8565 To 8670 8460 To 8584 (MD) (TVD) Total Footage: 105 Bit Information Bit Type: CORE BIT #2 Bit Hours: 2 Averages: Before During After Maximum ROP (fph) WOB RPM Mud Wt. 6.1 14.2 63 9.6 47.6 7.1 61.4 9.6 10.2 5.1 60 9.7 193.9 12 71 9.5 Total Gas C1 (ppm) C2(ppm) C3 (ppm) C4 (ppm) C5(ppm) 10 1125 133 66 5 0 784 112564 18707 9657 3896 1405 180 17682 3046 1536 686 455 1732 231184 43243 23652 10947 4285 ( Cuttings Fluorescence%: 20-70% Intensity: dull to moderate Mud Fluorescence: trace dull yellow Color:, bluish green Cut: diffused yellow cut Formation Description: Sandstone = medium light gray to medium gray; very fine to fine to some slightly scattered medium lower grains; sub-rounded to subangular; well to moderately well sorted; slight calcareous cement and slight quartz overgrowth; moderately well consolidated to friable; slight loose grains in sub-rounded overall; very slight to slight clay matrix; 90-85% quartz and 10-15% glauconite very poor visible to estimate some poor to fair porosity; 20-70% dull to moderate bluish green fluorescence; diffuse yellow cut. Logging Geologist: Brian Q'Fallon ( [:I EP()(:H: 36 k'_.-i~~ ~==~. ALTAMURA#1 ( DAILY ACTIVITY SUMMARY 03/10/02 107' -151' Epoch commenced logging at 22:15 hours when rig spudded well at 107',16" conductor pipe shoe; drilled ahead with new bit #1 and HWDP from 107' to 151'. 03/11/02 151' - 589' Drilled ahead from 151' to 258', and circulated hole clean; worked on top drive; picked up BHA with MWD tools including nuclear source, and ran in hole with same bit #1 to 258'; pulled out of hole to 138' and ran in hole logging (MADD Pass) from 138' to 258'; drilled ahead from 258' to 327'; worked on top drive; drilled ahead from 327' to 384'; worked on top drive; drilled ahead from 384' to 589'. 03/12/02 589' - 1924' Drilled ahead from 589' to 697'; worked on top drive; drilled ahead from 697' to 1623'; worked on pumps; drilled ahead from 1623' to 1924'. 03/13/02 1924' - 2762' Drilled ahead from 1924' to 2762', casing depth, and circulated out; filled trip tank and circulated hole clean; tripped out of the hole, backreaming from 2208' to shoe. ( 03/14102 2762' Continue to back ream out of the hole; download Sperry-Sun tools before laying down and racking back Bottom Hole Assembly; make up BHA and run into the hole washing and reaming as necessary; circulate bottoms up and pump high viscosity sweep; circulate hole clean and trip out of the hole. 03/15/02 2762' Finish pulling out of the hole before racking back and laying down the bottom hole assembly. Rig to and run 9 5/8" casing. Casing landed at 2748'. Riged to and ran cement. Cement in place at 1900 hrs. Waited on cement and rigged down cementers. Clear the rig floor and nipple down the diverter. 03/16/02 2762' Finish nippling down the diverter and nipple up BaPE. 03/17/02 2762' Continue to Nipple up the BaPE; check for leaks and begin to test. 03/18102 2762' Continue testing BaPE then begin picking up pipe. 03/19/02 2762' - 2930' Finish picking up pipe, make up bottom hole assembly and run into the hole and tag cement; drill out cement and 25' of new hole; circulate hole clean and perform formation integrity test; resume drilling ahead to a midnight depth of 2930'. 03/20102 2930' - 4188' Continue drilling ahead with surveys to 4188'. Circulated bottoms up and pumped a weighted, high viscosity sweep around to clean the hole before pulling out of the hole for a wiper trip. ( 03/21/02 4188' - 5040' [=I EP()C:H 37 ,~~~ ALTAMURA#1 ( Continue to wiper trip to shoe pumping out as necessary. Run into the hole washing down the last stand before resuming drilling to a midnight depth of 5040'. 03/22/02 5147' - 6152' Drill ahead from 5040' to 5147'; wiper trip maximum 690 units of gas; drill ahead from 5147' to 6152'. 03/23/02 6152' - 7271' Drill ahead with sUl'\leys as necessary to a midnight depth of 7271 ' 03/24/02 7271' - 8358' Drill ahead with sUl'\leys as necessary to a midnight depth of 8358'. 03/25/02 8358' - 8510' Drill ahead to 8510', casing point. Circulate bottoms up and inspect sample; circulate high weight, high viscosity sweep; pump dry job and begin pulling out of the hole for a wiper trip. Hole pulled tight and had to back ream 5 stands. Ran into bottom and circulated a sweep and pumped out 15 stands; continue wiper trip to shoe. Run into hole and wash down last stand. Circulate bottoms up and pump high weight, high viscosity sweep and circulate hole clean. 03/26/02 8510' Continue to circulate and condition mud for casing. Pull out of the hole and stand back and lay down the bottom hole assembly. Rig to and begin running 7" casing. 03/27/02 8510' Run in total 206 joints 7" casing to 8500'; circulated and conditioned hole, maximum 240 units of gas; pump cement and displace, maximum 415 units of gas. Rig up to test BOPs ( 03/28/02 8510' Test BOP's; pick up 33 joints of drill pipe and lay back 11 stands in derrick; make up new BHA; run in hole to top of cement and displace mud, maximum 55 units of gas. 03/29/02 8510'- 8545' Drill cement and shoe and continue to displace mud for coring; drill from 8510' to 8530' and conduct PIT test to 13.5 EMW; drill ahead from 8530' to 8545'. coring point; circulate out and clean hole; trip out of hole. 03/30/02 8545' - 8605' Finish trip out of hole; make up assembly for core #1; run in hole; core from 8545' to 8605' and trip out of hole with core #1 . 03/31/02 8605' - 8665' Finish pull out of hole with core #1; lay down and make up for core run #2; run in hole and core from 8605' to 8665'; pull out of hole with core #2. 04/01/02 8665' - 8725' Finish pull out of hole with core #2; lay down and make up for core run #3; run in hole and core from 8665' to 8725'; pull out of hole with core #3 and lay down; make up BHA #8 and run in hole. 04/02/02 8725' - 9100' Finish run in hole with BHA #8; drill from 8725' to TD at 9100'; pull out of hole to test. ( [=I EP()C:H 38 .-,d~~ I, " ~ P~~,,,,,,",,<~,,,,,<,,,,,, AL TAMURA #1 ( GAS SAMPLES SAMPLE NUM8ER DEPTH UNITS SAMPLE NUM8ER DEPTH UNITS 8-1126 604' 17 8-1176 8640' 1510 8-1127 1095' 76 8-1177 8645' 1650 8-1128 1595' 150 8-1178 8650' 1620 8-1129 2120' 50 8-1179 8655' 1700 8-1130 2604' 72 8-1180 8660' 1600 8-1131 3103' 32 8-1181 8665' 358 8-1132 3556' 400 8-1182 8670' 454 8-1133 4138' 134 8-1183 8675' 295 8-1134 4640' 63 8-1184 8680' 278 8-1135 5106' 160 8-1185 8685' 224 8-1136 5467' 320 8-1186 8690' 309 8-1137 5931' 183 8-1187 8695' 220 8-1138 5967' 310 8-1188 8700' 172 8-1139 6109' 660 8-1189 8705' 250 8-1140 6273' 1500 8-1190 8710' 310 8-1141 6427' 359 8-1191 8715' 241 8-1142 6461' 820 8-1192 8720' 194 8-1143 6908' 750 8-1193 8725' 160 8-1144 7150' 920 8-1194 8810' 210 8-1145 7197' 1070 8-1195 8930' 300 8-1146 7220' 810 8-1196 8980' 293 8-1147 7337' 847 8-1197 9100' 930 8-1148 7607' 435 8-1198 ( 8-1149 7700' 135 8-1199 8-11 50 7815' 125 8-1200 8-1151 7900' 126 8-1201 8-1152 1990' 153 8-1202 8-1153 8095' 254 8-1203 8-1154 8157' 260 8-1204 8-11 55 8350' 107 8-1205 8-1156 8440' 48 8-1206 8-1157 8540' 85 8-1207 8-1158 8550' 15 8-1208 8-11 59 8555' 10 8-1209 8-1160 8560' 9 8-1210 8-1161 8565' 92 8-1211 8-1162 8570' 145 8-1212 8-1163 8575' 33 8-1213 8-1164 8580' 33 8-1214 8-1165 8585' 31 8-1215 8-1166 8590' 38 8-1216 8-1167 8595' 138 8-1217 8-1168 8600' 295 8-1218 8-1169 8604' 398 8-1219 8-1170 8610' 720 8-1220 8-1171 8615' 1450 8-1221 8-1172 8620' 1250 8-1222 8-1173 8625' 940 8-1223 ( 8-1174 8630' 1000 8-1224 8-1175 8635' 1390 8-1225 [:I EJ")()C:H 39 ~¡.~ ".,"",.,""C",""¡:ó'.¡'" AL TAMURA #1 ,-1' SURVEY RECORD I¡, Measured Inclination Azimuth Vertical Lat Departure Section Dog Leg Depth Depth (feet) (degrees) (Degrees) (Feet) (feet) (Feet) (Feet) ~/1 00') 157.61 0.17 139.76 157.61 -0.18 0.15 0.22 0.11 253.48 0.38 151.31 253.48 -0.57 0.4 0.67 0.22 345.85 0.39 149.69 345.85 -1.11 0.71 1.28 0.02 438.83 0.3 167.45 438.82 -1.62 0.92 1.83 0.15 529.9 0.27 185 529.89 -2.07 0.95 2.27 0.1 622.79 0.25 197.25 622.78 -2.48 0.87 2.63 0.06 715.56 0.11 187.32 715.55 -2.76 0.8 2.87 0.15 807.82 0.17 185.89 807.81 -2.98 0.78 3.07 0.06 901.26 0.18 177.87 901.25 -3.27 0.77 3.34 0.03 997.45 0.19 186.69 997.44 -3.58 0.76 3.63 0.03 1091 .48 0.28 179.61 1091.47 -3.96 0.74 3.98 0.1 1184.96 0.27 189.37 1184.95 -4.4 0.71 4.39 0.05 1280.07 0.4 196.74 1280.06 -4.94 0.57 4.86 0.15 1374.75 0.4 196.4 1374.74 -5.58 0.38 5.4 0 1470.69 0.42 204.21 1470.67 -6.22 0.15 5.93 0.06 1565.18 0.4 196.38 1565.16 -6.85 -0.09 6.45 0.06 1660.29 0.44 196.38 1660.27 -7.52 -0.29 7.02 0.04 1755.27 0.62 206.09 1755.24 -8.33 -0.62 7.69 0.21 1851.77 0.6 190.93 1851.74 -9.29 -0.94 8.49 0.17 1944.79 0.82 187.15 1944.75 -10.43 -1.11 9.51 0.25 ( 2039.55 0.86 173.96 2039.5 -11 .82 -1.13 10.82 0.21 2134.89 0.48 66.09 2134.84 -12.36 -0.68 11.48 1.16 2229.72 0.31 47.82 2229.66 -12.03 -0.12 11.34 0.22 2324.10 0.22 82.24 2324.04 -11.83 0.25 11.27 0.19 2419.42 0.19 76.15 2419.36 -11 .77 0.58 11.32 0.03 2513.45 0.39 52.08 2513.39 -11.53 0.99 11.23 0.24 2607.70 0.57 52.36 2607.64 -11.05 1.62 10.97 0.19 2691.98 0.6 45.84 2691.91 -1 0.48 2.27 10.65 0.09 2794.35 0.6 56.76 2794.28 -9.81 3.1 10.29 0.11 2887.38 0.55 72.87 2887.3 -9.41 3.94 10.18 0.18 2982.93 0.64 113.19 2982.85 -9.49 4.86 10.55 0.44 3076.04 3.91 169.88 3075.88 -12.82 5.9 14.04 3.86 3173.13 8.18 162.59 3172.41 -22.67 8.55 24.21 4.46 3268.44 11.46 164.08 3266.31 -38.25 13.18 40.45 3.45 3362.87 14.62 168.39 3358.29 -58.95 18.15 61.65 3.5 3457.57 18.83 167.45 3448.97 -85.59 23.88 88.71 4.45 3552.73 22.36 166.84 3538.03 -118.21 31.33 121.99 3.72 3647.67 23.85 159.84 3625.37 -153.83 42.06 159.16 3.29 3742.34 23.25 158.04 3712.15 -189.13 55.64 196.96 0.99 3832.98 22.75 158.07 3795.59 -221.98 68.88 232.32 0.55 3928.63 22.3 158.08 3883.94 -255.97 82.56 268.91 0.47 4025.06 21.87 158.17 3973.3 -289.61 96.06 305.12 0.44 4120.68 21.26 155.82 4062.23 -321.96 109.79 340.17 1.11 4216.42 20.54 156.44 4151.7 -353.47 122.74 374.17 0.77 4309.70 19.81 155.71 4239.25 -382.88 135.78 406.22 0.82 ( 4404.98 18.03 162.22 4329.39 -411.65 146.93 437.05 2.9 ['1 EP()(::H 40 ~:. LTAMURA#1 I I' ¡':'t:~r(iI".~J,'1'1 Cr.~.."'Qt".~(n A .,~. ( Measured Inclination Azimuth Vertical Lat Departure Section Dog Leg Depth Depth (feet) (degrees) (Degrees) (Feet) (feet) (Feet) (Feet) t>/100') 4499.23 14.93 161.52 4419.76 -437.06 155.23 463.78 3.3 4594.09 11.97 160.23 4512.01 -457.91 162.44 485.84 3.13 4688.48 9.15 158.01 4604.79 -474.09 168.56 503.12 3.02 4783.72 5.73 156.24 4699.21 -485.46 173.31 515.42 3.6 4878.15 2.65 171 .85 4793.38 -491.93 175.52 522.26 3.44 4972.72 1.47 201.91 4887.89 -495.23 175.37 525.33 1.65 5067.95 1.63 201.09 4983.09 -497.63 174.43 527.3 0.16 5163.08 1.8 203.57 5078.17 -500.26 173.35 529.44 0.19 5255.83 1.87 205.88 5170.84 -502.67 172.98 531.6 0.11 5352.17 1.87 208.14 5267.13 -505.47 171.55 533.79 0.08 5446.37 1.89 206.02 5361 .28 -508.22 170.14 535.94 0.08 5538.93 1.86 207.97 5453.79 -510.92 168.77 538.05 0.07 5635.79 2.03 205.14 5550.6 -513.87 167.30 540.36 0.2 5730.11 2.16 207.92 5644.85 -516.95 165.76 542.78 0.17 5825.78 0.51 219.31 5740.49 -518.87 164.65 544.23 1.74 5920.04 0.21 282.46 5834.75 -519.15 164.22 544.36 0.48 6014.78 0.25 293.8 5929.49 -519.03 163.85 544.13 0.07 6109.27 0.47 295.36 6023.98 -518.78 163.32 543.72 0.23 6204.54 0.16 265.85 6119.25 -518.63 162.83 ' 543.41 0.35 6297.32 0.19 224.90 6212.03 -518.75 162.59 543.45 0.14 6392.52 0.23 247.51 6307.23 -518.94 162.30 543.53 0.1 6487.73 0.45 239.92 6402.44 -519.20 161.79 543.62 0.23 I 6583.52 0.44 205.32 6498.22 -519.72 161.31 543.96 0.28 \ 6678.39 0.88 190.35 6593.09 -520.77 161.02 544.85 0.49 6773.54 1.40 182.77 6688.22 -522.65 160.83 546.57 0.57 6867.91 1.60 166.26 6782.56 -525.08 161.09 548.95 0.5 6963.59 1.27 146.78 6878.21 -527.26 161 .99 551.31 0.61 7057.99 1.03 134.25 6972.59 -528.73 163.17 553.08 0.37 7152.13 1.36 115.29 7066.71 -529.80 164.79 554.62 0.54 7246.62 1.47 105.78 7161.17 -530.61 166.97 556.09 0.27 7341.78 1.36 108.59 7256.30 -531.30 169.21 557.47 0.14 7436.57 1.01 110.83 7351.07 -531.96 171 .06 558.69 0.37 7530.36 1.01 89.68 7444.84 -532.25 172.66 559.48 0.39 7625.93 0..66 76.22 7540.40 -532.11 174.03 559.79 0.42 7720.54 0.62 72.88 7635.01 -531 .83 175.05 559.86 0.06 7815.69 0.45 52.93 7730.15 -531 .45 175.84 559.76 0.26 7909.93 0.45 38.83 7824.39 -530.94 176.37 559.44 0.12 8004.45 0.39 41.78 7918.91 -530.41 176.81 559.09 0.07 8099.92 0.57 32.02 8014.38 -529.77 177.28 558.63 0.2 8194.55 0.46 33.62 8109.00 -529.06 177.74 558.11. 0.11 8289.24 0.45 7.62 8203.69 -528.37 178.00 557.54 0.22 8383.80 0.49 13.36 8298.25 -527.61 178.14 556.86 0.06 8438.86 0.53 27.22 8353.30 -527.15 178.31 556.49 0.24 8530.66 0.64 84.72 8445.10 -526.73 179.02 556.31 0.62 8624.92 0.81 92.95 8539.35 -526.71 180.21 556.69 0.21 8719.63 0.83 86.84 8634.05 -526.71 181.56 557.12 0.09 8813.90 0.64 89.45 8728.32 -526.67 182.77 557.47 0.21 8910.38 0.70 79.69 8824.79 -526.55 183.89 557.73 0.14 ( 8983.74 0.61 69.02 8898.14 -526.33 184.70 557.78 0.21 9100.00 0.61 69.02 9014.40 -525.89 185.86 557.74 0.00 [:I EP()C:H 41 i,~n"l'~h_S ~ "v::\"""~t.\",;,-",,"<.,, AL TAMURA #1 ( MUD REPORT DATE DEPTH DEN VIS PV YP GELS FIL SOL SAND OIW MBT PH Pm CL- Ca 03/11/02 470 10.0 64 14 27 11/12/0 5.0 8.3 0.5 0/89.0 0.0 9.7 0.30 35000 160 03/12/02 1830 10.0 41 10 22 4/6/8 5.0 5.8 0.25 0.0/91.2 3.0 9.7 0.30 38000 160 03/13/02 2660 10.05 43 11 21 5/8/9 5.6 5.0 0.25 0.0/91.5 3.0 9.3 0.50 44000 160 03/14/02 2762 10.15 58 13 29 6/11/15 5.6 6.6 0.25 0.0/91.5 5.0 9.0 0.30 24000 120 03/15/02 2762 10.40 42 17 24 6/11/0 5.6 7.7 0.25 0.0/90.0 3.0 9.0 0.20 29000 400 03/16/02 2762 9.55 41 9 9 3/5/0 7.0 4.1 0.0 0.0/93.0 2.0 8.0 0.00 36000 200 03/17/02 2762 9.55 41 9 9 3/5/0 7.0 4.1 0.0 0.0/93.0 5.0 8.0 0.00 36000 400 03/18/02 2762 9.50 36 8 6 2/4/5 7.6 4.6 0.0 0.0/93.0 5.0 7.8 0.00 30000 320 03/19/02 2800 9.50 38 7 8 3/5/0 8.0 3.9 0.25 0.0/93.0 4.5 10.0 0.60 38000 680 03/20/02 3450 9.50 38 7 12 2/4fl 6.8 4.3 0.25 0.0/93.0 6.0 9.2 0.30 33000 320 03/21/02 5001 9.8 38 11 12 5/11/14 5.5 8.5 0.25 0.0/88.0 4.5 9.3 0.40 33000 200 03/22/02 5800 10.0 39 7 13 4/6/1 0 5.2 6.4 0.25 1.0/90.0 4.5 6.4 0.40 33000 320 03/23/02 7240 11.35 46 17 14 9/24/32 6.5 11.9 0.25 1.0/85.0 5.0 9.2 0.00 28500 180 03/24/02 8324 11.35 41 13 12 8/14/20 5.6 13.3 0.25 0.5/84.0 9.0 9.2 0.05 30000 200 03/25/02 8510 11.40 47 20 18 9/18/25 5.2 14.4 0.50 0.5/83.0 11.0 8.75 0.00 28500 200 03/26/02 8510 11.60 46 16 18 12/30/32 5.2 13.2 0.25 0.5/84.0 10.0 8.60 0.00 31000 240 03/27/02 8510 11.50 43 8 11 217/11 5.8 14.0 0.25 0.5/83.5 10.0 7.70 0.00 28000 240 03/28/02 8510 10.00 40 12 13 2/7/1 0 5.0 8.3 0.12 0.5/89.5 0.0 7.90 0.00 25000 320 03/29/02 8545 10.20 54 10 11 4/9/13 6.8 8.9 0.12 0.2/89.0 10.0 10.20 0.50 24000 320 03/30/02 8605 10.00 53 23 18 3/6/6 3.0 9.2 0.10 1.0/87.5 7.0 8.00 0.00 30000 280 03/31/02 8665 10.10 54 21 17 4/8/8 2.8 9.7 0.10 0.0/88.0 6.2 8.00 0.00 30500 280 04/01/02 8725 10.10 54 21 18 3/8/8 3.0 8.5 0.10 0.2/89.0 7.0 8.00 0.00 30000 200 04/02/02 9100 10.10 45 16 13 5/14/14 3.8 8.3 0.10 0.1/89.0 7.5 8.50 0.00 33000 400 04/03/02 9100 10.10 45 14 16 4/11/11 3.6 8.5 0.10 0.1/89.0 7.0 8.,40 0.00 31000 280 ( ( (::I EP()C::H 42 At,Iw_g ""tTi-~"';C~~\ AL TAMURA #1 BIT RECORD BIT# MAKE TYPE SIN DEPTH DEPTH FOOTAGE HOURS ROP WOB RPM TORQUE PUMP IN OUT PRESURE 1 STC HTCS-C MJ 5242 107' 2762' 2655' 31.8 83.5 18.9 78.8 3531 1783 2 STC S88HPX JS 3515 2762' 8510' 5749' 77.8 73.9 8.4 7.07 3938 2569 3 Smith XRT+ MK 3003 8510' 8545' 30' 2.32 12.9 26.4 108.2 5466 2096 4 STC S75BPX JS 1419 8545' 9100' 555' 4.49 123.6 5.8 79 7183 2341 [~ EP()(~H ~" "~ lOG 0 N U A T N T U H E E G E R R E R ',-/ R E A S 0 N P U L L E D 43 ~--- -F"'l-) r)(-'~'-H" . It:il , ..J - (._,f -- 5801 Silverado Way Anchorage, AK 99518 (907) 561-2465 Sample Type Start Depth End Depth Amount Vvet Sarnples 107' 1-590' \Net Sarnples 1590' 3120' VVet S¡'lrnples 3120' 4380' VVet Sarnples 4380' 5670' VV(~t Samples 5670' 7500' VVet Samples 7500' 8605' VVet Samples 8605' 9100' Dry SZHnples 107' 9100' 7 Dry S8Inples 107' 9100' 7 Dr-y S8mples 107' 9100' 7 Isotube!,ii) Gas Samples 8-1'10'1 8-1125 1 Isott.Ü)e(¡(! Gas Samples B-1 '126 8-11 50 1 Isotube"I~) Gas Samples 8-11 51 B-1175 1 Isotube!í(: Gas Samples B--1176 8-1200 1 IsoiubeQ!} Gas Samples 8-1476 B-1 500 1 -,~- isotube:y,! Gas Samples 8-1501 B-1 525 1 Geochern Samples 8545' 8610' Geochem Samples 8620' 8725' ~- A-~tF~~ h~~<"'{"'J>¡;r<>¡o<>'-' AL TAMURA #1 SHIPPING MANIFEST Date Shipped 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 4/5/2002 [:I EPOC~H ---- Operator: Well Name: Location: Date: Date Received 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 4/6/2002 Signature: Anadarko Petroleum Corporation Altamura #1 NPRA North Slope Alaska 4/9f2002 Remarks Sent to ~vl¡ke Beattie in Houston 281-873-3852 Set '1 Set 2 Set 3 Empty 25 used of 25 25 used of 25 22 used / 3 unused Empty Empty 14 bottles 14 bottles Person Shipping Brady Kilmer " " " " " " " " " " " ÞlÂV;~¿~'~ 44 "'---- -~ ¡en ~t- :)Q:: :Eo <cD. t-W ciQ:: -~. C) J§z Ill,' '. ,'~,:,~ z -k Q:: } ° ~ :e ~~ .,-,' ~ 1.0 v ~ r -, V ¡tØ"", '-/ H ~ ~ CASING INFORMATION 16" @ 105' SURVEY DATA DEPTH INCLINATION BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT 12.25 STC 3X20 1X12 105 ANADARKO Altamura #1 REPORT FOR Doug Beserechtl DATE Mar 11, 2002 TIME 00:16:09 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT ( MW FC GAS SUMMARY(units) DITCH GAS CUTTI NG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY ~<';rO-t"cn~"",ì",,"j, AL TAMURA #1 DAILY WELLSITE REPORT [1 El-'OCH DEPTH 161 YESTERDAY 105 PRESENT OPERA TION= Drill Ahead 24 Hour Footage 56 AZIMUTH VERTICAL DEPTH FOOTAGE CON DmON T/B/C REASON PULLED HOURS 1.2 VIS SOL HIGH LOW AVERAGE CURRENT AVG 77.3 @ 132 29.0 @ 125 21.7 53.8 ft/hr 1691 @ 107 521 @ 106 589.6 806.0 amps 13 @ 107 13 @ 106 5.9 13.4 Klbs 83 @ 119 23 @ 106 31.2 45 RPM 456 @ 156 276 @ 106 158.5 393 psi DEPTH: PV YP Fl. Gels CL- SD OIL MBL pH Ca+ CCI HIGH LOW AVERAGE 3 @ 107 0 @ 134 0.4 TRIP GAS= - 0 @ 161 0 @ 161 0.0 WIPER GAS= - CH ROMA TOGRAPHY(ppm) SURVEY= - 153 @ 160 -17 @ 134 16.2 CONNECTION GAS HIGH= - 0 @ 161 0 @ 161 0.0 A VG= 0 0 @ 161 0 @ 161 0.0 CURRENT - 0 @ 161 0 @ 161 0.0 CURRENT BACKGROUND/AVG 0 0 @ 161 0 @ 161 0.0 LlTHOLOGYfREMARKS GAS DESCRIPTION DAILY ACTIVITY SUMMARY CLAY; CONGLOMERATIC SAND; SAND Daily Cost Logging $2555.00f Insturmentation $625.00 Epoch Personel On Board= 4 Report by: Andrew Buchanan ( " [::s :EP()C::H 46 ANADARKO (' Altamura #1 REPORT FOR Doug beresecht DATE Mar 12, 2002 TIME 23:56:10 CASING INFORMATION 16" @ 105' ,A..__1-~~ MURA #1 ~~=~ ALTA DAILY WELLSITE REPORT [1 EPOCH, DEPTH 587 YESTERDAY 161 PRESENT OPERATION= Drill ahead 24 Hour Footage 426 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CON DITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PU LLE D 105 482 7.3 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY R PM PUMP PRESSURE DRILLING MUD REPORT MW VIS ( FC SOL GAS SUMMARY(units) DITCH GAS 27 CUTTING GAS 0 METHANE(C-1) 4558 ETHANE(C-2) 0 PROPANE(C-3) 0 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY HIGH LOW AVERAGE CURRENT AVG 198.3 @ 188 2.7 @ 585 88.2 6.3 ft/hr 4619 @ 466 -1022 @ 328 2476.7 1838.2 amps 25 @ 569 0 @ 259 13.3 21.0 Klbs 86 @ 531 -3 @ 328 76.0 86 RPM 1035 @ 261 363 @ 328 704.8 730 psi DEPTH: PV yp Fl SD OIL MBL HIGH LOW AVERAGE CL- Gels pH Ca+ CCI @ 440 0 @ 257 @ 567 O@ 587 CH ROM A TOGRAPHY(ppm) @ 578 7 @ 257 854.1 @ 587 0 @ 587 0.0 @ 587 0 @ 587 0.0 @ 587 0 @ 587 0.0 @ 587 0 @ 587 0.0 TRI P GAS= - WIPER GAS= - SURVEY= nil 5,8 0.0 CONNECTION GAS HIGH= nil A VG= nil CURRENT 7 CURRENT BACKGROUND/AVG 2 LITHOLOGY/REMARKS GAS DESCRIPTION PRESENT LITHOLOGY 20% Tuffaceous Ash, 20% Tuffaceous Clay, 20% Clay, 20% Tuffaceous Siltstone; 20% Siltstone DAILY ACTIVITY SUMMARY Drill ahead; work on top drive; work on pumps; drill ahead Epoch Personel On Board= 4 Report by: Andrew Buchanan ( Daily Cost Logging $2555.00 / insturmentation $675.00 rr:.ø F"'I) ')C"'H" , 1l:1ll ..,j l , 47 A_/~:~ A #1 ~l"-~''''(~'''.''-'''¡'-'''' AL T AMUR ANADARKO DAILY WELLSITE REPORT [~ EPOCH ( Altamura #1 REPORT FOR DATE Mar 13,2002 TIME 24:00:00 DEPTH 1901 YESTERDAY 588 PRESENT OPERATION= Drilling ahead 24 Hour Footage 1313 CASING INFORMATION 16" @ 105' SURVEY DATA DEPTH INCLINATION BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT 12.25 stc 3x20 1x12 107 AZIMUTH VERTICAL DEPTH FOOTAGE 1796 HOU RS 21.8 CON DITION T/BfC REASON PULLED DRILLING MUD REPORT HIGH LOW AVERAGE CURRENT AVG 466.0 @ 1680 4.0 @ 588 116.3 25.7 ftIhr 5666 @ 1365 759 @ 1072 3332.4 3503.0 amps 34 @ 1901 0 @ 1852 13.5 34.6 Klbs 94 @ 1543 34 @ 1072 82.1 86 RPM 1550 @ 1830 565 @ 590 1280.8 1407 psi DEPTH: DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY R PM PUMP PRESSURE ( MW FC VIS SOL PV YP Fl. SD OIL MBL HIGH LOW AVERAGE 273 @ 1677 4 @ 1609 80.3 0 @ 1901 0 @ 1901 0.0 Gels CL- pH Ca+ CCI GAS SUMMARY(units) DITCH GAS CUTTING GAS TRIP GAS= WIPER GAS= METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) CHROMA TOGRAPHY(ppm) 52040 @ 1677 765 @ 1609 10066 @ 1893 1 @ 948 10089 @ 1893 10089 @ 1901 0 @ 1901 0 @ .190'1 0 @ 1901 0 @ 1901 14849.9 61.4 61.5 SURVEY= nil CONNECTION GAS HIGH= nil AVG= 80 0.0 0.0 CURRENT CURRENT BACKGROUND/AVG 30 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY drill ahead Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost logging $2555.00finstrumentation $675.00 ( [:I EP()C::H 48 i Ite:~~:j AL TAMURA #1 Anadarko DAILY WELLSITE REPORT [~ El~OCH ~" Altamura #1 REPORT FOR DouglDarrel DATE Mar 14,2002 TIME 24:00:00 DEPTH 2762 YESTERDAY 1913 PRESENT OPERATION= Stand Back BHA 24 Hour Footage 849 CASING INFORMATION 16" @ 105' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CON DITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25 STC FGSH+C 3X20,1 X12 107 2763 2656 31.7 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 362,4 @ 2511 8.2 @ 2299 92.4 77.2 ft/hr SURFACE TORQUE 6771 @ 2705 2 @ 2087 4481.5 5328.9 amps WEIGHT ON BIT 46 @ 2410 3 @ 2628 30.1 32.3 Klbs ROTARY RPM 92 @ 1927 9 @ 2077 74.6 81 RPM PUMP PRESSURE 1948 @ 2539 824 @ 2299 1621.4 1783 psi DRILLING MUD REPORT DEPTH: 2762 MW 10.05 VIS 43 PV 11 YP 21 FL Gels 5/8/9 CL- 44,000 ( FC 2 SOL 5.0 SD 0.25 OIL 0.0 MBL 3.0 pH 9.3 Ca+ 160 CCI METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH LOW AVERAGE 138 @ 2511 15 @ 2278 61.5 TRIP GAS= - 0 @ 2762 0 @ 2762 0.0 WIPER GAS= - CH ROMA TOGRAPHY(ppm) SURVEY= NIL 26798 @ 2511 2920 @ 2278 11456.3 CONNECTION GAS HIGH= Nil 90 @ 2715 2 @ 2277 12.2 AVG= NIL 73 @ 2715 1 @ 2567 5.5 CURRENT 0 20 @ 2709 1 @ 2637 1,4 CURRENT BACKGROUND/AVG 0 0 @ 2762 0 @ 2762 0.0 GAS SUMMARY(units) DITCH GAS CUTTING GAS HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 50% Clay, 20% Shale, 20% Siltstone, 10% Tuffaceous Clay DAILY ACTIVITY SUMMARY Drilled ahead from 1924' to 2762', casing depth, and circulated out; filled trip tank and circulated hole cl.ean; trip,ped out of the hole, bac.kreaming from 2208' to shoe. Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $2555.00+lnsturmentation $675.00 ( (1 EP()(:H 49 ~,~~,~~t~~ ALTAMURA#1 Anadarko DAILY WELLSITE REPORT Altamura #1 REPORT FOR DarrellGarry [J EPOCH DATE Mar 15, 2002 TIME 24:00:00 DEPTH 2762 YESTERDAY 2762 PRESENT OPERATION= Lay down and rack back BHA 24 Hour Footage 0 CASING INFORMATION 16" @ 105' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CON DITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 15.25 STC FGSH+C 3x20,1 x12 107 2762 2655 37.8 TD DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT HIGH LOW 0 @ 0 0 @ 0 0 @ 0 0 @ 0 0 @ 0 0 @ 0 0 @ 0 0 @ 0 0 @ 0 0 @ 0 DEPTH: PV YP SD OIL AVERAGE 0 0 0 0 0 ROTARY RPM PUMP PRESSU RE DRILLING MUD REPORT ( MW FC VIS SOL GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH lOW AVERAGE 0 0 0 @ 0 0 @ 0 0 @ 0 0 @ 0 METHANE(C-1) ETHAN E(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) CH ROMATOGRAPHY(ppm) O@OO@O 0 O@OO@O 0 O@OO@O 0 O@OO@O 0 O@OO@O 0 HYDROCARBON SHOWS INTERVAL UTHOLOGYfREMARKS LITHOLOGY PRESENT LITHOLOGY 50% Clay, 20% Shale, 20% Siltstone, 10% Tuffaceous Clay CURRENT AVG 0 ft/hr 0 amps 0 Klbs 0 RPM 0 psi Fl MBL Gels CL- pH Ca+ CCI TRIP GAS= 63 WIPER GAS= - SURVEY= - CONNECTION GAS HIGH= - A VG= - CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION DAILY ACTIVITY Continue to back ream out of the hole. Download Sperry-Sun tools before laying down and racking back Bottom Hole SUMMARY Assembly. Make up BHA and run into the hole washing and reaming as necessary. Circulate bottoms up and pump high viscosity sweep. Circulate hole clean and POOH for casing. Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3230.00 ( \ [~ EP()C:H 50 P\'l''1&~ iA._...-IJ.~~ MURA #1 ~,~~\~~.!,,"n AL T A Anadarko DAILY WELLSITE REPORT ( Altamura #1 REPORT FOR Darrell Garry DATE Mar 16. 2002 [~ El~OCH DEPTH 2762 YESTERDAY 2762 PRESENT OPERATION= Nipple down diverter TIME 24:00:00 24 Hour Footage 0 CASING INFORMATION 95/8" @2760' SURVEY DATA DEPTH INCLINATION AZIMUTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION @ @ SURFACE TORQUE @ @ WEIGHT ON BIT @ @ ROTARY RPM @ @ PUMP PRESSURE @ @ DRILLING MUD REPORT DEPTH: MW VIS PV YP FL ( FC SOL SD OIL MBL GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ CUTTI NG GAS @ @ CH ROMA TOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY 50% Clay, 20% Shale, 20% Siltstone, 10% Tuffaceous Clay VERTICAL DEPTH CON DITION TIBIC REASON PU LLE D CURRENT AVG ftIhr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= 38 WIPER GAS= - SURVEY= - CONNECTION GAS HIGH= - A VG= - CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION DAILY ACTIVITY Finish pulling out of the hole before racking back and laying down the bottom hole assembly. Rig to and run 9 5/8" SUMMARY casing. Casing landed at xxxx.x'. Riged to and ran cement. Cement in place at 1900 hrs. Waited on cement and rigged down cementers. Clear the rig floor and nipple down the diverter. Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 ( fJ r~P()(~H 51 Ao:-~W.~ AMURA #1 ~, ," C'~N""~~ AL T ""IIJ:~:GI:'\~.tl''l ,,'- ... Anadarko DAILY WELLSITE REPORT ( Altamura #1 REPORT FOR Darrel/Doug DATE Mar 17, 2002 i [~ El~OCH DEPTH 2762 YESTERDAY 2762 PRESENT OPERATION= Nipple up and test BOPE. TIME 12:17:34 24 Hour Footage 0 CASING INFORMATION 95/8" @ 276C1 SURVEY DATA DEPTH INCLINATION AZIMUTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION @ @ SURFACE TORQUE @ @ WEIGHT ON BIT @ @ ROTARY RPM @ @ PUMP PRESSURE @ @ DRILLING MUD REPORT DEPTH: MW VIS PV YP Fl ( FC SOL SD OIL MBL GAS SUMMARY(unb) HIGH LOW AVERAGE DITCH GAS @ @ CUTTI NG GAS @ @ CH ROMA TOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY. 50% Clay, 20% Shale, 20% Siltstone, 1,0% Tuffaceous Clay. DAILY ACTIVITY SUMMARY Finish nippling down diverter and nipple up BOPE, Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 (' '-- [:œEP()(~H VERTICAL DEPTH CONDITION T/B/C REASON PULLED CURRENT AVG ftlhr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= - WIPER GAS= - SURVEY= - CONNECTION GAS HIGH= - A VG= - CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION 52 f ~~~i ALTAMURA#1 Anadarko DAILY WELLSITE REPORT ( Altamura #1 REPORT FOR Darrel/Garry DATE Mar 18,2002 DEPTH 2762 YESTERDAY 2762 TIME 24:00:00 24 Hour Footage 0 CASING INFORMATION 95/8" @ 2760" SURVEY DATA DEPTH INCLINATION AZIMUTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOU RS DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION @ @ SURFACE TORQUE @ @ WEIGHT ON BIT @ @ ROTARY RPM @ @ PUMP PRESSURE @ @ DRILLING MUD REPORT DEPTH: MW VIS PV YP FL ( FC SOL SD OIL MBl GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ CUTTI NG GAS @ @ CH ROMA TOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY 50% Clay, 20% Sli1al.e, 20% Siltstone, 10%, Tuffaceous Clay DAILY ACTIVITY SUMMARY Continue to nipple up BOPE, test same. Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 ( [:Il-~P( )C=H [~EP()CH PRESENT OPERATION= Test BOPE VERTICAL DEPTH CON DITION T/B/C REASON PULLED CURRENT AVG ft/hr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= - WIPER GAS= - SURVEY= - CONNECTION GAS HIGH= - AVG= - CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION 53 ~~~~~ AL TAMURA #1 Anadarko DAILY WELLSITE REPORT f Altamura #1 REPORT FOR DarrellGarry { [1 EPOCH DATE Mar 19, 2002 TIME 24:00:00 DEPTH 2762 YESTERDAY 2762 PRESENT OPERATION= Pick up drill pipe 24 Hour Footage 0 CASING INFORMATION 9 5/8~ @ 2743' SURVEY DATA DEPTH INCLINATION BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT 2 8.5 STC S88HPX JS 3515 4X10,4X11 2762 AZIMUTH VERTICAL DEPTH FOOTAGE HOURS CONDITION T/B/C REASON PULLED DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION @ @ SURFACE TORQUE @ @ WEIGHT ON BIT @ @ ROTARY RPM @ @ PUMP PRESSURE @ @ DRILLING MUD REPORT DEPTH: ( MW VIS PV YP FL FC SOL SD OIL MBL GAS SUM'MARY(units) HIGH LOW AVERAGE DITCH GAS @ @ CUTTI NG GAS @ @ CH ROMA TOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY 50% Clay, 20% Shale, 20% Siltstone, 10% Tuffaceous Clay DAILY ACTIVITY SUMMARY Continue testing BOPE, pick up drill pipe. ( Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 (:I :EP()(":H CURRENT AVG ft/hr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= - WIPER GAS= - SURVEY= - CONNECTION GAS HIGH= . A VG= - CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION 54 A.-.",._..¡,"~:~ MURA #1 ~~~ ALTA ~:'.r~';~:-~.¡":"\ I...-."It.. Anadarko DAILY WELLSITE REPORT [1 El~()CH l ~ Altamura #1 REPORT FOR JenniferlGarry DATE Mar 20, 2002 TIME 24:00:00 DEPTH 4187 YESTERDAY 2931 24 Hour Footage 1256 CASING INFORMATION 95/8" @ 2748' SURVEY DATA DEPTH INCLINATION BIT INFORMATION NO. SIZE INTERVAL IN OUT 2762 TYPE SIN JETS 4X10,4X11 2 8.5" STC S88HPX PRESENT OPERATION= Wiper trip AZIMUTH VERTICAL DEPTH FOOTAGE 1426 CONDITION TIBIC REASON PULLED HOURS 16.6 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE HIGH LOW AVERAGE CURRENT AVG 424.3 @ 3360 6.5 @ 3071 110.8 72.9 ft/hr 13430 @ 3378 0 @ 3099 2320.5 3189.4 amps 41 @ 3032 0 @ 3718 9.1 7.7 Klbs 81 @ 3930 0 @ 3589 43.5 61 RPM 2391 @ 3282 742 @ 3718 1843.2 1937 psi DEPTH: DRILLING MUD REPORT ( MW FC VIS SOL PV SD GAS SUMMARY(uni,ts) DITCH GAS CUTTING GAS HIGH LOW METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) 489 @ 3551 4 @ 3049 0 @ 4187 0 @ 4187 CH ROMA TOGRAPHY(ppm) 67979 @ 3551 980 @ 3049 10066 @ 4186 4 @ 3071 10089 @ 4186 1 @ 3419 2376 @ 3550 1 @ 3299 1411 @ 3550 1 @ 4083 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS YP OIL Fl MBL Gels CL- pH Ca+ CCI AVERAGE 78.0 0.0 TRIP GAS= - WIPER GAS= - SURVEY= - 12690.6 598.2 212.8 88.4 20.6 CONNECTION GAS HIGH= NIL AVG= NIL CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION LITHOLOGY Interbedded clays and siltstones. The clays are grading to shale in part and the siltstone occasionally grade to very fine sandstone. PRESENT LITHOLOGY 60% Clay, 20% Siltstone, 20% Shale DAILY ACTIVITY SUMMARY Continue drilling ahead with surveys to 4188'. Circulated bottoms up and pumped a weighted, high viscosity sweep around to clean the hole before pulling out of the hole for a wiper trip. Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 ( [1 :EP()(~H 55 ~( ,~ Anadarko AL TAMURA #1 { DAILY WELLSITE REPORT [1El~OCH f Altamura #1 REPORT FOR JenniferlGarry DATE Mar 21,2002 TIME 24:00:00 DEPTH 5022 YESTERDAY 4188 24 Hour Footage 834 CASING INFORMATION 95/8" @ 2748' SURVEY DATA DEPTH INCLINATION BIT INFORMATION NO. SIZE INTERVAL IN OUT 2762 TYPE SIN JETS 4X10,4X12 2 8.5 STC S88HPX PRESENT OPERATION= Drilling Ahead AZIMUTH VERTICAL DEPTH FOOTAGE 2281 HOURS 29.2 CON DITION TIBIC REASON PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE HIGH LOW AVERAGE CURRENT AVG 392.6 @ 4463 6.0 @ 4873 85.3 125.1 ftIhr 5589 @ 4731 -14 @ 4494 2671.8 4228.1 amps 35 @ 4406 0 @ 4809 8.6 6.8 Klbs 94 @ 4319 1 @ 4860 52.7 74 RPM 2824 @ 5013 1004 @ 4572 2077.3 2670 psi DEPTH: DRILLING MUD REPORT ( MW FC VIS SOL PV SD GAS SUMMARY(units) DITCH GAS CUTTI NG GAS HIGH lOW METHANE(C-1) ETHAN E(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) 194 @ 4356 14 @ 4704 0 @ 5022 0 @ 5022 CH ROMA TOGRAPHY(ppm) 23499 @ 4356 1868 @ 4704 10066 @ 5015 169 @ 4704 10089 @ 5015 65 @ 4704 671 @ 4355 17 @ 4704 264 @ 4355 1 @ 4985 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS YP Oil Gels CL- Fl MBl Ca+ CCI pH AVERAGE 66.1 0.0 TRIP GAS= - WIPER GAS= 1660 SURVEY= - 8703.8 992.7 CONNECTION GAS HIGH= 42 AVG= 491.7 152.8 21.2 CURRENT 0 CURRENT BACKGROUND/AVG 35 GAS DESCRIPTION LITHOLOGY Predominantly intebedded clays and siltstones occasionally grading to very fine sandstone. Occasional thicker, coarser sand units observed at bottom of section. PRESENT LITHOLOGY 40% Siltstone, 20% Sandstone, 20% Shale, 10% Sand, 10% Clay DAilY ACTIVITY SUMMARY Continue to wiper trip to shoe pumping out as necessary. Run into the hole washing down the last stand before resuming drilling. Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 ( [:I ,EP()(~:H 56 Andarko ( Altamura #1 REPORT FOR Jennifer/Garry DATE Mar 22.2002 TIME 24:00:00 CASING INFORMATION 95/8" @ 2748' í) ~~~,. AL TAMURA #1 DAILY WELLSITE REPORT [1 EPOCH DEPTH 6147 YESTERDAY 5040 PRESENT OPERATION= Drill ahead 24 Hour Footage 1107 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOU RS T/B/C PULLED 2 8.5 STC 2762 3415 43.0 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS ( FC SOL GAS SUMMARY(units) DITCH GAS 632 CUTTI NG GAS 8 METHANE(C-1) 111721 ETHANE(C-2) 10066 PROPANE(C-3) 10089 BUTANE(C-4) 1460 PENTANE(C-5) 477 HYDROCARBON SHOWS INTERVAL LITHOLOGY HIGH lOW AVERAGE CURRENT AVG 1887.9 @ 5459 10.1 @ 5806 92.4 69.6 ftlhr 8345 @ 5459 60 @ 5813 4062.4 4173.5 amps 115 @ 5208 0 @ 5898 5.9 5.2 Klbs 92 @ 5532 28 @ 5923 79.0 81 RPM 3220 @ 6027 1,375 @ 5043 2829.8 2821 psi DEPTH: PV SO yp Cl- FL Gels Ca+ CCI OIL MBL pH HIGIi. LOW AVERAGE 126.8 0.0 TRIP GAS= - WIPER GAS= 690 SURVEY= - @ 6109 24 @ 5402 @ 5653 7 @ 5654 CH ROMA TOGRAPHY(ppm) @ 6109 2952 @ 5309 @ 6110 202 @ 5309 @ 6110 98 @ 5309 @ 5984 38 @ 5402 @ 5984 1 @ 5252 17548.0 1449.1 926.9 251.7 90.4 CONNECTION GAS HIGH= - A VG= - CURRENT 129 CURRENT BACKGROUND/AVG 45 LITHOLOGY/REMARKS GAS DESCRIPTION PRESENT LITHOLOGY 70% Sandstone; 10% Siltstone; 10% Clay; 10% Shale. DAILY ACTIVITY SUMMARY Drill ahead; wiper trip; drill ahead Epoch Personel On Board= 4 Report by: Andrew Buchanan ¡ \, Daily Cost $3080.00 [:I ,EP()(:H 57 ( ( ( Anadarko Altamura #1 REPORT FOR Jenifer/Garry DATE Mar 23, 2002 TIME 24:00:00 ~~~ ALTAMURA#1 r:.iIJ~OO',~.'n\ 1..-,~'".t.. DAILY WELLSITE REPORT DEPTH 7271 YESTERDAY 6151 24 Hour Footage 1120 SURVEY DATA CASING INFORMATION 95/8" @ 2748' DEPTH INCLINATION BIT INFORMATION NO. SIZE TYPE 2 8.5 STC S88HPX DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC GAS SUMMARY(units) DITCH GAS CUTTI NG GAS METHANE(C-l) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL SIN JETS 4Xl0,4X12 INTERVAL IN OUT 2762 AZIMUTH FOOTAGE 2691 ( [~ El?OCH PRESENT OPERATION= Drill ahead VERTICAL DEPTH HOU RS 57.3 CON DITION T/B/C REASON PULLED HIGH LOW AVERAGE CURRENT AVG 210.1 @ 6842 18.4 @ 6961 83.6 23.0 ftlhr 7633 @ 7185 921 @ 7226 5155.1 5016.7 amps 26 @ 6939 0 @ 7173 9.1 5.0 Klbs 108 @ 6961 21 @ 7226 88.5 59 RPM 3667 @ 7206 1286 @ 6298 2868.8 3457 psi DEPTH: VIS SOL PV SD HIGH LOW 1523 @ 6273 8 @ 7130 0 @ 7271 0 @ 727'1 CH ROMA TOGRAPHY(ppm) @ 6273 1376 @ 7130 @ 6273 1'28 @ 7130 @ 6273 37 @ 7130 @ 7197 11 @ 7130 607 @ 6273 7 @ 7130 260464 23051 6328 1594 LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY 90% Sand, 10% Clay DAILY ACTIVITY SUMMARY Drill Ahead Daily Cost $3080.00 Epoch Personel On Board= 4 Report by: Andrew Buchanan [:I ,EP()C:H yp OIL AVERAGE 280.9 0.0 47659.3 3663.7 1028.0 359.5 153.5 Fl MBL Gels CL- Ca+ CCI pH TRIP GAS= - WIPER GAS= - SURVEY= - CON NECTION GAS HIGH= - A VG= - CURRENT 500 CURRENT BACKGROUND/AVG 80 GAS DESCRIPTION 58 Anadarko Altamura #1 REPORT FOR Jennifer/Garry DATE Mar 24, 2002 TIME 24:00:00 ~~;! ALTAMURA#1 DAILY WELLSITE REPORT DEPTH 8359 YESTERDAY 7271 24 Hour Footage 1088 SURVEY DATA CASING INFORMATION 95/8- @ 2748' DEPTH INCLINATION BIT INFORMATION NO. SIZE TYPE 2 8.5 STC S88HPX DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT ( MW FC GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY VIS SOL 200912 14995 10089 1443 695 SIN JETS 4X10,4X12 INTERVAL IN OUT 2762 AZIMUTH FOOTAGE 5497 YP OIL AVERAGE 229.3 0.0 41610.8 4147.4 1891.6 47904 200.1 PRESENT LITHOLOGY 70% Shale, 20% Tuffaceous Clay, 10% Carbonaceous shale [~ E1J()(~H PRESENT OPERATION= Drill ahead VERTICAL DEPTH HOURS 75.0 CONDITION T/B/C REASON PULLED HIGH LOW AVERAGE CURRENT AVG 349.5 @ 7626 11.3 @ 7733 74.2 22.2 ftIhr 7535 @ 8177 1347 @ 8170 5583.0 4974.4 amps 22 @ 8170 0 @ 8228 8.0 5.3 Klbs 102 @ 8267 25 @ 8170 89.9 86 RPM 3641 @ 7628 1963 @ 7310 3370.3 2658 psi DEPTH: PV SD HIGH LOW 1052 @ 7294 12 @ 8335 0 @ 8359 0 @ 8359 CH ROMA TOGRAPHY(ppm) @ 7294 8483 @ 7474 @ 7294 587 @ 7474 @8312 214 @ 7474 @ 8259 70 @ 7474 @ 7358 33 @ 7751 LlTHOLOGYfREMARKS DAILY ACTIVITY SUMMARY Drill ahead. Daily Cost $3080.00 Epoch Personel On Board= 4 Report by: Andrew Buchanan ( [::I E,P()(:H Fl MBL CL- Gels pH Ca+ CCI TRIP GAS= - WIPER GAS= - SURVEY= - CONNECTION GAS HIGH= Nil A VG= - CURRENT 60 CURRENT BACKGROUND/AVG 50 GAS DESCRIPTION 59 ( ( ( Anadarko Altamura #1 REPORT FOR Jennifer/Mike DATE Mar 25, 2002 TIME 24:00:00 A_i~~ AMURA #1 ~~~ ALT f,I~ ~,t~~'\.~I' ... DAILY WELLSITE REPORT DEPTH 8511 YESTERDAY 8359 24 Hour Footage 152 SURVEY DATA CASING INFORMATION 95/8" @ 2762' DEPTH INCLINATION BIT INFORMATION NO. SIZE TYPE 2 8.5" STC S88H PX DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC GAS SUMMARY(units) DITCH GAS CUTTI NG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY SIN JETS 4X10,4X12 INTERVAL IN OUT 2762 8510 AZIMUTH FOOTAGE 5749 yp OIL AVERAGE 69.5 0.0 12542.7 1809.9 884.8 367.8 189.9 1 ~ [1 EP()C.H PRESENT OPERATION= Circulating VERTICAL DEPTH HOURS 77.8 CON DITION T/B/C REASON PULLED TD HIGH lOW AVERAGE CURRENT AVG 578.6 @ 8454 15.7 @ 8472 41.9 22.6 ftlhr 6791 @ 8420 1017 @ 8454 4623.5 5251.0 amps 14 @ 8477 4 @ 8362 7.5 5.5 Klbs 86 @ 8359 19 @ 8454 64.6 82 RPM 3019 @ 8491 2324 @ 8361 2298.8 2829 psi DEPTH: VIS SOL PV SD Fl MBl Gels CL- HIGH LOW pH Ca+ CCI 199 @ 8485 30 @ 8422 0 @8511 0 @ 8511 CH ROMA TOGRAPHY(ppm) 38440 @ 8485 5493 @ 8422 4615 @ 8485 809 @ 8422 2116 @8485 398 @8422 924 @ 8485 165 @ 8422 426 @ 8485 86 @ 8422 LlTHOlOGYfREMARKS TRIP GAS= - WIPER GAS= 205 SURVEY= - CON NECTION GAS HIGH= - A VG= - CURRENT 50 CURRENT BACKGROUND/AVG 15 GAS DESCRIPTION DAILY ACTIVITY SUMMARY 70% Shale, 10% Carbonaceous Shale, 10% Tffaceous Ash, 10% Tuffaceous Clay Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 [:I EP()C:H 60 ~~~\ ALTAMURA#1 lI)'lI:,I\~~U~'1) \"..,.~L'1oIJI' Anadarko DAILY WELLSITE REPORT ( Altamura #1 REPORT FOR Jennifer/Mike DATE Mar 26,2002 TIME 24:00:00 DEPTH 8510 YESTERDAY 8510 PRESENT OPERATION= Run 7" casing 24 Hour Footage 0 CASING INFORMATION 95/8" @ 2762' SURVEY DATA DEPTH INCLINATION AZIMUTH BIT INFORMATION NO. SIZE TYPE INTERVAL JETS IN OUT SIN FOOTAGE HOURS DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION @ @ SURFACE TORQUE @ @ WEIGHT ON BIT @ @ ROTARY RPM @ @ PUMP PRESSURE @ @ DRILLING MUD REPORT DEPTH: ( MW VIS PV YP FL FC SOL SD OIL MBL GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ CUTTI NG GAS @ @ CH ROMA TOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUT AN E(C-4) @ @ PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY [1 El~OCH VERTICAL DEPTH CON DITION T/B/C REASON PULLED CURRENT AVG ft/hr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION DAILY ACTIVITY SUMMARY PRESENT LITHOLOGY 70% Shale, 10% Carbonaceous Shale, 10% Tuffaceous Ash, 10% Tuffaceous Clay Continue to circulate and condition mud for casing. Pull out of the hole and stand back and lay down the bottom hole assembly. Rig to and begin running 7" casing. Epoch Personel On Board= 4 Report by: Andrew Buchanan Daily Cost $3080.00 ( [:I EP()C:H 61 ~'4I~i¡ ALTAMURA#1 ¡::'¡'I"'I.)\.~"'J~'¡1 ",...,"(1"1.1" ANADARKO DAILY WELLSITE REPORT ( Altamura #1 REPORT FOR Jennifer/Mike DATE Mar 27,2002 TIME 24:00:00 DEPTH 8510' YESTERDAY 8510' 24 Hour Footage 0' CASING INFORMATION 95/8" @ 2762'; r @ 8500' SURVEY DATA DEPTH INCLINATION AZIMUTH BIT INFORMATION NO. SIZE TYPE INTERVAL JETS IN OUT FOOTAGE HOURS SIN DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION @ @ SURFACE TORQUE @ @ WEIGHT ON BIT @ @ ROTARY RPM @ @ PUMP PRESSURE @ @ DRILLING MUD REPORT DEPTH: ( MW VIS PV YP FL FC SOL SO OIL MBL GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ CUTTI NG GAS @ @ CHROMA TOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENT ANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY f, [1 El~()CH PRESENT OPERATION= BOP TEST VERTICAL DEPTH CON DITION T/B/C REASON PULLED CURRENT AVG ft/hr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION PRESENT LITHOLOGY 70% Shale; 10% Carbonaceous Shale; 10% Tuffaceous Ash; 10% Tuffaceous Clay DAILY ACTIVITY SUMMARY Run in 206 joints 7" casing to 8500'; Circulated and conditioned hole, 240 gas units Max; Completed pumping cement, displaced cement gave maximum 415 units of gas. Epoch Personel On Board= 4 Report by: A. Audet Daily Cost $3080 ( [=I El~()(:H 62 A--i~~ URA #1 Rt"~~~ ALTAM '~':f~~IL,I."'\'~ r..A.,'f1,: ANADARKO DAILY WELLSITE REPORT t Altamura #1 REPORT FOR Jennifer/Mike [1El~OCH DATE Mar 28, 2002 TIME 24:00:00 DEPTH 8510' YESTERDAY 8510' PRESENT OPERATION= RUN IN HOLE 24 Hour Footage O' CASING INFORMATION 95/8" @ 2762'; 7" @ 8500' SURVEY DATA DEPTH INCLINATION AZIMUTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION @ @ SURFACE TORQUE @ @ WEIGHT ON BIT @ @ ROTARY RPM @ @ PUMP PRESSU RE @ @ DRILLING MUD REPORT DEPTH: MW VIS PV YP FL FC SOL SD OIL. MBL ( GAS SUMMARY(units) HIGH lOW AVERAGE DITCH GAS @ @ CUTTING GAS @ @ CH ROMA TOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY VERTICAL DEPTH CON DITION T/B/C REASON PULLED CURRENT AVG ftIhr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION PRESENT LITHOLOGY 70% Shale; 10% Carbonaceous Shale; 10% Tuffaceous Ash; 10% Tuffaceous Clay DAILY ACTIVITY SUMMARY Test BOP's; Make up new BHA; Run in hole; displace mud, get 55 units of max gas. Epoch Personel On Board= 4 Daily Cost $3080 Report by: T. Smith ( [:I F~P()(:H 63 ANADARKO Altamura #1 REPORT FOR John/Mike DATE Mar 29,2002 TIME 24:00:00 ~~~~ AL TAMURA #1 ~'-t1~~';..!!.1~~"t J..,.~'1ë"~I:!, í ( DAILY WELLSITE REPORT [~ EPOCH DEPTH 8545 YESTERDAY 8510 PRESENT OPERATION= RIH WITH CORE ASSEMBLY 24 Hour Footage 35 CASING INFORMATION 95/8" @ 2762' T' @ 8500' AZIMUTH VERTICAL DEPTH SURVEY DATA DEPTH INCLINATION BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT 6.13 SMITH XRT + MK3003 1X15,2X14 8510 8545 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS ( FC SOL GAS SUMMARY(units) DITCH GAS CUTTI NG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY CONDITION T/B/C REASON PULLED FOOTAGE HOU RS 35 HIGH LOW AVERAGE CURRENT AVG 38.0 @ 8532 5.2 @ 8514 16.7 20.6 ft/hr 5838 @ 8515 5106 @ 8529 5170.7 5255.0 amps 32 @ 8537 5 @ 8511 25.0 28.5 Klbs 118 @ 8517 41 @ 8512 102.3 115 RPM 2851 @ 8510 1170 @ 8512 1983.4 21.65 psi DEPTH: PV yp Fl. Gels CL- SD OIL MBL pH Ca+ CCI HIGH LOW AVERAGE 85 @ 8542 3 @ 8513 13.5 TRIP GAS= @ @ WIPER GAS= CH ROMA TOGRAPHY(ppm) SURVEY= 12159 @ 8542 630 @ 8513 2139.0 CONNECTION GAS HIGH= 1542 @ 8542 74 @ 8513 264.8 AVG= 762 @ 8542 35 @ 8513 139.6 CURRENT 313 @ 8542 15 @ 8513 50.8 CURRENT BACKGROUND/AVG 178 @ 8542 5 @ 8540 11.9 LITHOLOGY/REMARKS GAS DESCRIPTION PRESENT LITHOLOGY 40% SHALE, 10% CARBONACEOUS SHALE, 30% TUFFACEOUS CLAYSTONE, 20% TUFF DAILY ACTIVITY SUMMARY Epoch Personel On Board= 4 Report by: T. Smith Drill cement, 7" shoe, 20' new formation; P.I.T. (13.5 E.M.W.); drill to 8545'; POOH; M/U core assembly; RIH. Daily Cost $3080 (:I :EP() ( ~H 64 ANADARKO ( Altamura #1 REPORT FOR John/Mike DATE Mar 30. 2002 TIME 24:00:00 A"_ooQ..L¡~l RA #1 ~~,~~,~C,~",!"" AL T AMU DAILY WELLSITE REPORT [1 EPOC,H DEPTH 8605 YESTERDAY 8546 PRESENT OPERATION= Trip out with core assembly 24 Hour Footage 59 CASING INFORMATION 95/8" @2762' T' @8500' AZIMUTH VERTICAL DEPTH SURVEY DATA DEPTH INCLINATION BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT CB#1 6.13 1964272 8545 8605 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS ( FC SOL GAS SUMMARY(units) DITCH GAS CUTTI NG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY CON DITION T/B/C REASON PULLED FOOTAGE 60 HOURS 9.2 HIGH LOW AVERAGE CURRENT AVG 29.9 @ 8599 2.3 @ 8556 11.4 19.4 ft/hr 7613 @ 8600 3673 @ 8597 6228.9 6923.0 amps 14 @ 8559 2 @ 8604 10.3 4.6 Klbs 67 @ 8598 30 @ 8597 63.1 67 RPM 1390 @ 8546 773 @ 8597 1195.6 1230 psi DEPTH: PV YP Fl Gels CL- SD OIL MBL pH Ca+ CCI HIGH' LOW AVERAGE 431 @ 8602 7 @ 8559 90.3 TRIP GAS= 150 @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 64643 @ 8602 858 @ 8559 13067.2 CONNECTION GAS HIGH= 8102 @ 8602 99 @ 8559 1601.8 AVG= 3844 @ 8602 50 @ 8557 751.4 CURRENT 1394 @ 8602 3 @ 8561 273.8 CURRENT BACKGROUND/AVG 549 @ 8603 3 @ 8562 102.1 LlTHOLOGY/REMARKS GAS DESCRIPTION PRESENT LITHOLOGY 50% SANDSTONE; 30% TUFFACEOUS CLAYSTONE; 10% SILTSTONE; 10% TUFF. DAILY ACTIVITY SUMMARY Finish RIH with core assembly; core from 8545' to 8605'; POOH with core. Epoch Personel On Board= 4 Report by: T. Smith ( Daily Cost $3080 1r-l!L'I)(")('~,H , t=I .l-~" . .~.. 65 ~~~~i ALTAMURA#1 'C>",'~:.x""'¡í1~ ".01";:"0' ANADARKO DAILY WELLSITE REPORT [~ EPO(~H ( Altamura #1 REPORT FOR John/Mike DATE Mar 31,2002 TIME 24:00:00 DEPTH 8665 YESTERDAY 8605 PRESENT OPERATION= POOH with core #2 24 Hour Footage 60 CASING INFORMATION 95/8" @ 2762' T' @ 8500' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE SIN INTERVAL JETS IN OUT FOOTAGE HOU RS CON DITION T/B/C REASON PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 193.9 @ 8656 19.4 @ 8605 70.3 31.8 ft/hr SURFACE TORQUE 9281 @ 8641 6690 @ 8661 8486.2 7252.5 amps WEIGHT ON BIT 9 @ 8621 0 @ 8648 5.6 1.8 Klbs ROTARY RPM 71 @ 8661 63 @ 8641 66.6 69 RPM PUMP PRESSURE 1767 @ 8609 -128 @ 8606 1308.8 1273 psi DRILLING MUD REPORT DEPTH: MW VIS PV yp Fl Gels Cl- FC SOL SD Oil MBl pH Ca+ CCI GAS SUMMARY(units) HIGH lOW AVERAGE DITCH GAS 1732 @ 8657 241 @ 8605 1268.2 TRIP GAS= CUTTI NG GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1) 231184 @ 8614 34577 @ 8605 182072.1 CONNECTION GAS HIGH= ETHANE(C-2) 43243 @ 8645 4331 @ 8605 30799.2 AVG= PROPANE(C-3) 23652 @ 8650 2074 @ 8605 15960.3 CURRENT BUTANE(C-4) 10947 @ 8657 768 @ 8605 6447.3 CURRENTBACKGROUN~AVG PENTANE(C-5) 4285 @ 8659 530 @ 8605 2329.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 70% sandstone, 20% sand, 10% shale. DAilY ACTIVITY SUMMARY Finish POOH with core #1, UD core #1, M/U for core run #2, RIH, core from 8605' to 8665', POOH. Epoch Personel On Board= 4 Daily Cost $3080 Report by: T. Smith ( [:I :EP()C:H 66 ~~i~ #1 ~~ ALTAMURA ';¡.t:h~~~n "'''''''';;'0' { ANADARKO DAILY WELLSITE REPORT [~EP()CH ( Altamura #1 REPORT FOR John/Mike DATE Apr 01 , 2002 TIME 24:00:00 DEPTH 8725 YESTERDAY 8665 PRESENT OPERATION= RIH with BHA#8 24 Hour Footage 60 CASING INFORMATION 95/8" @ 2762' T' @ 8500' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE SIN INTERVAL JETS IN OUT FOOTAGE HOU RS CON DITION T/B/C REASON PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 74.8 @ 8677 8.7 @ 8723 36.4 31.5 ftIhr SURFACE TORQUE 8361 @ 8709 6118 @ 8723 4928.8 6799.0 amps WEIGHT ON BIT 12 @ 8709 1 @ 8665 9.4 8.9 Klbs ROTARY RPM 72 @ 8722 66 @ 8709 47.0 70 RPM PUMP PRESSURE 2000 @ 8685 1273 @ 8665 1091.5 1400 psi DRILLING MUD REPORT DEPTH: MW VIS PV yp Fl. Gels CL- ( FC SOL SD OIL MBL pH Ca+ CCI GAS SUMMARY{units) HIGH LOW AVERAGE DITCH GAS 454 @ 8673 161 @ 8701 273.3 TRIP GAS= CUTTI NG GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1) 62863 @ 8672 15171 @ 8701 31752.3 CONNECTION GAS HIGH= ETHANE(C-2) 8497 @ 8672 2555 @ 8701 4988.1 AVG= PROPANE(C-3) 4743 @ 8665 1366 @ 8701 2526.9 CURRENT BUTANE(C-4) 2288 @ 8665 588 @ 8701 1147.4 CURRENTBACKGROUN~AVG PENTANE(C-5) 1031 @ 8665 328 @ 8666 635.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 40% SANDSTONE, 20% SAND, 20% SILTSTONE, 20% SHALE DAILY ACTIVITY SUMMARY Finish POOH with core #2, LID same, M/U for core #3, RIH, core from 8665' to 8725', POOH, M/U BHA#8 and RIH ' Epoch Personel On Board= 4 Daily Cost $3080 Report by: T. Smith ( [:I :EP()C=:H 67 ANADARKO ( Altamura #1 REPORT FOR John/Mike DATE Apr 02,2002 TIME 24:00:00 t ~~!~~! AL TAMURA #1 DAILY WELLSITE REPORT [1 EPOCH DEPTH 9100 YESTERDAY 8725 PRESENT OPERATION= POOH 24 Hour Footage 375 CASING INFORMATION 95/8M @ 2762' 7" @ 8500' AZIMUTH VERTICAL DEPTH SURVEY DATA DEPTH INCLINATION BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT 4 6.125 S75BPX JS1419 5x11 8725 9100 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS ( FC SOL GAS SUMMARY(uni,ts) DITCH GAS CUTTI NG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY CON DITION T/B/C REASON PU LLE D TD FOOTAGE 375 HOURS 4.5 HIGH LOW AVERAGE CURRENT AVG 239.1 @ 9025 8.1 @ 8838 97.4 121.6 ftIhr 7951 @ 9018 6305 @ 8749 7194.3 6929.9 amps 9 @ 8945 0 @ 8735 4.4 1.8 Klbs 91 @ 8842 70 @ 8725 88.8 90 RPM 3351 @ 9028 1400 @ 8725 2894.2 2935 psi DEPTH: PV yp FL Gels CL- SD OIL MBL pH Ca+ CCI HtGH LOW AVERAGE 854 @ 9100 58 @ 8829 236.3 TRIP GAS= 168u @ @ WIPER GAS= CH ROMA TOGRAPHY(ppm) SURVEY= 97629 @ 9100 6051 @ 8829 23403.4 CONNECTION GAS HIGH= 22778 @ 9100 1151 @ 8829 4819.0 AVG= 12924 @ 9100 611 @ 8726 2753.8 CURRENT 5104 @ 9100 279 @ 8726 1209.6 CURRENT BACKGROUND/AVG 1662 @ 9100 150 @ 8769 481.2 LlTHOLOGY/REMARKS GAS DESCRIPTION 50% SHALE, 30% SILTSTONE, 10% TUFFACEOUS SILTSTONE. 10%TUFFACEOUS CLAYSTONE, ABUNDANT PYRITE AGGREGATE Epoch Personel On Board= 4 DAILY ACTIVITY SUMMARY Finish RIH, drill from 8725' to TD @9100', POOH Daily Cost $3080 Report by: T. Smith ( [::I EP()C:H 68 Sperry-Sun Drilling Anadarko Alaska Altamura Altamura 1 (South) WP04 -i '_.-tI -rv-SUI1 Cef,J...bJHr.f. $J¡r,,~ A~~ .- ã3 ~ .s:: ã. Q) 0 (ij 0 ~ 6000- > ;t:: a a a N II "510000 - ,!;; Q) [ij I.) (J) 0----------- ..-.---- _m__n. ----~ ---m___n- fj;¡~-¡P~'n~~~-¡;;'~-; f;-.ff/ :hlji T~il) 2000- 9 518" 2750.00ft MD 2750.00ft 1VD ------ J ~ ,¿B~i_~- D_i~_~ 4~~~~,?,~~,~ : 3000.0Oft MD, 3000.000 TVD /_m 1....)-=,,;.:W'}'.R~ At -:;.'it;Ý.f}i¿{t ;} i) 4000 ---- !t':;~~r~~;~~~,;,:~:~::::~:~'~~~~::~:V: ¡,__n-y. Jy-~YJNf£ 1,- u -End Dir, Start Sail @ 0.000°: 4817.48ftMD,4725.0OftTVD --..----- -__n"_' --------- » iff ê ! m ,_n__'~ r¡'n____- "0 0 to> ---T=Tt":. Shtl?~::s ;~;.¡.37 tj!Jf; 11-'1) -~ -- -~ --~ ~~~- ~~- tj'j) --------- ----~- ----....,--- "_.____h _mh_--. n_- . .--- "__n__n__- un no . . -'0 --------- _n_~-- .h__-n- . _n - - . --" ". n . ...n- __nn___- -- 8000- ! 7" ;__lL. _aQ51.48ft MD ___m .:--- omo ;-.::=_:::,:_:~ :::::,::,M59.o.00:1VO::.::_:::.::: 4112" ¡ 10124.48ft MD -- 10032.000 1VD; u ~ -. ---- -------- ;~'':'~~ q..~3JJ¡¡Ht T;7.J LL-Total Depth: 10124.48ftMD,10032.0OOTVD I I 0 2000 Scale: 1 inch = 200l:mection Azimuth: 161.115° (True North) Vertical Section (Well) :.,: ri1 Begin Dir @ 4.000°/1000 : 3000.000 MD, 3000.00ft TVD End Dirt Start Sail @ 25.006° : 3625.14ftMD,3605.48ftTVO¡ Begin Dir @ 4.000°/1000: 4192.34ft MD, 4119.~ Scale: 1 inch = 2~~ting~ (Well) 0 I 200 I I I End Dir, Start Sail @ 0.000° : 4817.48ftMO,4725.0OftTVD Total Depth : 10124.48ftM~,1p032.0OOTVD ~~- I ¡ WeB: ¡ Horizontal Coordinates: i Ref. Global Coorömates : ¡ Ref. Structure: I Ref. Geographical Coordinates: i RKB Elevation: ; ~ i North Reference : Units: Current Well Properties AlIa mura 1 (South) 5888899,10 N. 284418.40 E 882423.71 N, 240718,59 W 70.05' 57,5662" N, 151.43' 45,3985' W -0 - -200 -- Q) ~ IJI. V> c 1: 1:: - 400 ~-., S, 16-1,51 t: == 0 0 N - -600 \I -5 .E (¡j ] (J) ----~ 149,OOft above Mean Sea Level 149,OO1t above Structure True North Feet (US) Proposal Data for Altamura 1 WP04 ; I i Vertical Origin: Well , Horizontal Origin: Well Measurement Units:ft North Reference: True North '1 ---"---. -'~'---'-'--'-"'----'--'-'-" ""'-'----.. . m_..__...-.---.---.----- Dogleg severity : Degrees per 100 feet (US) Vertical Section Azimuth: 161.115° Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E 'JIeasured Incl. Azim. Vertical Northings Eastlngs Vertical Dogleg Depth Depth Section Rate -- 0.00 0.000 358.374 0.00 O.OON 0.00 E 0.00 3000.00 0.000 358.374 3000.00 O.OON 0.00 E 0.00 0.000 3625.14 25.006 161.115 3605.48 127.04 S 43.46 E 134.26 4.000 4192.34 25.006 161.115 4119.52 353.89 S 121.06 E 374.02 0.000 4817.48 0.000 358.374 4725.00 480,93 S 164.5\ E 508.29 4.000 8601.48 0.000 358.374 8509.00 480.93 S 164.51 E 508.29 0.000 10124.48 0.000 358.374 10032.00 480.93 S 164,5\ E 508.29 0.000 REV DA 1£ -::SCRIPTION REV OA 1£ BYÇ' APP REV. ,( ..J:) RD., &: ADD illV. ( I , ~:~ ~~0 Il~~ ~ 28 ~ 27 .~ -à~.ð NOTES: 1 ~ 'V ~, ~ ff ~ a V , 03~\..:..td 31 £"\ .SIS OF HORIZONTAL AND VERTICAL LOCATION t 10 N ~,~", . 32 33 0\13400 ARE MONUMENTS 23-10-1 AND 24-10-1 t 9 () ~~~ .' ~ c§/' . , SET BY LOUNSBURY & ASSOC. 2 Q 1 ~ ñð : '''CJ.<; 2 ~n&-, . n'" , \; , 0 -~en ezvous 4U" 3 '~~ 2. COORDlNA lES SHOYvN ARE ALASKA STAlE PLANE Q ~ b '-J ~ . ~ Ð ZONE 4. NAD 27. .' ~ 0 l ~ ~ ~.. ~ 0 tJ 3. GEOGRAPHIC COORDINAlES ARE NAD 27. ;," '~'~9 fI-, ~.' , 4. ELEVATIONS SHOWN ARE BRITISH PETROLEUM :I~~ ,~~ ~C\' b .: l? '.. G? MEAN SEA LEVEL DATUM. N C' 18 I I~~ ~~ ~5' , t:I' 14 5. ALL DISTANCES ARE TRUE. qo 0 , :A ".. J '4:' ~. 0 . ~ \ 0 L 6, ICE PAD IS ROTATED 70' EAST FROIA NORTH, .. 230 ' ~TAo!,U~~~". 2~ ð ¡t . .' of" \ ~ 7. DATE OF SURVEY: 2/11/02; FB L02-6, Pp. 1-3. ~ <,. .~. ~. ~ ~I C 22. 2j,f ;: .'0) <7' V\'/~\.f"" . ~ .~. ,. ~ 26 eJ.25 LTMiô~ N~~ t' 28 <ßs ~ 'l~: ~ .l J ~ \, AL TAMURA No. , ~ \:~: C ~\ " E b' :;--.s ~.: ~ . LOCA lED WITHIN PROlRAClED " ~. 36 .~ ~ ;- ~/.¡,,? 34 do t ,f:t. 'to þ.-: SEC. 30, T 9 N, & R 2 E, I~ß '\ ~b ~Ql' J:'I!. '~'~~ ~ UMIAT MERIDIAN, 0 " II .' ';" utt. ... 332' F.S,L, 2260' F.W.L. 2,>. ~.!l¡¡'.. 5 - 4 03".', 2 .ø~''¡¡ LA T = 70-05'57.575- VI CINITY MAP SCALE: 1" = 2 MILES LONG = 151.43'45.344" Y = 5,888,899.91 X = 284,420.30 ~ROUND ELEV. = 82.4' rop OF ICE PAD ELEV. = 86.4' BY CK APP DESCRIP1l0N 1 1/31/02 RLS CC ... N ~.....~""" ..4tÞ~r¿ CF '- . , ......-- ..-'\ I '\ ~ ...............k~-'~ 4 ......-- .~, ,~ -or ~ .tit/. \ . -.J .. .. ..:\ \9" / -. II H ; *... ......-- / II vI ' ......-- -' (" OJ\\~'" ~ " ! 49th '. \ ~ ~\ ~"\..) \ ~ ....J-..........- \ * t .. -' ~ ...... iI! ............,¡ .. ~ \..- ? ...... \ iI! ....- - .-. i! / <t- iI! .. ,-""'''''--' iI! \ V" ~ ~ \ BR ........ ~ \'" ~ ~ , IAN G M ---,.....j to \ ".. ~ ... . ANGOlD ¡ Pi" ~ ~" f.. ~ .... LS-8626 ~.: I A "\ / ~ . ~o ..... ,/ ; L TAM U RAN 0 ,\ .4 t-~;'";7 .._~::..._.......... I) ,I' . ~ Y '. tssIONÞ.\. \,.t-~....' ~ . ç'od ./.> .\./ -::;,. <fi)t' """,..........4' ~"'. !\~ ./ ./ \./ 1> ~ /"' /"' /"' /"' "!J~'Ó Š ¡¡'/ ... ~ /~ ?0" ~ \ ....--:: <01$ ~ ......--"""-- "'~ 1 C/) SURVEYOR'S CERTIFICA TE SCALE: 1" = 200' A~-gulLI I HERES Y CERTIFY THA T I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE SY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBURARY 14, 2002 Anadarko S Petroleum Corporation CADD F1LE NO. I DRAWING NO: LK60tD457 2/13/02 AL TAMURA No.1 EXPLORATORY, WELL CONDUCTOR & ICE PAD ASBUIL T LOCA llON NSK 6.0' - d457 I SHEET: t Cf' t I REV; ø 2;.rJ 10'3~ljd 9Þ:£1 G00G 10 AljW { j", - I I . /¿;? / J;h~ ~: RELAB d~~.,-- Core ~bor~tori~$ - AI~$k$ From: Core Laboratortea 600 W. 68th Ave., Unit D Anchorage, Alaska 99618 ~CJ~', c;~ L /tiS To: Alaska 011 & Gas Cons. Comm. 333 W. 7th #100 Anchorage, Alaaka 99&01 907 -279-1433 Date: Apr-12-2002 Well Name: Anadarko Petroleum, Altamura Number of Sampl88~ Contact: John Hartner Description of Material: Core Chip Samples Depths: 6545-8722 Sent By: 1)1.1 v ~ (i; s 1'(:;12, Core Laboratories Received By: .~:~ ./ RECEIVED APR 1 8 200/ At8aOl&GlsCÆ8.Qm..~ ~ -- ..JI~".J ..02 I' ANADARKO PETROLEUM CORPORATI~ 32~ MAIN 907/273-6300 TREET, SUITE 603 . ANCHORAGE, ALASKA 99503 Anadarl(p~ April 16, 2002 Mr. Thomas Maunder, PE Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Approval of Well Suspension for Anadarko Altamura #1, AOGCC Permit 202-010, NPRA Alaska Dear Mr. Maunder: Anadarko Petroleum Corporation hereby applies for Sundry Approval of Well Suspension Operations. Anadarko Petroleum plans to suspend the above referenced well upon completion of Flow Testing operations. Pertinent information attached to this Sundry includes the following: 1. Application for Sundry Approval (Form lO-403) 2. Suspension Justification 3. Suspension Procedure 4. Proposed Suspension Wellsketch Please review this application and advise if you are in agreement with the suspension plans. For your information, this Sundry request is being simultaneously submitted to the U.S. Bureau of Land Management. If you have any questions or require additional information, please contact me at (907) 273-6300. Sincerely, 0~~\~~~ Tommy ftd~ Drilling Superintendent RECEIVED CONFIDENTIAL enclosures APR 1 6 2002 Af8ka0l1& GIs ConI. Commission Aedorage ORIGINAL , STATE OF ALASKA (I ALASKA d'L AND GAS CONSERVATION(L,ùMMISSION APPLICATION FOR SUNDRY APPROVALS kY.b'-\ ~ 9'/..<. 1. Type of Request: Operation shutdown: Re-enter suspended well: Plugging: -Time extension: Stimulate: Variance: Perforäte: Other: - 5. Type of well: 6. Datum elevation (DF or KB) Development: KB Exploratory: x 7. Unit or Property name Stratigraphic: - Service: Abandon: Suspend: x Alter casing: Repair well: Change approved program: Pull tubing: 2. Name of Operator Anadarko Petroleum 4. Location of well at surface X = 284,420.30 E Y = 5,888,899.91 N At top of productive interval X = 284,582.41 E Y = 5,888,367.51 N At effective depth X = 284,583.60 E Y = 5,888,367.49 N At total depth X == 284,589.26 E Y = 5,888,368.15 N 3. Address 3201 C Street, Ste 603 Anchorage, AK, 99503 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 792 measured true vertical 29 feet Altamura 8. Well number 9. Permit number 202-010 10. API number 50-103-20403-00 11. Field/Pool 76 2,721 8,472 9,100 feet Plugs (measured) 9,014 feet 9,100 feet Junk (measured) 9,014 feet Size Cemented 16 surf 9518 surf 7 7,050 RECËI~ED 9,014 Measured depth True vertical depth 103 2,750 8,501 103 2,750 41/2 8,557 - 8,575, 8,590 - 8,655 8,308 9,100 APR 1 6 200) 8,471 - 8,489, 8,504 - 8,569 Tubing (size, grade, and measured depth) 3 1/2, 9.3 ppf, L-80, EUE 8rd Mod to 8,308 Alask8OillGasCoß$. Commission Anchorage 13. Attachements Packers and SSSV (type and measured depth) Baker ZXP liner top packer @ 8,399, Cameo TRM 4E SCSSV @ 1,524 BOP sketch: Description summary of proposal: X Detailed operations program: 16. If proposal well verbally approved: 14. Estimated date for commencing operation 04/22/2002 Suspended: - 15. Status of well classification as: Oil: Gas: Date approved Name of approver Tom Maunder 04/04/2002 Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe9' ".l'fj -..,..), ~ \."'", ~ Title:~l\~~ ~~~ C 1-- c "'-.. _Y FOR COMMISSION U$ ONLY --, Conditions of approval: Notify Commission so representative may witness , ~ Plug integrity- BOP Test- Location clearance Mechanical Integrity Test- Subsequent form required 10- ~t) \t-C..\\,)~\~ ~\, ",~~M"-:. ~ \C)~~ CONFIDENTiAl Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Date: ~h,,-( 0'2...- APproval No~ ~LJ;;2.-i3 ) Onglnal Signed B~ 'CJmmy Occh.sü T ~~ç ¿¡ ;J!;>.(j)- Commissioner Date 1~ p a !j SUBMIT IN TRIPLICATE ~, Anada...l1 Petroleum Corporation Suspension Justification for the Anadarko Petroleum Altamura # 1 The Altamura # 1, located about 20 miles WSW ofNuiqsut, is being drilled to help delineate the Moose's Tooth complex jointly owned by Anadarko Petroleum and Philips Petroleum. Over the next few years, there will likely be several flow tests in this field to help prove it's commercial viability. The Altamura # 1 is intended to be used as an observation well to help characterize the reservoir. Permanent BH pressure-Surface Readout gauges are installed in this well. They will be used to monitor pressure transients from the other wells. - . { Altamura Drilling Program NPRA Alaska 2001-2002 Drilling Season ~! PetrOleum Corporauon Altamura #1 Suspension Procedure 1. MIRU SLU and lubricator. RU lubricator and test to 5000 psig with Nitrogen. 2. Make 2.250 GR run to 8,700'. POOH. 3. MU Quartz Electronic Pressure Gauges. RIH to 8,700' and make a 5 minute gradient stop 4. Pull gauges to mid perf @ 8622' and collect data for 1 hr. Pull gauges to mid perf @ 8566' and collect data for 1 hr. 5. Pull gauges making 5 min gradient stops every +1- 100' from mid 8566' to 200 ft above top gauge mandrel @ 8054'. Align gradient stops to be adjacent to the 3 downhole pressure gauges @ 8256', 8144', and 8054'. 6. POOH making 5 min gradient stops every 500' to surface. LD gauges and verify data recovery. 7. Pickle and freeze protect by pumping 75 bbls diesel down the tubing. 8. Make 2.800 GR run to 8,223'. POOH. 9. RIH and set PXN plug in the 2.813 XN nip at 8223. POOH. 10. RIH and set PXN prong in the PXN plug. POOH. 11. RIH wI 2.75 catcher sub and set on top of PXN plug. POOH. 12. PU kick over tool and 1141" JDC pulling tool. RIH and pull top pressure gauge at 8054. POOH. 13. RIH and pull bottom pressure gauge at 8144. POOH. 14. RIH and set dummy valve in bottom gauge mandrel at 8144. POOH. 15. RIH and set dummy valve in top gauge mandrel at 8054. POOH. 16. RIH and retrieve catcher sub. POOH 17. RDMO SLU 18. Bleed off pressure to close SCSSV. 19. Install BPV in tubing hanger. 20. Close master valves, wing valve and swab valve. Remove the valve hand wheels. 21. Install VR plugs in the annulus valves. 22. Install cellar guard to protect wildlife. Install well identification sign. - 1 - i' Altamura # 1 NPRA - North Slope, Alaska Suspended Well bore Sketch Rig: S: T: Nabors 14-E I R: [Z) GL: 86.4' MSL I KB: 115.4' MSL KB: Lockdown studs + 25.8' 20" Hole 16", 65ppf, H-40 @ +/- 80' Cmt to surf i. s.. B/ Permafrost @ 649' [Z). 3.5" TRM-4E SCSSV 3HSS-1247 2.81 X-nip @ 1539' (closed) 12-1/4" Hole r--- Camco 3.5"x1" KBUG-MW/DM.BK-5 Mandrel @ 2640' Nova Injection sub @ 2,729' :s. 9-5/8", 40ppf, L-80, BTC @ 2,746' Cmt to surf - CMT wI 329 sx 10.7 ppg (lead) + 327 sx 15.9 ppg (tail) :z. I Note: All depths are measured depths from RKB to top of the Kick-off point @ 3000' (Max dev = 24 deg, DLS = 4.5 deg/100 ft) Hold angle @ 23 deg, 3550 - 4100 Drop angle at 4100' Vertical @ 4850' - 3 1/2,9.3 ppf, EUE 8rd-mod, L-80 tubing FC Slumps @ 6,337' TOC @ 7050' (USIT log) 8-1/2" Hole Camco 3.5" x 1" KBUG-MW/EKED D.,BEK Side Pocket Mandrel @ 7965' BST Pressure Gauge Mandrels @ 8,144',8,054' Camco 2.750 XN profile nipple @ 8,223' c/w PXN plug Promore Surface Read Out Pressure Guages @ 8,256' Baker G-36 seal assembly Baker 7x41/2 Lnr Hngr c/w ZXP Packer and 10' PBR @ 8,308' X-over, 2 7/8" tbg (2 jts + 3 pups), flow sub @ 8401, and REG @ 8437' 7" , 26ppf, L-80, BTC-mod @ 8,501' - cmt wI 52.3 bb113.0 ppg (lead) + 34.7 bb115.8 ppg (tail) ~ Perfs (6 JSPF with 2-112" scallop gun w/11g HMX millenium charges) 8557 - 8575' Stim sleeves (8560-66, 8572-75) 8590 - 8655' Stim sleeves (8594-8606, 8616-28, 8638-50) 6-1/8" Hole Dropped TCP perf gun (gun assembly 218 ft + 10 foot bar) PBTD after dropping guns = 8777' 4-1/2", 12.60ppf, L-80, IBT-mod, Liner 8308 - 9096' PBTD = 9010' MD Cmt wI 30 bb112.0 ppg cemcrete TD = 9100' MD, 9014' TVD ( NOTE TO FILE AL TIMURA #1 202-010 302-131 Anadarko Petroleum Corporation has requested to suspend Altimura #1. Anadarko drilled this well in NPRA during the past season. It appears that they have been successful in finding hydrocarbons. They are presently testing the well and propose to retain it initially for observation purposes and potentially as a production well if the commercial viability of the "Moose's Tooth Complex" is proven. Anadarko has included a surface readout gauge in their completion that will allow them to return to the well and download pressure information without having to disturb any of the wellbore plugs. It is my opinion that Anadarko can satisfy the criteria as listed in 20AAC 25.110, although I do not have specific volume, rate or quality information. (1 ) (A) encounters hydrocarbons of sufficient quality and quantity... (1 )(C) has potential value as a service well (2)(C) need for pool delineation and evaluation to determine the prudence of pool development Given the limited drilling season and the desire of the successful past operator (PPCo) to retain the ability to re-enter recently drilled exploration wells, a modified plugging procedure has been developed to address wellbore security and to facilitate the ability to plug the well according to the regulations without needing a drilling rig. Although cementing and wireline/electric line equipment would be needed for a P&A, the necessary equipment is transportable should the need arise to plug a well. Anadarko proposes to secure the well by displacing the tubing with diesel and establishing 3 mechanical plugs in the wellboré. The plugs include one immediately above the production packer, a closed subsurface safety valve and a backpressure valve in the tubing hanger. Annulus isolation includes the liner top packer and the tubing seal assembly, brine and diesel annulus fluid and the tubing hanger seals. Anadarko plans to remove all valve hand wells and install "VR" plugs in all annulus valves. When these steps have been accomplished, the well will be secure. I recommend that Anadarko's plans be approved. ~~~ 4(~~-o~ Tom Maunder, PE Sr. Petroleum Engineer AOGCC . ( . Alaska Oil and Gas Conservation (;\)mmission Attention: Tom Maunder Fax(907r276-7542 GENERAL INFORMATION: 1. Property 2. Well Name & No.: 3. Prospect: 4. API No.: 5. Permit Number: 6. Rig Floor: CONFIDENTIAL Anadarko Petroleum WEEKLY ACTIVITY REPORT (Partial) PERIOD: 04102102 thro 4108/02 AA-081736 Altamura No.1 Wildcat 50-103-2043..00 202-010 29 ft 7. Designated Operator: 8. Rig Name: 9. Contact/Phone No.: 10. Spud Date 11. TO Date: 12. SUS., COMP., or ABN Date: CURRENT WELL SUMMARY INFORMATION: (' Bureau of Land Management Attention: Greg Noble Fax (907)-267-1304 Anadarko Petroleum Corp. Nabors #14-E Tommy W. Thompson /907-273-6302 March 10, 2002 (22:00 hrs AST) April 02, 2002 (15:30 hrs AST) NA MDITVD: 9,100'/9,014' Mud Weight: 10.0 Last BOP Test Date: 3/28/02 T est Pressures (psi): 5000 Well Status (Drlg, Camp, WO, TA, PA): Coring Summary of Operations: Complete coring operations, Run MDT, ....(prep for liner job) 13. 14. 15. 16. 17. 18. Casing/Liner Summary Casing Details 16" 9..5/8" 7" Depth (MD/TVD) , Test Press~re (psi) 105 2747 8501/8415 Cement Vol. (cuft) Shoe Test (E~W) 13.5 13.5 1846 491 3000 3500 19. List all open-hole logs and surveys run (Including MWD, velocity surveys and directional surveys): Date SPUD 3/10/02 . Log/Survey GR, Res, Dens /Poros, Sonic Interval (MD) Surface-9, 1 00' Indicate below if any of the following samples/surveys were taken: 20. Velocity Surveys: 21. Conventional cores: 22. Sidewall cores: Yes Yes XXX Yes 23. 24. 25. Paleo Samples: Litho samples: Geochem samples: 1 Run Number Yes Yes Yes APR 15 2002 11:13 FR APC ALASKA 19075639479 TO 2767542 P.02/03 dDd.-'Ô/O . > (' AI_,", 011 and Gas Conservatlft.. ~mml88lon Attention: Tom M.under Fax (907)-278-7542 CONFIDENTIAL Anadarko Petroleum WEEKLY ACTMTY REPORT PERIOD: 04108102 thru 04114102 GENERAL INFORMATION: 1. Property 2. Well Name & No.; 3. Prospect: 4. API No.: 5. Permit Number: 6. Rig Floor: M-081738 Aftamura No.1 Wildcat 50-103-2043-00 202.010, ,. 29 ft 7. Designated Operator: 8. Rig Name: 9. Contact/Phone No.: 1°, Spud Date 11. TD Date; , 12. SUS., COMP" or ABN Date: I CURRENT WEll SUMMARY INFORMATION= 13. 14. 15. 16. Bureau of lend Management Attention: Greg Noble Fax (907)..261-1304 Anadarko Petroleum Corp. Nabors #14..E Tommy W. Thompson 1907.,,273.6302 March 10, 2002 (22:00 hrs AST) April 02, 2002 (15:30 hrs AST) NA MDITVD; . ::gi,1iQO,~I$,,()14 , Mud Weight 9,8 -.. Last BOP Test Date: 4/07/02 Test Pressures (pSi): 3500 Well Status (Drtg, Comp, WQ, TA, PA): Rng. CA Summary of Operations: Run completion aMembly & te$t, RDMO rotary rig and prep for tEtsting operatl4;>ns. 17. 18. Casing/liner Summary ". ,'O,' ~.~.... r', '..... -.. -,W" R . .. .' ..t..,.....- . - '" v" " II ,6" ., A. ',--...-., ..~,_. .- '," ~-- ¡.,: ,. -'" N..'II .....~.. )\"".""."".""..."r,1,v' ,..",,,., ,:rrr,.",_",. " "., ""',,", '~~":''''_.'II1I",',J ',''~"'''\' - - Ç~~in9,De!,~JI~ Depth (MDnvP) , _T.~te.~l.I~ (psi). Shoe Test {f;MyV> . " .,' ç~æ.~.f.:1ty~".(ç,lI,fn",: 16" 1 05 . . 9-5/8"""''''''''..' , "."2747 3000 ~''''.'~'..', '...''''''''13.5 -,., ""'._-"""""''-'-1'846'''''.\ .,. " .7.,:'.., -,. ~501/a41'~:~~',:':'~~...,,,,,, ....-- 3500 :-.. -" .., . ..,I~~§"., '" ,-.. ....-. - .~,.."",~u_'_:::':~~'.'::~~::,4~ 1,~~,'~:',~~: , .".' '... 4-1/2" 9095 3500 N/a 168 - - .n- "','" , ..,~-_... M'-.. -. .. "'_.11......._- - .- '''-.¡'''' .,," .'~~.. ...............- -,""..,. ,~.,.".~"".,-".. ""'/' .~. I' :-..-.,.,..... . -"'''''''''_4~_- . "'1' t , .... " ,-,~..- I, ,n_..- List all open~hole Jogs and survey a run (including MWD, velocity surveys and directional surveys): 1~ . '''''''V I . \¡# . . .-. -.'- " '... ," ,. ~,,~. ." "Qat~"".''''''. ~ "--''',~ _,:,~~/Su;v~y'.'--""" ~,_..,:J~~~rVãï{MDr- -U"',. ,. " ":,',,~ûñ'~Njirñt)'e,r~,_'m"__.',.,",...- 3/10/02 ,~.4/02/02" GR, Res, Dens,!p'Qros, Sonic Surface-.9. ~.OO' , ' LWD/MWD/PWD '. '''4/03/02 .. ...,~, MDT" " --... 8,500' ~ TD ", '^ "--" _~_M"~"__"~.'-'-'~"--"""",~"",, ''''4/07/02 -" .. '.. """----- USIT .-...." "~""'."7 050' - TO .,..". ''''.. ". ,. '.-" ,.... .. ,"",II -.., ..., ... , . n'.'...II_', ....,. Indicate below jf any of tht¡;) following sampleslsurveys were taken: 20. Velocity Surveys: 21. Conventional cores: 22. SfdewaU cores: Yes" ,,,,' ""'" ". 23. 'V ",' .~~".",',",'''" ".'-'..-. !I,' ,',~)o,'.",!"("', ., T ."'~'~j"!~"":"': ., 24. Yes"" ",,' ','.!,,,,:'::.;,v 25. Paleo Sampfes: Litho semples: Geochem samples: 1 ,......" .. cäsed Höìe Rûñ'"1~"~"'--'''~''''- -...-... ";,-.,~....'Itb.,,,,..A4tI,,, """'"'''''' ",..,.."",,. Yes Yes Yes - .," ~ APR 15 2002 11:14 FR APC ALASKA 19075639479 TO 2767542 P.03/03 ( ( CONFIDENTIAL Anadarko Petroleum WEEKlY ACTIVITY REPORT PERIOD: 04lO8I02 thru Ot/14102 OPERATIONS DETAIL Report Date: \ Mon 4/08/02: RIH w/3-1/2" Dummy A$Sembly & sting in, test tbg. To 4700 psi, test annulua to 2500 psi, $1'OH wI Dummy Assembly. Tues 4109/02: LO Dummy Assembly, RIH w/3-1/2" CA & control Unes, prep to sting in. Wed 4/10102: RIH wI CA. DIsplace Diesel & corrosion Înhìbited fluid to annulus, land hanger, test annutus to 3600 psi, RD casing tools, install 2~way check, Start RDMO Thurs 4/11/02: RDMO, ND Stack, NU Tree & Test, install SPV, RD pumps, choke & killlJnes. m'Jd pit$, (Haul 12 load$) Fri 4/12/02; RDMO, LD Top Drive. C~Section, V-Door, etc... (Haul 3 loads) Sat 4113/02; RDMO Lower floor & derrick, & RD wind walls (Haul 8 loads) Stln 4/14/02: RDMO, Truck out derrick, RD pump houses (HaUled 11 loadS) , ;1 2 ** TOTAL PAC:;E. 03 ** ( Petroleum Corporation 20" Hole B/ Permafrost @ 649' ,Altamura # 1 / NPRA - North Slope, Alaska Suspended Well bore Sketch ; IZJ ' ¿ 9 5/8/1 X 7" Freeze protected wI 62 bbls Diesel .-» ,~ . 7/1 X 3 1/2/1 Freeze protected w/63 bbls Diesel ---.... 31/2" Freeze protected wI 38 bbls Diesel - ' , J t - 12-1/4" Hole Inhibited 9.8 ppg KCI-NaCI Brine FC Slumps @ 6,337' TOC @ 7050' (USIT log) USIT shows very poor cmt bond behind the 4 1/2" liner ( Rig: S: Nabors 14-E I T: R: GL: 86.4' MSL I KB: 115.4' MSL KB: Lockdown studs + 25.8' 16/1, 65ppf, H-40 @ 105' Cmt to surf ~ 1/4 SS control line for injection sub and SCSSV 3.5" TRM-4E SCSSV 3HSS-1247 2.81 X-nip @ 1539' (closed) Camco 3.5"x1" KBUG-MW/DM.BK-5 Mandrel @ 2640' ,¿, - Nova Injection sub @ 2,729' - So. 9-5/8", 40ppf, L-80, BTC @ 2,746' Cmtto surf - CMT wI 329 sx 10.7 ppg (lead) + 327 sx 15.9 ppg (tail) ----- Kick-off point @ 3000' (Max dev = 24 deg, DLS = 4.5 deg/1 00 ft) Hold angle @ 23 deg, 3550 - 4100 Drop angle at 4100' Vertical @ 4850' - 3 1/2, 9.3 ppf, EUE 8rd-mod, L-80 tubing 8-1/2" Hole . ~ PBTD after dropping guns = 8777' 6-1/8" Hole I Note: All depths are measured depths I from RKB to top of the tools. Camco 3.5" x 1" KBUG-MW/EKED D.,BEK Side Pocket Mandrel @ 7965' BST Pressure Gauge Mandrels @ 8,144', 8,054' Camco 2.813-2.750 XN profile nipple @ 8,223' c/w PXN plug Promore Surface Read Out Pressure Guages @ 8,256' Baker G-36 seal assembly Baker 7x41/2 Lnr Hngr c/w ZXP Packer and 10' PBR @ 8,308' X-over, 2 7/8" tbg (2 jts + 3 pups), flow sub @ 8401, and REG @ 8437' 7", 26ppf, L-80, BTC-mod @ 8,501' - crnt w/52.3 bb113.0 ppg (lead) + 34.7 bb115.8 ppg (tail) Perfs (6 JSPF with 2-1/2" scallop gun w/11g HMX millenium charges) 8557 - 8575' Stirn sleeves (8560-66, 8572-75) 8590 - 8655' Stirn sleeves (8594-8606, 8616-28, 8638-50) Dropped TCP perf gun (gun assembly 218 ft + 10 foot bar) 4-1/2", 12.60ppf, L-80, IBT-mod, Liner 8308 - 9096' PBTD = 9010' MD Cmt wI 30 bb112.0 ppg cemcrete TD = 9100' MD, 9014' TVD ".-.. Ov "; ~ Summary of Drilling Operations Anadarko Altamura # 1, NPRA Alaska, AOGCC 202-010, API 50-103-20403-00, BlM AA-081736/316( Anadarko FIT/lOT Report casing or BOP BOP Date other test Test Drill 3/6/02 3/7/02 3/8/02 3/9/02 3/1 0/02 3/11/02 3/12/02 3/13/02 3/14/02 3/15/02 3/16/02 3/17/02 3/18/02 3/19/02 3/20/02 3/21/02 3/22/02 3/23/02 3/24/02 3/25/02 3/26/02 3/27/02 3/28/02 3/29/02 3/30/02 3/31 /02 4/1/02 4/2/02 4/3/02 4/4/02 4/5/02 4/6/02 4/7/02 4/8/02 4/9/02 4/10/02 x x X X X X X X X X Operational Summary TO 105' KB, 16" conductor preset @ 105'KB, RU Rotary Tools. TO 105', RU Rotary Tools, Pre-Spud Meeting, Cut off 16" conductor, Install landing ring & diverter adapter spool, test to 350 psi. for 5 min., NU diverter spool. TO 105', Rig Up Rotary Tools, NU 21-1/4" Hydrill, PU 12-1/4" bit, install kill line (Lou Grimaldi - AOGCC on location). TO 105', RU Rotary Tools, Function Test diverter (Lou Grimaldi - AOGCC witnessed). TO 105', RU Rotary Tools, function test mud system, take on spud mud, PU OP. TO 165' (60'), PJSM, PU BHA, Spud 12-1/4" @ 22:00hrs 3/10/02, MW 9.9, vis. 65. TO 589' (424'), Orlg. 12-1/4" hole, MW 10.0ppg, vis. 65. TO 1,925' (1,336'), Orlg 12-1/4" hole, MW 10.0ppg, vis. 41. TO 2,763' (838'), Orlg. 12-1/4" hole, TO surface casing point, C&C, TF BHA, MW 10.0 ppg, vis. 42. TO 2,763' (0'), LO BHA, W&R to btm, C&C, Short trip to 1,802', C&C, STOH for 9-5/8" csg., MW 10.2ppg, vis. 43. TO 2,763' (0'), LO BHA, run 67 jts. 9-5/8", 40ppf, L-80, BTC csg., FS @ 2,746'. Cmt'd w/ 329 sx ASL FB 327 sx (15.8ppg @ 1.17cuft/sx) displace w/ 10.0 ppg KCUPHPA mud, PD @ 18:30 hrs,circ 110 Bbls. cmt to surface, floats held. WOC, NO diverter. TO 2,763' (0') Nipple down Oiverter. Install Bradenhead. Nipple up and start testing BOP's. Finish testing BOP's. PU drill pipe. Pick up drill pipe and BHA. TIH. Test 9 5/8 surf csg. to 3000 psi. OK. Drill out, drill 20' and perform FIT test to 13.5 ppgE. Drill 2782-2940. MW 9.5 ppg. Rotary and slide drill 2940-4189. Short trip. MW 9.5 ppg. Finish short trip. Rotary apd slide drill 4189-5030. MW 10.0 ppg. Drill 5030-6145. MW 10.0 ppg. Drill 6145-7285. MW 11.3 ppg. Drill 7285-8510. TO intermediate hole. MW 11.3 ppg. Run 7" csg to 3280. Circulate @ 9 5/8 shoe. Finish running 7" csg to 8501" MD. Cmt w/491 cuft class G+adds. Start testing BOP's. Finish Testing BOP's (effective test date 3/28/02). TIH. Displace hole w/ 10.2 ppg mud. Test Csg 3500 psig for 30 min OK. Drill out float eqpt. Displace w/ 9.5 ppg mud sys. Drl 8510 - 8530. Circ and condition mud. FIT test to 13.5 ppgE. Drl to core pt @ 8545. MW 9.7 ppg. Core # 1 8545 - 8605. Increase MW to 10.0 ppg. Core # 2 8605 - 8665. MW 10.0 ppg. Drlg. ahead to TD @ 9,100' MD (9,014'TVD) MW 10.1ppg. Run MDT Log, MW 10.1 ppg. " Make wiper trip, prep for liner job, MW 10.1 ppg. TOOH, Run 4-1/2" liner & cmt @ 9,095', MW 10.3 ppg. (Bo Brown on location) Set liner hanger, WOC, TOOH w/ setting tool, RIH to liner top, pressure test casing to 3500 psi, c/o Liner to 9,010' & pressure test to 3500 psi, displace hole w/ completion fluid, MW 9.8 ppg Displace hole w/ completion fluid, TOH LDDP, Run USIT CE log, c/o rams & test stack, MW 9.8 ppg. Make dummy run w/ 3-1/2" tbg & seal assembly, pressure test tbg to 4600 psi & annulus tc 3500 psi, MW 9.8 ppg brine. LD Dummy Assembly, RIH w/ 3-1/2" CA & control lines, prep to sting in. RIH w/ CA, Displace Diesel & corrosion inhibited fluid to annulus, Land hanger, test annulus to 3500 psi, RD tubing tools, install 2-way check, Start RDMO. cY ,I, ~\ ( Anadarko Petroleum Corporation Fax To: Greg Noble From: Tommy W. Thompson Phone: 907-267-1443 Pages: 12 + cover Fax: 907-267.1304 Date: April 04, 2002 Re: Suspension Request cc: Tom Maunder 0 Urgent ..\ . Comments: 0 for Review 0 Please Comment 0 Please Reply 0 PI.... Recycle Greg, As I mentioned by phone, Anadarko is requesting approval to potentially temporary suspend the Altamura NO.1 well bore (rather than P&A) on the premise that we will continually use the walloore for reservoir monitoring as the delineation and development of the "Moose's Tooth Complex" progresses. Ongoing and continued reservoir pressure monitoring will be very beneficial in the process of determining the commercial status of the play area. Enclosed are schematics of our proposed operation along with tentative procedures and plans. I have also included a brief update as to our current status as well as a timeline that would infer that we could not accomplish the remaining tasks and permanently abandon the well in the short timeframe remaining in this exploration season. I appreciate your consideration of this proposal. Tommy Thompson Please call when you have had the opportunity to review and are ready to provide comments and/or suggestions. RECEIVED APR 4 2002 AlllllOiIIGllConI.CommiIion AMIOIJge \~,,~ ~ X~ 5'~~~' c AN~DARKO PETROLEUM CORPORATI( 32(' MAIN 907/ 273-6300 .TREET, SUITE 603 . ANCHORAGE, ALASKA 99503 Anadal'l(p! April I, 2002 Mr. Thomas Maunder, PE Alaska Oil and Gas Conservation Commission 333 West 7tb Avenue, Suite 100 Anchorage, Alaska 99501 CONfID(NTIAL RE: Sundry Approval of Well Suspension for Anadarlm Altamura #1, AOGCC Permit 202-010, NPRA Alaska ' Dear Mr. Maunder: Anadarko Petroleum Corporation hereby applies for Slmdry Approval of Well Suspension Operations. Anadarko Petroleum plans to suspend the above referenced well upon completion of Drilling and Flow Testing operations. Pertinent information attached to tlús Slmdry includes tlle following: 1. Application for SWldry Approval (Form 10-403) 2. Suspension Justification 3. Suspension Procedure 4. Proposed Completion Wellsketch 5. Proposed Suspension Well sketch The Altamura # 1 is currently drilling. Due to time constraints, I am submitting design data rather tllan actual data. I expect tlmt the well construction will closely follow the submitted design. Please review this application and advise if you are in agreement Witll tlle suspension plans. I will file an update with actual data when tlle well constmction is complete. For your information, tl1Ís Slmdry request is being simlùtaneously submitted to the U.S. Bureau of Land Management. If you have any questions or reqlÙre additional information, please contact me at (907) 273-6300. Sincerely, RECEIVED Cc: well file ORIGINAL APR 4 2002 NllllflIGllConI.ConImiIion A.dtG.. Enclosures ,(' STATE OF ALASKA (i ALASKA OIL AND GAS CONSERVATIONc;OMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: x Alter casing: Repair well: Change approved program: PuiitUbing: 2. Name of Operator Anadarko Petroleum 1,725 measured Operation shutdown: Re-enter suspended well: Plugging: -Time extension: Stimulate: Variance: Perforate: ):>ther: - 5. Type of well: 6. Datum elevatioy'{DF or KB) Development: KB Exploratory: x 7. Unit or Pro~rty name Stratigraphic: - Service: 29 feet 3. Address 3201 C Street, Ste 603 Anchorage, AK, 99503 Altamura 4. Location of well at surface X = 284,420.30 E Y = 5,888,899.91 N At top of productive interval X = 284,569.20 E Y = 5,888,413.70 N At effective depth X = 284,569.20 E Y = 5,888,413.70 N At total depth X = 284,569.20 E Y = 5,888,413.70 N 202-010 10. API number 50-1 03-20403-00 11. Field/Pool 12. Present well condition summary Total depth: measured true vertical 10,124 10,032 feet feet Effective depth: measured true vertical 10,124 10,032 feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Measured depth True vertical depth 76 2,721 8,522 surf surf 6,400 103 2,750 8,551 103 2,750 8,459 8,399 10,124 10,032 true vertical Tubing (size, grade, and measured depth) 3 1/2fi.3 ppf, L-80, EUE 8rd Mod to 8,399 CONflDfNl1Al Packers and SSSV (type and measured depth) / ZXP liner top packer @ 8,399 13. Attachements Detailed operations program: BOP sketch: 14. Estimated date for commencing operatio 04/22/2002 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: - Name of approver Date approved Service: 17. I here,bY:iert', that the forego'n . is true and correct to the best of my knowledge. Signe,ç}." I SD'-'-' "'~ ~~ Title: ~'\<\ \ \~. tV~.~~E\? " FOR COMMISSION USE ~NL Y -1 Conditions 0 ro a: I Co . ion so representative may witness Plug integrity BOP Test- Location clearance Mechanical I grity Test- Subsequent form required 10- Date: 4/~11 ð 7 APproval N30d- / / g- Approved by order of the Commissioner RECEIVED Commissioner Date APR 4 2002 ORIGINAL Form 10-403 Rev 06/15/88 AI8IIIœaGl8QaCOlWnb8ion A-a.- SUBMIT IN TRIPLICATE ;( f An""'", t Petroleum Corporation Suspension Justification for the Anadarko Petroleum Altamura # 1 The Altamura # 1, located about 20 miles WSW ofNuiqsut, is being drilled to help delineate the Moose's Tooth complex jointly owned by Anadarko Petroleum and Philips Petroleum. Over the next few years, there will likely be several flow tests in this field to help prove it's commercial viability. The Altamura # 1 is intended to be used as an observation well to help characterize the reservoir. Permanent BH pressure-Surface Readout gauges are going to be installed in this well. They will be used to monitor pressure transients from the other wells. Altamura Drilling p~ugram NPRA Alaska 2001-2002 Drilling Season AnadIll'lAP! Petfol<'1um COfpol"ntloo Altamura #1 Suspension Procedure 1. MIRU SLU and lubricator. RU lubricator and test to 5000 psig with methanol. 2. Make 2.250 GR run to 8,950'. POOH. 3. MU Quartz Electronic Pressure Gauges. See notes concerning gauge setup. RIH to 8,850. Make 5 minute gradient stops at 8,800' and 8,700' 4. Pull gauges to mid perf@ 8,656' and collect data for 1 hr. 5. Pull gauges making 5 min gradient stops every +/- 100' from mid perf@ 8,656 to 200 ft above top gauge mandrel @ 8,213'. Align gradient stops to be adjacent to the 3 downhole pressure gauges. 6. POOH making 5 min gradient stops every 500' to surface. LD gauges and verify data recovery. 7. Make 2.800 GR run to +/- 8,400'. POOH. 8. RIH and set PXN plug in the 2.750 XN nip at +/- 8,337'. POOH. 9. RIH and set PXN prong in the PXN plug. POOH. 10. PU kick over tool and 11;4" JDC pulling tool. RIH and pull btm pressure gauge at +/- 8,275'. POOH. 11. RIH and pull top pressure gauge at +/- 8,213'. POOH. 12. RIH and set dummy valve in top gauge mandrel. POOH. 13. RIH and set dummy valve in btm gauge mandrel. POOH. 14. RDMO SLU 15. Close SCSSV. Dump 25 gals of diesel on top ofSCSSV. 16. Install BPV in tubing hanger. 17. Close master valves, wing valves and swab valve. Install VR plug in the annulus valve. Install tapped blind flange with plugged needle valve. 18. Remove the valve hand wheels. - 1 - ( a PCtfQleurn CorpOration Altamura # 1 NPRA - North Slope, Alaska Planned Wellbore Sketch ( Rig: I T: GL: 120'AMSL I KB: 29 ft S: Nabors 14-E I R: 20" Hole 16", 65ppf, H-40 @ 105' Cmt to surf BI Permafrost @ 649' v - TAM port collar @ 900' (contingency) SCSSV clw 2.81 X-nip @ 1,500' 12-1/4" Hole 9-518", 40ppf, L-80, BTC @ 2,750' Cmt to surf Injection Sub @ 3,000' J --- Side Pocket Mandrel @ TBA I Note: All depths are estimated in I measured depths from RKB - 31/2,9.3 ppf, EUE 8rd-mod, L-80 tubing Projected TOC is 100' above FC Slumps @ 6,429' 8-1/2" Hole Side Pocket Mandrel @ +1- 8,151' Pressure Gauge Mandrels @ 8,275',8,213' Baker BX 2.750 XN-nip @ 8,337' Promore Surface Read Out Pressure Guages @ 8,368' Baker 7x41/2 Lnr Hngr clw ZXP Packer and 10' PBR @ 8,399' 2 7/8" Seal Extension, flow sub, and GDAIWLEG 7" , 26ppf, L-80, BTC-mod @ +1- 8,551' 60' perfs @ +1- 8,626' - 8,686' (TCP- dropped) Dropped TCP perf gun 6-1/8" Hole - 4-1/2", 12.60ppf, L-80, IBT-mod, Liner @ 10,124' Altamura # 1 NPRA - North Slope, Alaska Suspended Wellbore Sketch (: Rig: S: I T: Nabors 14-E I R: GL: 120'AMSL I KB: 29 ft ~ BPV installed in Tubing Hanger 16", 65ppf, H-4O @ 105' Cmt to surf 20" Hole BI Permafrost @ 649' L2J SCSSV c/w 2.81 X-nip @ 1,500' (Closed) 12-1/4" Hole Injection Sub @ 3,000' J --- Side Pocket Mandrel @ TBA I Note: All depths are estimated in I measured depths from RKB - 3 1/2, 9.3 ppf, EUE 8rd-mod, L-80 tubing Projected TOC is 100' above FC Slumps @ 6,429' 8-1/2" Hole Side Pocket Mandrel @ +1- 8,151' Pressure Gauge Mandrels @ 8,275', 8,213' Baker 2.750 XN-nip @ 8,337' c/w PXN Plug and Eq Prng Promore Surface Read Out Pressure Guages @ 8,368' Baker 7x41/2 Lnr Hngr clw ZXP Packer and 10' PBR @ 8,399' 2 7/8" Seal Extension, flow sub, and GDAIWLEG 7" , 26ppf, L-80, BTC-mod @ +1- 8,551' 60' perfs @ +1- 8,626' - 8,686' (TCP- dropped) Dropped TCP perf gun 6-1/8" Hole - 4-1/2", 12.60ppf, L-80, IBT-mod, Liner @ 10,124' CONFIDENTIAL Anadarko Petroleum WEEKLY ACTMTY REPORT PERIOD: 04102102 thru 0418/02 OPERATIONS DETAIL Report Date: Tues 4/2/02: Drlg. ahead to TD @ 9,100' MD (9,014'TVD) MW 10.1ppg. Wed 4/3/02: Run MDT Log, MW 10.1 ppg. Thurs 4/4/02: Make wiper trip, prep for liner job, MW 10.1 ppg. Fri 4/5/02: Sat 4/6/02: Sun 4/7/02: Mon 4/8/02: 2 Start Date I Time 10-Mar..o222:oo {mmldcllyy hh:mm) Item No. Activity Starting Date and Time 130 Wed 19:00 131 Wed 19:00 132 Fri 19:00 133 Tue 19:00 134 Wed 7:00 135 Sun 7:00 136 Mon 7:00 Anadarko Petroleum Corporation WELL: Altamura No.1 TIME BREAKDOWN and LOOKAHEAD DRILLING Description of Activity 17-Apr If guns do not fire, pressure up wI N2 17 -Apr Flow well to separator to clean up, continue flowing 19-Apr Shut in for 4-day buildup 23-Apr Run static gradients & pull gauges 24-Apr Rig up hot oiler & reinject produced fluids down tbg 28-Apr Suspend wen 29-Apr Complete any remaining RDMO operations Date of Printing: 04/04/2002 11 :51 AM Page 4 of 4 An..d~ PefrdeuTI GorparaIion Est. Time [hrs] 0 48 96 12 96 24 0 Actual Time [hrs) End Date and Time 17-Apr-02 19:00 19-Apr-02 19:00 23-Apr-0219:oo 24-Apr-02 07:00 28-Apr-02 07:00 29-Apr-02 07:00 29-Apr-02 07:00 Days From Spud 37.9 39.9 43,9 44.4 48,4 49.4 49.4 EQUIPMENT, MATERIAL AND PERSONNEL MOVEMENTS Personnel Requirements Equipment and Material Requirements ~~"- Lookahead - AL T1_032402 RevQ6,xls Anadarko Petroleum Corporation Start Date I Time WELL: Altamura No.1 AnadarICP1 10-Mar..o2 22:00 TIME BREAKDOWN and LOOKAHEAD EQUIPMENT, MATERIAL AND PERSONNEL MOVEMENTS (mmlddlyy hh:mm) DRILLING Petrel eo.8T1 CorpcraIion Item Activity Starting Est. Actual End Date Days Equipment and Material No. Date and Time Descñption of Activity Time Time and Time From Personnel Requirements Requirements [hrs] [hrs] Spud 87 Thu 0:00 04-Apr POOH and LD Logging Tools 8 04-Apr-02 08:00 24.4 88 Thu 8:00 O4-Apr TIH w/6 1/8" BHA. 6 04-Apr-0214:oo 24.7 ...- 89 Thu 14:00 O4-Apr Circulate and Condition mud to run 4 1/2" csg. 2.5 04-Apr-02 16:30 24.8 90 Thu 16:30 O4-Apr POOH 6 O4-Apr-02 22:30 25.0 91 Thu 22:30 04-Apr RU and PU 4 1/2" liner and hanger assembly. 7 05-Apr-02 05:30 25.3 92 Fri 5:30 05-Apr TIH w/liner on DP. 8 05-Apr-02 13:30 25.6 93 Fri 13:30 05-Apr Condition and Condition mud to cement. 2 05-Apr-02 15:30 25.7 94 Fri 15:30 05-Apr Cement 4 1/2" liner and set liner hanger. 6 05-Apr-02 21:30 26.0 ......~ 95 Fri 21:30 05-Apr Set ZXP liner top packer and pull out of liner. 3 06-Apr-02 00:30 26.1 96 Sat 0:30 06-Apr Circulate out excess cement. 2 Q6-Apr-02 02:30 26.2 97 Sat 2:30 06-Apr POOH 5 Q6-Apr-02 07:30 26.4 98 Sat 7:30 06-Apr PU 41/2" liner clean-cut BHA. 8 06-Apr-02 15:30 26.7 99 Sat 15:30 06-Apr TIH to top of liner. 5 06-Apr-02 20:30 26.9 100 Sat 20:30 06-Apr Test top of liner to 4000 psi. 1.5 06-Apr-0222:oo 27.0 101 Sat 22:00 06-Apr Clean out 4 1/2" liner to PBTD. 3,5 07 -Apr -02 01:30 27.1 102 Sun 1:30 07-Apr Test liner to 4000 psi. 1,5 07 -Apr-02 03:00 27.2 103 Sun 3:00 07 -Apr Displace well in Inhibited packer fluid. 4 07-Apr-0207:oo 27.4 104 Sun 7:00 07-Apr POOH standing DP in derrick. 12 07-Apr-02 19:00 27.9 105 Sun 19:00 07-Apr Rig Up ELU 3 07-Apr-02 22:00 28.0 106 Sun 22:00 07-Apr Run GRlCCUUSIT 5 08-Apr-0203:oo 28.2 107 Mon 3:00 08-Apr Rig Down ELU 2 08-Apr-0205:oo 28.3 108 Mon 5:00 08-Apr MU Dummy seal assembly on 3-1/2" tbg 1 08-Apr-0206:oo 28.3 109 Mon 6:00 08-Apr TIH to just above PBR 12 08-Apr-02 18:00 28.8 110 Mon 18:00 08-Apr Circulate, Sting in, and Pressure Test Tbg & Uner 1 08-Apr-0219:OO 28,9 111 Man 19:00 O8-Apr TOOH Standing Back Tubing 5 09-Apr-02oo:oo 29.1 112 Tue 0:00 09-Apr LOOP 12 09-Apr-0212:oo 29,6 113 Tue 12:00 09-Apr MU Perf Guns, Spacer etc 4 09-Apr-02 16:00 29.7 114 Tue 16:00 O9-Apr MU Seal Assembly, 1 09-Apr-0217:oo 29.8 115 Tue 17:00 09-Apr MU Promore Gauges 1 09-Apr-0218:oo 29.8 116 Tue 18:00 09-Apr TIH with Tubing 14 10-Apr-0208:oo 30.4 117 Wed 8:00 10-Apr Locate PBR and space out for proper weight 1 10-Apr-0209:00 30.5 118 Wed 9:00 10-Apr Displace diesel and N2 down tubing & sting into PBR 3 10-Apr-0212:oo 30.6 119 Wed 12:00 10-Apr Test Annulus to 4000 psig 1 10-Apr-0213:oo 30.6 120 Wed 13:00 10-Apr Bleed N2 pressure off tubing and remove landing joint 1 1O-Apr-0214:oo 30.7 121 Wed 14:00 10-Apr Install BPV in tubing hanger 2 10-Apr-0216:oo 30.7 122 Wed 16:00 10-Apr ND BOPs and NU THA and tree 8 11-Apr-02 00:00 31.1 123 Thu 0:00 11-Apr Test wellhead equipment per procedure 4 11-Apr-0204:oo 31.2 124 Thu 4:00 11-Apr RD Derrick & Substructure to clear WH for Test Equip 48 13-Apr-0204:oo 33.2 +- 125 Sat 4:00 13-Apr RU & Press test remaining surface test equipment 96 17-Apr-0204:oo 37.2 126 Wed 4:00 17 -Apr Wait on Daylight 12 17-Apr-0216:oo 37.7 127 Wed 16:00 17 -Apr Conduct Pre Job Safety Meeting 1 17-Apr-0217:oo 37,8 128 Wed 17:00 17-Apr Rig up lubricator and load 10' firing bar 1 17-Apr-0218:oo 37.8 129 Wed 18:00 17-Apr Drop firing bar & monitor wenhead to insure gunfire 1 17-Apr-0219:00 37,9 Date of Printing: 04/04/2002 11 :51 AM Page 3 of 4 Lookahead - AL T1_032402 Rev06,xls Anadarko Petroleum Corporation Start Date I Time WELL: Altamura No.1 AnadArlCp8 10-Mar-02 22:00 TIME BREAKDOWN and lOOKAHEAD EQUIPMENT, MATERIAL AND PERSONNEL MOVEMENTS (mmJddIyy hh:mm) DRilLING Pelrcleo..on Caporation Item Activity Starting Est Actual End Date Days Equipment and Material No. Date and Time Description of Activity Time Time and Time From Personnel Requirements Requirements [hrsl [hrs] Spud 44 Tue 2:30 26-Mar POOH 8 4.0 26-Mar-0206:3O 15.4 45 Tue 6:30 26-Mar LD BHA & Download LWD 3 6.0 26-Mar-0212:3O 15.6 46 Tue 12:30 26-Mar Pull wear bushing. Install and test 7" rams in BOP's. 4 4,5 26-Mar-0217:oo 15.8 47 Tue 17:00 26-Mar RU to run 7" casing. 2 0.0 26-Mar-0217:oo 15.8 48 Tue 17:00 26-Mar RU & Run 7" casing to 8551'. 10 18.5 27-Mar-0211:3O 16,6 49 Wed 11:30 27-Mar Circulate and condition mud to cement, 3 3.0 27-Mar-0214:3O 16.7 50 Wed 14:30 27-Mar RU and Cement 7" casing. 4 2.0 27-Mar-0216:3O 16,8 51 Wed 16:30 27 -Mar RD and drain BOP stack. Back out 7" landing jt. 4 2.0 27-Mar-02 18:30 16,9 52 Wed 18:30 27-Mar InstaU 7" X 95/8" annular FMC pack-off and Test. 4 1,0 27-Mar-02 19:30 16.9 53 Wed 19:30 27-Mar Change out 7" rams for variables. Test BOP's. 6 14.5 28-Mar-0210:oo 17.5 +- 54 Thu 10:00 28-Mar RU Handling Tolls & Install Wear Bushing. 3 1.0 28-Mar-02 11:00 17.5 55 Thu 11:00 28-Mar PU 6-1/8" BHA & DP. 6 5.5 28-Mar-02 16:30 17.8 56 Thu 16:30 28-Mar TIH to top of cement @ 8531. 4 5.0 28-Mar-0221:3O 18.0 57 Thu 21:30 28-Mar CO Cmt., Displace Mud, & test r casing to 3500 psi. 1 5.5 29-Mar-0203:oo 18.2 58 Fri 3:00 29-Mar RU and Perform LOT on 7" X 9 5/S" annulus. 2 0.0 29-Mar-02 03:00 18,2 59 Fri 3:00 29-Mar Bullhead 2700 gals. Diesel in 7" X 9 518" annulus. 3 0.0 29-Mar-02 03:00 18.2 60 Fri 3:00 29-Mar Drill 7" shoe jts. and 20 ft. of formation. 3 6.5 29-Mar-0209:3O 18,5 61 Fri 9:30 29-Mar Circulate and condition mud. 1.5 0.5 29-Mar-02 10:00 18.5 62 Fri 10:00 29-Mar Perform FIT to 13.5 ppg eqv. 2 2.0 29-Mar-02 12:00 18.6 63 Fri 12:00 29-Mar Drill ahead to coring point @ 8545'. 6 1,0 29-Mar-0213:oo 18,6 64 Fri 13:00 29-Mar Circulate and condition mud. 2 1.0 29-Mar-02 14:00 18.7 65 Fri 14:00 29-Mar POOH for Coring Assembly. 7 5.0 29-Mar-0219:oo 18,9 66 Fri 19:00 29-Mar PU Coring Assembly. 5 2.0 29-Mar-02 21:00 19.0 67 Fri 21:00 29-Mar TIH wI Coring Assembly NO.1. 5 5.5 3O-Mar-0202:3O 19.2 68 Sat 2:30 3D-Mar Cut Core No.1 (8,545' - 8,605') 10 9.5 3O-Mar-02 12:00 19.6 69 Sat 12:00 3O-Mar POOH 1ST, C&C Mud 4 15.0 31-Mar-0203:oo 20.2 70 Sun 3:00 31-Mar LD Core No.1 and redress assembly. 2 3,5 31-Mar-0206:3O 20.4 71 Sun 6:30 31-Mar TIH wI Coring Assembly NO.2 (Service Rig) 5 8,0 31-Mar-0214:3O 20,7 72 Sun 14:30 31-Mar Cut Core No.2 (8,605' - 8,665') 10 1.0 31-Mar-0215:3O 20.7 73 Sun 15:30 31-Mar POOH (C&C) 4.5 8.5 01-Apr -02 00:00 21,1 74 Mon 0:00 01-Apr LD Core NO.2 and redress assembly. 2 1.5 01-Apr-02 01:30 21.1 75 Men 1:30 01-Apr TIH wI Coring Assembly No.3. 5 4.0 01-Apr-02 05:30 21.3 76 Men 5:30 01-Apr Cut Core NO.3 (8,665' - 8,725') 10 2,5 01-Apr-02 08:00 21.4 77 Men 8:00 01-Apr POOH 5 8.5 01-Apr-0216:30 21.8 78 Men 16:30 01-Apr LD Core No. 3 and coring assembly. 4 1,5 01-Apr-0218:00 21.8 79 Men 18:00 01-Apr MU 61/8" BHA wI MWDILWD (LWD FaHure). 1.5 8.5 02-Apr-0202:30 22.2 80 Tue 2:30 O2-Apr TIH. ReamlLog over Cored Interval. 6 7.0 02-Apr-02 09:30 22.5 81 Tue 9:30 O2-Apr Drill to TO to -10,124' MD (+1- 9,100' MD). 8 6.0 02-Apr-0215:30 22,7 82 Tue 15:30 02-Apr Short Trip into 7" casing shoe. TIH 3 3.0 O2-Apr-02 18:30 22.9 83 Tue 18:30 O2-Apr Circualte and condition mud. 2 1.0 02-Apr-D2 19:30 22,9 84 Tue 19:30 02-Apr POOH. Strap out, Download LWD Data & LD Tools. 8 10.0 03-Apr-0205:30 23,3 85 Wed 5:30 03-Apr MU MDT Logging Tools on DP 3 2.0 03-Apr-02 07:30 23.4 86 Wed 7:30 03-Apr TIH and log per Anadarko Geologist. 12 16.5 04-Apr-02 00:00 24,1 Date of Printing: 04/0412002 11 :51 AM Page 2 ef 4 Lookahead - AL T1_032402 Rev06,xls Anadarko Petroleum Corporation Start Date 1 Time WELL: Altamura No.1 An""'''''' 10.Mar-02 22:00 TIME BREAKDOWN and LOOKAHEAD EQUIPMENT, MATERIAL AND PERSONNEL MOVEMENTS (mmlddlyy hh:mm) DRILLING Pelrcleum Ca-pcration Item Activity Starting Est Actual End Date Days Equipment and Material No. Date and Time Description of Activtty Time Time and Time From Personnel Requirements Requirements [hrs] [hrs] Spud 1 Sun 22:00 1O-Mar Spud Well-10 March 2002. 0 0.0 10-Mar-0222:00 0.0 ToRíg From Rig To Rig From Rig 2 Sun 22:00 1O-Mar Drill from suñace to 2750'. 60 62,5 13-Mar-0212:30 2.6 3 Wed 12:30 13-Mar Circulate bottoms up. 1 1.0 13-Mar-0213:3O 2.6 4 Wed 13:30 13-Mar Make short trip to top of BHA. TIH 5 0,0 13-Mar-0213:3O 2.6 5 Wed 13:30 13-Mar Pumped and Back Reamed out of the hole. 0 9,5 13-Mar-0223:00 3,0 6 Wed 23:00 13-Mar LD BHA and downloaded MWD. 0 3,0 14-Mar-02 02:00 3,2 7 Thu 2:00 14-Mar PU new BHA 0 2,0 14-Mar-0204:oo 3,3 6 Thu 4:00 14-Mar TIH. Washed and Reamed tight spots. 0 12.0 14-Mar-0216:oo 3.8 9 Thu 16:00 14-Mar Made 10 std short trip. 0 2,5 14-Mar-02 16:30 3.9 10 Thu 18:30 14-Mar Circulate and condition mud to run casing. 2 3.0 14-Mar-0221:3O 4.0 11 Thu 21:30 14-Mar POOH and lD BHA 5 4.0 15-Mar-02 01:30 4.1 12 Fri 1:30 15-Mar RU to run 9 5/8" casing and make dummy run. 3 4,5 15-Mar-0206:oo 4.3 13 Fri 6:00 15-Mar Run 9 5/8" casing - 2746'. 6 6,0 15-Mar-0212:oo 4.6 14 Fri 12:00 15-Mar RU. Circulate and condition mud to cement. 2 4.0 15-Mar-02 16:00 4,7 15 Fri 16:00 15-Mar Cement 9 5/8" casing. 3 3.0 15-Mar-0219:oo 4.9 16 Fri 19:00 15-Mar RD. Drain and flush bell nipple, etc. 2.5 3.0 15-Mar-02 22:00 5.0 17 Fri 22:00 15-Mar Back out 95/8" casing. NO diverter and wellhead. 6 5,5 16-Mar-02 03:30 5.2 18 Sat 3:30 16-Mar NU weRhead on 9 5/8" casing. 5 2.0 16-Mar-02 05:30 5.3 19 Sat 5:30 16-Mar NU BOP's. 12 33.5 17-Mar-0215:oo 6.7 20 Sun 15:00 17-Mar Test BOP's per BlM and AOGCC requirements. 12 25.0 18-Mar-0216:oo 7.7 21 Mon 16:00 18-Mar PU & stand 189 Jts. 4" DP in derrick to drill 8 1/2" hole. 7 14.0 19-Mar-0206:oo 8,3 22 Tue 6:00 19-Mar Install wear bushing and PU 81/2" BHA. 6 7,0 19-Mar-0213:oo 8.6 23 Tue 13:00 19-Mar TIH to top of cement or float collar. 2 2,5 19-Mar-02 15:30 8.7 24 Tue 15:30 19-Mar RU and test 95/8" casing to 3000 psi. 1 2.0 19-Mar-02 17:30 8.8 25 Tue 17:30 19-Mar Drill 9 5/8" shoe and 20 ft. of formation. 3 1,5 19-Mar-02 19:00 8.9 26 Tue 19:00 19-Mar Circulate and condition mud. 1.5 1,0 19-Mar-022O:oo 8.9 27 Tue 20:00 19-Mar Perform FIT to 13.5 ppg eqv. 1.5 0,5 19-Mar-02 20:30 8.9 28 Tue 20:30 19-Mar Orin from 2750' to KOP at 3000'. 5.5 6.0 2O-Mar-02 02:30 9.2 29 Wed 2:30 2O-Mar Dml and porform diroctional work from 3000' to '1817'. 40 0.0 2D-Mar-02 02:30 9,2 30 Wed 2:30 20-Mar Peñorm Dir. Work & Drilled from 3000' to 4189'. (1189') 26.4 20,0 20-Mar-0222:3O 10.0 31 Wed 22:30 20-Mar Circulate bottoms up. 0 1.0 20-Mar-02 23:30 10.1 32 Wed 23:30 20-Mar Made short trip to casing shoe at 2746'. (-1500') 0 4.0 21-Mar-02 03:30 10.2 33 Thu 3:30 21-Mar Peñorm directional work from 4189' to 4900'. (711') 13.6 19.0 21-Mar-0222:3O 11.0 34 Thu 22:30 21-Mar Drill straight hole from '1900' to 8551'. 65 0.0 21-Mar-0222:3O 11.0 35 Thu 22:30 21-Mar Dnll straight hole from 4900' to 5948'. (1048') 17.5 17,5 22-Mar-02 16:00 11,7 36 Fri 16:00 22-Mar Circulate bottoms up. 0 1,0 22-Mar-0217:oo 11,8 37 Fri 17:00 22-Mar Made short trip to 4189'.18 stds. (-1760') 0 3,0 22-Mar-02 20:00 11,9 38 Fri 20:00 22-Mar Drill straight hole from 5948' to 8510'. (2562') 47,5 56.5 25-Mar-02 04:30 14.3 39 Mon 4:30 25-Mar Circulate bottoms up. 1 1.0 25-Mar-0205:3O 14.3 40 Mon 5:30 25-Mar Made 10 std short trip. 2.5 2.5 25-Mar-02 08:00 14.4 41 Mon 8:00 25-Mar Circulate around heavy sweep to clean hole. 1.5 4,0 25-Mar-0212:oo 14,6 - 42 Mon 12:00 25-Mar Short Trip into 9 5/8" casing shoe. TlH 9 12,0 26-Mar-02 00:00 15.1 43 Tue 0:00 26-Mar Circulate and condition mud to run casing. 2 2.5 26-Mar-02 02:30 152 Date of Printing: 04/0412002 11 :51 AM Page 1 of4 Lookahead - AL T1_032402 Rev06,xls APR 01 2002 12:27 FR APC ALASKA oil ( Alaska Oil and Gas conservatio( Attention: Tom Maunder . Fax (907)-276-7542 ,mmission GENERAL INFORMA TION~ 1. Property 2. Well Name & No.: 3. Prospect: 4. API No.: 5. Permit Number: 6. Ríg Floor: AA-081736 Altamura No.1 Wildcat 50-103-2043-00 202-010 29 ft CURRENT WELL SUMMARY INFORMATION: 13. 14. 15. MDfTVD: Mud Weight: last BOP Test Date: Test Pressures (p$i): Well Status (Drlg, Comp. WO, TAl PA): 16. 19075639479 TO 2767542 CONFIDENTIAL Anadarko Petroleum WEEKLY ACTIVITY REPORT PERIOD: 03/26/02 thru 4101/02 7. Designated Operator: 8. Rig Name: 9. Contact/Phone No.: 10. Spud Date 11. TD Date: 12. SUS.. COMP.. or ABN Date:' 8665/8579 10.0 3/28/02 5000 Coríng P.02/03 ( Bureau of L~nd Management Attention: Greg Noble Fax (907)..267,,1304 Anadarko Petroleum Corp. Nabors #14-E Tommy W. ThQmpson 1907<273~630? March 1 0, 2002 (22:00 hrs AST) NA NA" 17. Summary of Operations: Set 7"lntermediate csg @ 8501 test csg to 3500 psí, drill out, FIT to 13.5 ppgE. Coring @ 8665 16. Casing/Liner Summary . .. . Casiñg Details "1'6" 9..5/8" , i" Dt!p.!~ ,(MCtNt'j'j Test Pressure (psi) , 105 ' .. -- , 274i' .,,,,,-..- 8501ï8'415 cemèñtVôr~{šg~i.~~ Shoe Test (EMVY.) , , 3000 '.'3500 "'W_"- '" .~~:~":.~:.,.,,:'"'~~:.='~=''' .' "'''''''''''''''',v"''''."..,.,,,. 13.5 13.5 ~ '""""". "'-"-~ , .,~"" ._.n'., .~". ,,~".... "-"" "0'"'''",",''''' ,., ,. "'''~~. ''''''r''''' ".....~. 19. List all open-hole logs and surveys run (including MWD, velocity surveys and directional surveys): Date, spub 3/10/02 Log/SUlvey .. " GR, Rë'sJJ~en$ IPoros, Sonic ,- nterv~t (MD) Surface-8500 Indicate below if any of the following samples/surveys were taken: Rü'ñ"Number."'. ....."..:.w.!J,I, .. .""...,."......... 20. Velocity Surveys: Yes 23. Paleo Samples: Yes u 21. Conventional cores: Yes XXX 24. Litho samples: Yes 22. Sidewall cores: Yes 25. Geochern samples: Yes 1 APR 01 2002 12:27 FR APC ALASKA 19075639479 TO 2767542 P.03/03 ( ( CONFIDENTIAL Anadarko Petroleum WEEKLY ACTIVITY REPORT PERIOD; 03126102 thru 4/1/02 OPERATIONS DETAIL Report Date: Tues 3/26/02: 8510' MD. TD intermediate hole section. Wed 3127/02: Run 7" csg to 3280. Circulate @ 9 5/8 shoe. Thurs 3/28/02: Finish running 7" csg to 8501" MD. Cmt w/491 cuft class G+adds. Start testing BOP's. Fri 3/29/02: Finish Testing BOP's (effective test date 3/28/02). TIH. Displace hole w/10.2 ppg mud. Sat 3/30/02: Test Csg 3500 psig for 30 min OK. Prill out float eqpt. Displace w/9.S ppg mud sys. Drl 8510 - 8530. Ciro and condition mud. FIT test to 13.5 ppgE. Drl to core pt @ 8545. MW 9.7 ppg. Sun 3/31/02; Core 8545 - 8605. Increase MWto 10.0 ppg. Mon 4/1/02: Core 8605 - 8665. MW 10.0 ppg. 2 ** TOTAl.. PAGE. 03 ~K)j( Re: BOP test extension, Anadarko Petroleum, Altamura # 1 J, " ~: ( Subject: Re: BOP test extension, Anadarko Petroleum, Altamura # 1 Date: Mon, 25 Mar 2002 08:37:29 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Jim Rose <jim_rose@anadarko.COM> Jim, This is acceptable. Tom Maunder, PE AOGCC Jim Rose wrote: > Tom, > > Thanks for the reply. Just to confirm our plans, we are going to change > out the top ram in the stack to 7", run a test plug and do a shell test > which will verify the door seals, and then function test the rest of the > stack. > > We will do a full test prior to drilling out of 7". > > Thanks, > > jim > > > -----Original Message----- > > From: Tom Maunder [SMTP:tom_maunder@admin.state.ak.us] > > Sent: Friday, March 22,20026:42 PM > > To: Jim Rose > > Cc: AOGCC North Slope Office > > Subject: Re: BOP test extension, Anadarko Petroleum, Altamura # > > 1 » > > Jim, > > Your plan at TO is to come straight out to run pipe. All your logging > > will > > have been accomplished with L WO. Once on the bank, you will change > > the > > upper rams to 7", testing the same and run pipe. Looks like you will > > be > > accomplishing the test you need to do for the tubulars you will be > > running. Good luck with the operations. > > Tom Maunder, PE > > AOGCC » > > Jim Rose wrote: » > > > Tom, »> > > > Looking ahead, our next BOP test is due on the 25th. We should TO > > the > > > intermediate hole late on the 24th or early on the 25th. can we get > > an > > > extension from you that will allow us to run 7" and cement prior to 1. of 2 :;jQ"ð-Q \U 3/25/02 10:45 AM Re: BO~ test extension, Anadarko Petroleum, Altamura # 1 (f > > the > > > BOP test? »> > > > Thanks, »> > > > jim « File: Card for Tom Maunder » We will then test prior to drill out of 7". Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 20f2 3/25/02 10:45 AM Notification of Spud (Altamura ...nadarko Petroleum Corpora tion) ( (' Subject: Notification of Spud (Altamura No.1 - Anadarko Petroleum Corpora tion) Date: Mon, 11 Mar 2002 11 :36:44 -0600 From: Tommy Thompson <tommy_thompson@anadarko.COM> To: IIIGreg Noblelll <gre9_noble@ak.blm.gov>, "Tom Maunder'" <tom_maunder@admin.state.ak.us>, IIIWinton Aubert"' <winton_aubert@admin.state.ak.us> CC: Joe Cox <jxc006@DOMESTIC.EXCH.ANADARKO.com>, Jim Rose <j8k352@DOMESTIC.EXCH.anadarko.com>, Bob Elder <yom923@DOMESTIC.EXCH.ANADARKO.com> Gentlemen, As a follow-up to verbal notifications made to your field representatives, please be advised that Anadarko Petroleum Corporation commenced drilling operations on the Altamura No.1 at 22:00 hrs (AST) March 10, 2002. Thanks, Tommy W. Thompson International & Alaska Drilling Direct: 907-273-6302 Mobile: 907-301-7516 Fax: 907-563-9479 1 of 1 dOd--O\O 3/12/02 8:28 AM Please Pass to BLM Inspector (' ~ Subject: Please Pass to BlM Inspector Date: Thu, 07 Mar 2002 17:22:28 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: 18E- Company Man <N18ecm@ppco.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.ak.us>, Lonny Bagley <Ibagley@ak.blm.gov> dÜé1--0 ~ 0 Lonny, Good to talk to you. This note confirms our discussion regarding the upcoming diverter test at Anadarko's Altamura #1. Yes, please have Bo witness the function test. I have asked the PPCo Company Man to provide a disk copy of the AOGCC diverter and BOP test forms. We would appreciate receiving copies of the test report. Please call if there are any questions. Also, I would appreciate if we could get the Anadarko phone numbers. Tom Maunder, PE AOGCC Tom Maunder <tommaunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 3/7/02 6:46 PM Request Release of AOGCC Permit Data { Subject: Request Release of AOGCC Permit Data Date: Tue, 5 Mar 2002 17:43:54 -0600 From: Tommy Hutto <tommy_hutto@anadarko.COM> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, Per our phone conversation, please release Anadarko's Altamura NO.1 permit package to Mr. Bill Penrose (Fairweather). Bill is currently working under our direction. Thanks, Tommy Thompson 1 of 1 3/5/02 2:43 PM ~~~~E { : f!Æ~!Æ~~~!Æ TONY KNOWLES, GOVERNOR A.T~A.SIiA. OIL AlÐ) GAS CONSERVATION COMMISSION Tommy Thompson Drilling Superintendent Anadarko Petroleum Corporation 3201 C Street Ste 603 Anchorage AK 99503 333 w. ¡TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Altamura #1 Anadarko Petroleum Corporation Permit No: Revised 202-0 I 0 Sur.Loc.331'FSL,2258'Fvv.L,Sec.30,T9N,R2E,~ Btmho1e Loc. 150' FNL, 2423' Fvv.L, Sec. 31, T9N, R2E, ~ Dear Mr. Thompson: Enclosed is the approved application for pennit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations unt11 all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Ú ~"~ C~ChSli Taylor Chair BY ORDER OF THE COMM:ISSION DATED this 5th day of March, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA QIL AND GAS CONSERVATION COMMISSION ( PERMIT TO DRILL ( 20 MC 25.005 [ ] Service [ ] Development Gas [ ] Single Zone [X] Exploratory [ ] Stratigraphic Test [ ] Development Oil 5. Datum Elevation (DF or KB) 10. Field and Pool 29' RKB 6. Property Designation M-081736 7. Unit or Property Name Altamura 8. Well Number #1 9. Approximate spud date 3/1/02 14. Number of acres in property 15. Proposed depth (MD and TVD) 5,744 1 0,095'MD/1 0,003' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 25 deg M8)åmum surface 3,481 psig, At total depth (TVD) Setting Depth Top Bottom MD TVD MD TVD 29' 29' 80' , ~ 80' 237 sx AS1 29' 29' ~ 3000' Stage 1 : 340 sx G, Stage 2: 324 sx AS3 29' 29' 8,551' 8459' 421 sx G 8370' 8278' 1-0095' '1-GGæ' 118 sx G [O,2tj-' ,OO~ZI Wiifr 1 a. Type of work [X] Drill [] Redrill 11 b. Type of well [ ] Re-Entry [ ] Deepen 2. Name of Operator Anadarko Petroleum Corporation 3. Address 3201 C Street, Ste. 603, Anchorage, Alaska 99503 4. Location of well at surface 331' FSL, 2258' FWL, Sec. 30, T9N, R2E, UM At top of productive interval 150' FNL, 2423' FWL, Sec. 31, T9N, R2E, UM At total depth 150' FNL, 2423' FWL, Sec. 31, T9N, R2E, UM 12. Distance to nearest property line 113. Distance to nearest well 2,258' E. of lease line 4.7 miles S. of Rendezvous #2 16. To be completed for deviated wells Kick Off Depth: 3,000' 18. Casing Program Size Casing 16" 9-5/8" [X] Filing Fee [X] Property Plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling Program [X] Drilling Fluid Program [X] Time vs Depth Plot [ ] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Contact Engineer Name/Number: Jim Rose 273-6304 Prepared By Name/Number: Bill Penrose 258-3446 21. I herebcsrtifY that the f re oing is t~nd correct to the best of my knowledge Signed . ~ .~~" '~ð ~ Title Drilling Superintendent Date -:3/Q \ 'e}..; Commission Use Only Permit Number IAPI Number :;2.02.. - ð I 0 SL) ~ /D 3 ~- 2-D V63 -()D Conditions of Approval: Samples Required: ,þ1:Yes [] No Hydrogen Sulfide Measures: Dc] Yes [] No Required Working Pressure for BOPE: [] 2M, [] 3M, [] 5M, Other: SCÖÖ~~\ \3(:)?~~3t 0ngmal Signed By t.r Cammy Oechslj Taylor Commissioner Maximum Hole Angle: Hole 20" 12-114" 8-112" 6-1/8" Weight 65# 40# 26# 12.6# Specifications Grade Coupling H-40 NIA L-80 BTC L-80 BTC-Mod L-80 IBT-mod 7" 4-1/2" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: feet feet feet feet measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Approved By Form 10-401 Rev. 12-01-85 VJ6Æ- šiWo&.i- tB-?tv¡ '3, 4-C)"). [ ] Multiple Zone Wildcat 11. Type Bond (See 20 AAC 25.025) Blanket JX-8726 Number Amount $200,000 4,581 psig Length 51' 2971' 8522' 1725' Quantity of Cement (include stage data) Plugs (measured) Junk (measured) Size Cemented MD TVD RECEIVED MAR 0 1 2002 Alaska Oil & Gas Cons. CommiSSion Anchorage ~rr~v. I Date I See cover letter :1 J )' ~ ;).... for other requirements ud log Required .MYes [ ] No Directional Survey Req'd f>c1"Yes [ ] No [ ] 1 OM, [] 15M . by order of the commission Date ß/ (/ tJ r Submit Ih Triplicate ORIGINAL ~ ( f\. \~G.~~~ ~'J.. dOd--Q\ G Subject: Date: Mon, 4 Mar 2002 18:23:08 -0600 From: Walter Quigley <walter_quigley@anadarko.COM> To: '"tom_maunder@admin.state.ak.us'" <tom_maunder@admin.state.ak.us>, IIISteve Teller'" <steller@lynxalaska.com>, Bob Elder <yom923@DOMESTIC.EXCH.ANADARKO.com>, Bret Allard <x8c692@DOMESTIC.EXCH.ANADARKO.com>, Derry Thompson <d8q026@DOMESTIC.EXCH.ANADARKO.com>, Gary Goerlich <nBe940@DOMESTIC.EXCH.ANADARKO.com>, Mike Whiteley <v8j134@DOMESTIC.EXCH.ANADARKO.com> Steve Teller <c8b444@DOMESTIC.EXCH.anadarko.com>, Tommy Hutto <18t233@DOMESTIC.EXCH.ANADARKO.com>, Tommy Thompson <txtmid@DOMESTIC.EXCH.ANADARKO.com> Tom: Thank you so much for your direction today, you were a great help. This afternoon I asked about the ability to use dirty snow that was 99% snow & 1°k traces of Motor oil, Hydraulic oil, Diesel, Exhaust, & Glycol, for beneficial use in the rig make up water on a Good Faith, Best Efforts standard. I just need a confirmation from you on what we spoke about. Thank you once again for you time & help. Sincerely Walter J Quigley JR 1 of 1 3/4/02 3:49 PIV STATE OF ALASKA ALASKA QIL AND GAS CONSERVATION COMMISSION ( PERMIT TO DRILL .( 20 MC 25.005 [ ] Service [ ] Development Gas [ ] Single Zone [X] Exploratory [ ] Stratigraphic Test [ ] Development Oil 5. Datum Elevation (DF or KB) 10. Field and Pool 29' RKB 6. Property Designation M-081736 7. Unit or Property Name Altamura 8. Well Number #1 9. Approximate spud date 3/1/02 14. Number of acres in property 15. Pr depth (MD and lVD) 5,744 /0 ~1~1VD/MD If) /':bð' 17. Anticipated pressure {see 20 C 25.035 (e) (2)} f 'þj 25 deg Ma>åmum surface 3,481 psig At total depth (TVD) 4,581 psig Setting Depth Top Bottom MD TVD MD TVD 29' 29' 80' 80' 29' 29' 3000' 3000' 29' 29' 8430' 8430' 8278' 8278' 10003' 10003' 1 a. Type of work [X] Drill [] Redrill 11 b. Type of well [ ] Re-Entry [ ] Deepen 2. Name of Operator Anadarko Petroleum Corporation 3. Address 3201 C Street, Ste. 603, Anchorage, Alaska 99503 4. Location of well at surface 331' FSL, 2258' FWL, Sec. 30, T9N, R2E, UM At top of productive interval 150' FNL, 2423' FWL, Sec. 31, T9N, R2E, UM At total depth 150' FNL, 2423' FWL, Sec. 31, T9N, R2E, UM 12. Distance to nearest property line 113. Distance to nearest well 2,258' E. of lease line 4.7 miles S. of Rendezvous #2 16. To be completed for deviated wells Kick Off Depth: 3,000' 18. Casing Program Size Hole Casing 20" 16" 12-1/4" 9-518" 8-112" 7" 6-1/8" 4-1/2" Size /1' ....~~rf ~ !f~ cJ: / / l / I measured ;/ true vertical j/' . 20. Attachments [X] F, iling Fee ~. [X] Property Plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling Program [X] Drilling Fluid Progr [X] Time vs Depth Plot [ ] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Contact Engineer Name/Number: Ji ose 273-6304 Prepared By Name/Number: Bill Penrose 258-3446 21. I ~erebY0Z, rtify that the fOregOi,ng i,S ue and correct to the best of my knowledge Signed fUL t \t- ~ I I . ,,'r,1M.¡tu,J Title Drilling Superintendent Date .vI ß O-z... , Commission Use Only Permit NUmb~A.~ \0 AAPI]Jumber 0 3- ,'"") A" t I^ ~ -DO I /AoJ6roval Date,-... I See cover lett.er UU\- 0 / I 5"D .... I ~ ""'u ..::.¡.. . for other requirements Conditions 0 pproval: I Samples Required: ,.&>4 Yes [] No '-.J I Mud Log Required ~s [ ] No I" Hydrogen Sulfide Measures: þ('ves [] No Directional Survey Req'd XYes [ ] No / Required Working Pressure for BOPE: [ ] 2M, [] 3M, [] 5M, [] 10M, [] 15M Other: jL by order of Approved By Commissioner 'the commission Form 10-40 Rev. 12-01-85 ORIGINAL Maximum Hole Angle: Weight 65# 40# 26# 12.6# Specifications Grade Coupling H-40 NIA L-80 BTC L-80 BTC-Mod L-80 IBT-mod 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: n 1 'f\e." (Ò( (\ [ ] Multiple Zone 20 AAC 25.025) Number $200,000 Length 51' 2971' 8401' 1725' Quantity of Cement (include stage data) 23~S S1 Sta 1: 340 sx G, Stage 2: 324 sx AS3 4 sxG 18 sx G Plugs (measured) Junk (measured) Cemented MD TVD RECEIVED FES 1 5 2007. Alaska Oil & Gas Coos. Commission Anchorage I ,. ¡....- Datí '- )/C , Subm.í. ;;ï i ï¡¡JIIl,;äl~ ') ') ') ~1~::~~~:çJ~f:1,~1,~}~N, ::" ',~~j~',~~,(/i!~,' %", r'J " A ~~,~~~:!Y ~ ","" ''',:i'~'c, )t'~;(~iV~:1' .\'~, ~~~".~-,,~-~J'" ¿~~ ,.~. r, ,,'I' '~, - t;","'r:l'I';r-"'~""~~ð'~-'-:-'~,1,~,""'~" ,"~"~"~~"-'"''----''-~''' .l",~" ~-"'"..-L.¡""",-,---".,,,,,,,,,,,,-,,-+,,,--.;I..''',''~, "'''.'.'' '''''''''','---t',¡'Y'-''''''''''''':¡¡I'<''''''''''--''''''-',''''''','';¡;¡, ""----'-~"""''''f-'',j"~,,,-~-,,-,---~,'-<-'4lJh(j, 4 4"i"" ~)3"..,If%-,,, , ~ " æ ~ (1.~.\" >"~' ~ '~f;t ...' ~,~;ff(0;" 'jl ' Ä~'~ ,,4. a- ,*",,,,",,i L, " 1;1 VW(\¡¡)¡'¡ç. ,*,"~i"!:¡,' (. I "'~: .,~ '( . .'(~,.C i~;¡¡. . .' 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"',,' '."'-"'''-, '-t..."",'"',',,,' ,..9.- ''''. , .~'\ . "liIt",~ ~f ~\!~lG?f~ ' ,-..'" '~'''''''' \' ....",/" /~'<>" ~,¿7t .~"~ ~~:;t?~ r~ ~ :\f;: ":~;;¡¡;Ë1:!.. .', /:' . ", I'" " ""- 0 . '" ." ;.....£;¡ '" ~-'"'r''' '\ -, -. 1.,..' ,. .!.~. , " ;"., .-. hY' >;; '~~ . ~'" ~ \'r! ¡¡;'." 1. ~'f~' L.:_,-,~' l:"!~ '¡ ,¡~1~ ,;: ", ", ':' \ ') ,>..::'~ I, 0 ~.~~ ,.Yi" 00 . » '\;¡ /\ '''-'\ -'I ~'$~~l"ë 'i;»ñ ~'! t{) --~ '"'-" - . -~, " So'fB, .. 1': " ' ~''''-.ci!¡r ,J>'"-'..~. ._,X"".." , ---j~~......ffc,.--- . OCþ.an..-.4L--.-----¡f-_.- ,.--.~. ~ fi" '-"'- ',h ~ r J ~ ... . ~ ~,:~'''¿~~'¡l ~ ',;")~'.'~\1~,i.If:=~~~T\ ., ',~..", )" ~ ,/I,',d. r l~, ~j~di'~,<~:-~~'rá~~; ".i~:C~~~ ';~>1j§(~:"~~<~ "l~g:~~ . .' -4\\ ,r """'\' .__.~~'" -, '---f:1-___,....l~r"\--.t-.. ..,'~ -ifI3H1- ,.......,.--,..'f~-,,-"" '''''''<:7''' '. . . ~ , ,. <. '~ ""/'~;,! ,'i.. : ~;': ,~,. ,:' ~,. ,~L!' . "., rY\~ /, ',', ::D 7t 0 i ~~:~5t¡ ,~{';~''¿1'Ú1: ~/(\/:~~;:;:::i.'~;;p>:~<(,:~..;,;{{¡.~ ~~ A <:.[" ,..' ) . J~;- ,:'., ,~ ) ~.~~ .~-i ...,"( ¡ --- L"l-' ¡ ¡ \ .,'" , ' " ..r1, ¡/' -,"-:" -... L 2 I 1 >, ('" C!i7:r.7J;71 ') Lease Boundaries ~ ~ '" '" '" '\ r::-::.. -:: -:¡ National Petroleum Resérve.. Alaska r////;:1 I~~:~~~~~~~~~~~I Proposed Water Source Lakes Previously Permitted Lakes Fish Bearing Lake ...... ~¡¡¡->!ÌifNlí(rIi!'M Proposed Ice Road Previously Permitted Ice Roads -------. . -1- Proposed Rolligon Route Previously Permitted Exploration Wells Proposed Exploration Well Horizontal Datum NAD27, coordinate system UTM Zone 5, Vertical Datum NGVD29. Hydrology derived from 1 :63360 USGS DLG Data. Anadarlep2 ~~hO.(1UI" CI...'fpQhJf!Of1 AL TAMURA PROSPECTS, LEASES, PROPOSED WATER SOURCES, AND ACCESS SCALE: 1 inch equals 2 miles FIGURE: 2 Lynx: apc127,mxd, December 10, 2001, Rev 7 Sperrj~Sun Drilling Serl.,'ces Proposal Data - Altamura 1 (South) - Altamura 1 WP04 12 February, 2002 - 13:49 -1- Dri/IQuest Sperry-Sun Drilling Services . Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Anadarko Alaska Sperry-Sun Drilling Altam ura Measured Sub-Sea Vertical Local Coordinates Global Coordinates Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -149.00 0.00 O.OON 0.00 100.00 0.000 0.000 -49.00 100.00 0.00 N 0.000 0.00 200.00 0.000 0.000 51.00 200.00 0.00 N 0.000 0.00 300.00 0.000 0.000 151.00 300.00 O.OON 0.000 0.00 400.00 0.000 0.000 251.00 400.00 O.OON 0.000 0.00 500.00 0.000 0.000 351.00 500.00 8899.10 N 284418.40 E 0.000 0.00 600.00 0.000 0.000 451.00 600.00 5888899.10 N 284418.40 E 0.000 0.00 649.00 0.000 0.000 500.00 649.00 5888899.10 N 284418.40 E 0.000 0.00 Base Permafrost 700.00 0.000 0.000 551.00 700.00 5888899.10 N 284418.40 E 0.000 0.00 800.00 0.000 0.000 651.00 800.00 5888899.10 N 284418.40 E 0.000 0.00 900.00 0.000 0.000 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1000.00 0.000 0.000 O.OOE 5888899.10 N 284418.40 E 0.000 0.00 1100.00 0.000 0.000 O.OOE 5888899.10 N 284418.40 E 0.000 0.00 1200.00 0.000 0.000 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1300.00 0.000 0.000 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1400.00 0.000 0.000 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1500.00 0.000 0.000 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1600.00 0.000 0.000 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1700.00 0.000 0.000 O.OON 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1800.00 0.000 0.000 O.OON 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1900.00 0.000 0.000 1751.00 1900.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2000.00 0.000 0.000 1851.00 2000.00 O.OON 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 ~~ 2100.00 0.000 0.000 1951.00 2100.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2200.00 0.000 0.000 2051.00 2200.00 O.OON 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2300.00 0.000 0.000 2151.00 2300.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2400.00 0.000 0.000 2251.00 2400.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2500.00 0.000 0.000 2351.00 2500.00 O.OON 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2600.00 0.000 0.000 2451.00 2600.00 O.OON 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2700.00 0.000 0.000 2551.00 2700.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2750.00 0.000 0.000 2601.00 2750.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 9 5/8" Casing ---------. 12 February, 2002 -13:49 Page 1 of7 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for Altamura 1 (South) - Aftamura 1 WP04 Revised: 12 February. 2002 Anadarko Alaska Sperry-Sun Drilling Altamura Measured Sub-Sea Vertical Local Coordinates Global Coordinates Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 2800.00 0.000 0.000 2651.00 2800.00 0.00 N 0.000 0.00 2899.00 0.000 0.000 2750.00 2899.00 O.OON 0.000 0.00 K3 Marker 2900.00 0.000 0.000 2751.00 2900.00 0.00 N 0.000 0.00 3000.00 0.000 0.000 2851.00 3000.00 O.OON 0.000 0.00 Begin Dir @ 4.000o/100ft: 3000.00ft MD, 3000.00ft TVD ~"'"' 3100.00 4.000 161.115 2950.92 3099.92 3.30 S 284419.44 E 4.000 3.49 3200.00 8.000 161.115 3050.35 3199.35 5888885.79 N 284422.54 E 4.000 13.94 3300.00 12.000 161.115 3148.81 3297.81 5888869.21 N 284427.69 E 4.000 31.30 3400.00 16.000 161.115 3245.82 3394.82 5888846.11 N 284434.86 E 4.000 55.49 3500.00 20.000 161.115 3340.91 3489.91 5888816.61 N 284444.03 E 4.000 86.38 3600.00 24.000 161.115 3433.61 3582.61 5888780.84 N 284455.14 E 4.000 123.84 3625.14 25.006 161.115 3456.48 43.46 E 5888770.88 N 284458.23 E 4.000 134.26 End Dirt Start Sail @ 25.006° : 3625.14ftMD ,3605.48ftTVD 3700.00 25.006 161.115 156.98 S 53.70 E 5888740.66 N 284467.62 E 0.000 165.91 3800.00 25.006 161.115 196.97 S 67.38 E 5888700.30 N 284480.16 E 0.000 208.18 3900.00 25.006 161.115 236.97 S 81.06 E 5888659.93 N 284492.70 E 0.000 250.45 4000.00 25.006 161.115 276.96 S 94.74 E 5888619.56 N 284505.24 E 0.000 292.72 4048.32 25.006 161.115 3989.00 296.29 S 101.35 E 5888600.05 N 284511.31 E 0.000 313.15 Base Brookian Sands 4100.00 25.006 161.115 4035.83 316.96 S 108.42 E 5888579.19 N 284517.79 E 0.000 334.99 4192.34 25.006 161.115 4119.52 353.89 S 121.06 E 5888541.92 N 284529.37 E 0.000 374.02 Begin Dir @ 4.0000/100ft: 4192.34ft MD, 4119.52ftTVD 4200.00 24.699 161.115 3977.47 4126.47 356.94 S 122.10 E 5888538.84 N 284530.32 E 4.000 377.24 4300.00 20.699 161.115 4069.70 4218.70 393.44 S 134.59 E 5888502.00 N 284541.77 E 4.000 415.82 .....,0-, 4400.00 16.699 161.115 4164.41 4313.41 423.77 S 144.96 E 5888471.39 N 284551.28 E 4.000 447.88 4500.00 12.699 161.115 4261.11 4410.11 447.77 S 153.17 E 5888447.16 N 284558.80 E 4.000 473.25 4600.00 8.699 161.115 4359.36 4508.36 465.33 S 159.18 E 5888429.44 N 284564.31 E 4.000 491.81 4700.00 4.699 161.115 4458.65 4607.65 476.37 S 162.95 E 5888418.30 N 284567.77 E 4.000 503.4 7 . 4800.00 0.699 161.115 4558.52 4707.52 480.82 S 164.48 E 5888413.80 N 284569.17 E 4.000 508.18 4817.48 0.000 0.000 4576.00 4725.00 480.93 S 164.51 E 5888413.70 N 284569.20 E 4.000 508.29 End Dir, Start Sail @ 0.000° : 4817 .48ftMD,4725.00ftTVD 4900.00 0.000 0.000 4658.52 4807.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 5000.00 0.000 0.000 4758.52 4907.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 5100.00 0.000 0.000 4858.52 5007.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 5200.00 0.000 0.000 4958.52 5107.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 12 February. 2002 - 13:49 Page 20f7 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Anadarko Alaska Sperry-Sun Drilling Altamura Measured Sub-Sea Vertical Local Coordinates Global Coordinates ogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin ate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) OOft) 5300.00 0.000 0.000 5058.52 5207.52 480.93 S 0.000 508.29 5400.00 0.000 0.000 5158.52 5307.52 480.93 S 0.000 508.29 5500.00 0.000 0.000 5258.52 5407.52 480.93 S 0.000 508.29 5600.00 0.000 0.000 5358.52 5507.52 480.93 S 0.000 508.29 5700.00 0.000 0.000 5458.52 5607.52 480.93 S 0.000 508.29 r-~ 5800.00 0.000 0.000 5558.52 5707.52 8413.70 N 284569.20 E 0.000 508.29 5900.00 0.000 0.000 5658.52 5807.52 - 5888413.70 N 284569.20 E 0.000 508.29 6000.00 0.000 0.000 5758.52 5907.52 5888413.70 N 284569.20 E 0.000 508.29 6100.00 0.000 0.000 5858.52 6007.52 5888413.70 N 284569.20 E 0.000 508.29 6200.00 0.000 0.000 5958.52 6107.52 5888413.70 N 284569.20 E 0.000 508.29 6300.00 0.000 0.000 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 6400.00 0.000 0.000 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 6500.00 0.000 0.000 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 6529.48 0.000 0.000 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 TI F.C. Slumps 6600.00 0.000 0.000 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 6700.00 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 6800.00 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 6900.00 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7000.00 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7100.00 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7200.00 0.000 0.000 6958.52 7107.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7300.00 0.000 0.000 7058.52 7207.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7400.00 0.000 0.000 7158.52 7307.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7434.48 0.000 0.000 7193.00 7342.00 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 BI F.C. Slumps 7500.00 0.000 0.000 7258.52 7407.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7532.48 0.000 0.000 7291.00 7440.00 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 TI HRZ 7600.00 0.000 0.000 7358.52 7507.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 7607.48 0.000 0.000 7366.00 7515.00 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 Base H RZ 7641.48 0.000 0.000 7400.00 7549.00 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 K-1 7700.00 0.000 0.000 7458.52 7607.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 12 February, 2002 -13:49 Page 30f7 Dri//Quest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Anadarko Alaska Sperry-Sun Drilling Altamura Measured Sub-Sea Vertical Local Coordinates Global Coordinates ogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin ate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 000) 7800.00 0.000 0.000 7558.52 7707.52 480.93 S 0.000 508.29 7808.48 0.000 0.000 7567.00 7716.00 480.93 S 0.000 508.29 LCU 7900.00 0.000 0.000 7658.52 7807.52 480.93 S 0.000 508.29 8000.00 0.000 0.000 7758.52 7907.52 480.93 S 0.000 508.29 8100.00 0.000 0.000 7858.52 8007.52 480.93 S 0.000 508.29 8200.00 0.000 0.000 7958.52 8107.52 8413.70 N 284569.20 E 0.000 508.29 8300.00 0.000 0.000 8058.52 8207.52 5888413.70 N 284569.20 E 0.000 508.29 8400.00 0.000 0.000 8158.52 8307.52 5888413.70 N 284569.20 E 0.000 508.29 8500.00 0.000 0.000 8258.52 8407.52 5888413.70 N 284569.20 E 0.000 508.29 8551.48 0.000 0.000 8310.00 8459.00 5888413.70 N 284569.20 E 0.000 508.29 7" Casing 8600.00 0.000 0.000 8358.52 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 8601.48 0.000 0.000 8360.00 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 TI Upper Jurassic Target - Altamura 1, 200.00 Radius., Drillers 8700.00 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 8700.48 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 UJU 8774.48 0.000 0.000 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 TI Nuiqsut "A" 8800.00 0.000 0.000 8707.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 8900.00 0.000 0.000 8807.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9000.00 0.000 0.000 8907.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9100.00 0.000 0.000 9007.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9200.00 0.000 0.000 9107.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9300.00 0.000 0.000 9058.52 9207.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9400.00 0.000 0.000 9158.52 9307.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9500.00 0.000 0.000 9258.52 9407.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9600.00 0.000 0.000 9358.52 9507.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9700.00 0.000 0.000 9458.52 9607.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9800.00 0.000 0.000 9558.52 9707.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9900.00 0.000 0.000 9658.52 9807.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 9924.48 0.000 0.000 9683.00 9832.00 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 TI J-3 10000.00 0.000 0.000 9758.52 9907.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 10100.00 0.000 0.000 9858.52 10007.52 480.93 S 164.51 E 5888413.70 N 284569.20 E 0.000 508.29 12 February, 2002 - 13:49 Page 4 of7 Dri/lQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Aitamura 1 (South) . Altamura 1 WP04 Revised: 12 February, 2002 Sperry-Sun Drilling Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin (ft) (ft) (ft) (ft) (ft) (ft) 10124.48 0.000 0.000 9883.00 10032.00 480.93 S 164.51 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 161.115° (True). Based upon Minimum Curvature type calculations, at a Measured Dept' The Bottom Hole Displacement is 508.29ft., in the Direction of 161. Comments Measured Depth (ft) 3000.00 3625.14 4192.34 4817.48 10124.48 12 February, 2002 -13:49 Stat TVD (ft) 3000.00 3605.48 4119.52 4725.00 10032.00 Comment O.OOE 43.46 E 121.06 E 164.51 E 164.51 E Begin Dir @ 4.000°/1 OOft : 3000.00ft MD, 3000.00ft TVD End Dir, Start Sail @ 25.006° : 3625.14ftMD,3605.48ftTVD Begin Dir @ 4.0000/1 0 Oft : 4192.34ft MD, 4119.52ftTVD End Dir, Start Sail @ 0.0000: 4817.48ftMD,4725.00ftTVD Total Depth: 10124.48ftMD,10032.00ftTVD Page 5 0'7 ogleg ate 0 Oft} 0.000 . Anadarko Alaska Altamura Vertical Section Comment 508.29 Total Depth: 1 0124.48ftMD,1 0032.00ftTVD 4 1/2" Liner -------,_.~- Dri//Quest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 . Anadarko Alaska Altamura Sperry-Sun Drilling Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Northings (ft) Formation Tops 500.00 0.000 0.000 649.00 649.00 500.00 2750.00 0.000 0.000 2899.00 2899.00 2750.00 3840.00 0.000 0.000 4048.32 3989.00 3840.00 6288.00 0.000 0.000 6529.48 6437.00 6288.00 7193.00 0.000 0.000 7434.48 7342.00 7193.00 7291.00 0.000 0.000 7366.00 0.000 0.000 7400.00 0.000 0.000 7567.00 0.000 0.000 8360.00 0.000 0.000 8459.00 0.000 480.93 S 8533.00 0.000 480.93 S 9683.00 0.000 480.93 S Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth Casing Detail (ft) (ft) (ft) (ft) <Surface> <Surface> 2750.00 2750.00 9 5/8" Casing <Surface> <Surface> 8551.48 8459.00 7" Casing <Surface> <Surface> 10124.48 10032.00 4 1/2" Liner ase Permafrost K3 Marker Base Brookian Sands TI F.C. Slumps BI F.C. Slumps 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E T/HRZ Base HRZ K-1 LCU TI Upper Jurassic 164.51 E UJU 164.51 E TI Nuiqsut "A" 164.51 E TI J-3 ~-, 12 February, 2002 -13:49 Page 60f7 DrillQuest 2.00.09.006 Sperry-Sun Drilling Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Targets associated with this well path Target Name Altamura 1 12 February, 2002 - 13:49 Mean Sea Level/Global Coordina, Geographical C T O.OOft Page 70f7 480.93 S 164.51 E 5888413.70 N 284569.20 E 70005' 52.8360" N 151043' 40.6489" W . Anadarko Alaska Altamura Target Target Shape Type Circle Drillers ~... ~=- Dri/lQuest 2.00.09.006 ANADARKO PETROLEUM CORPORATI( 32(' MAIN 907/273-6300 ;TREET. SUITE 603. ANCHORAGE, ALASKA 99503 Anadarl(p! February 14, 2002 ~ J;Ô lo-tf) I ~. :>/I/b~ Ms. Cammy Oechsli- Taylor, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval: Anadarko Altamura #1 Dear Ms. Oechsli- Taylor: Anadarko Petroleum Corporation hereby applies for Sundry Approval to change the proposed bottomhole location of the previously approved Altamura # 1 exploratory well located in the NPRA area of the North Slope. Alta1llura # 1 was originally planned and approved as a straight hole. However, recent re- examination of geological data results in an optimized bottomhole location 508' southeast of the surface location. Enclosed find an Application for Sundry Approval and the proposed directional program for this well. The planned spud date is approxÏ1llately March 8, 2002. The AOGCC is requested to keep confidential all information included in the Application for Sundry Approval as information in these dOCUlllents is drawn from research and data proprietary to Anadarko. F or your information, this sundry approval request is being simultaneously submitted to the U.S. Bureau of Land Management. If you have any questions or require additional information, please contact me at (907) 273-6300. Sincerely, ¿~0~~~ Tommy Thomp~ Drilling Superintendent RECEIVED FEe 1 4: 2002 Alaska Oil & Gas Cons. Commission Anchorage enclosures ORIGINAL ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ] Abandon [ ] Suspend [ ] Alter Casing [ ] Repair Well [X) Change,Approved Program [] Operation Shutdown [ ] Plugging [ ] Pull Tubing [ ] Re- Enter Suspended Well 5. Type of well: [ ] Development [X] Exploratory [ ] Stratigraphic [ ] Service [ ] Time Extension [ ] P orate [ ] Variance [ther [ ] Stimulate 6. Datum Ele 2. Name of Operator Anadarko Petroleum Corporation #1 3. Address 3201 C Street, Suite 603, Anchorage, Alaska 99503 4. Location of well at surface 331' FSL, 2258' FWL, Sec. 30, T9N, R2E, UM At top of productive interval 150' FNL, 2423' FWL, Sec. 31, T9N, R2E, UM At effective depth 150' FNL, 2423' FWL, Sec. 31, T9N, R2E, UM At total depth 150' FNL, 2423' FWL, Sec. 31, T9N, R2E, UM 12. Present well condition summary Total depth: measured true vertical measured true vertical Perforation depth: 9. Permit Number 202-010 10. API Number 50-103-20403-00 11. Field and Pool Wildcat Effective depth: feet feet feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Cemented MD TVD RECEIVED measured fES 1 4 2002 True vertical Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade and measured depth) 13. Attachments 14. Estimated date for commencin)foperation 2/28/02 16. If proposal was verbally apDfoved N/A Name of approver Date Approved Service Proposed Exploratorv Contact Engineer N e/Number: Jim Rose, 907-273-6304 Prepared By Name/Number: Bill Penrose, 907-258-3446 17. I hereby certify th he foregoing is true and correct to the best of my knowledge s~nG~~4~ [ ] Detailed Operations Program 15. Status of well classification as: [ ] BOP Sketch [ ] Oil [ ] Gas [ ] Suspended Conditions of Approval: Title Drilling Superintendent - Commission Use Only Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Date 2/14/02 Location Clearance Subsequent form required 10- IApproval No. :~-<Yo~ Approved by order of the Commission Form 10-403 Rev. 06/15/88 Commissioner Date Submit In Triplicate ORIGINAL ~. Anadarko Altamura #1 Proposed Program Modification The Anadarko Altamura # 1 exploration well was originally proposed and approved as a straight hole. However, recent re-examination of geological data has resulted in an optimized bottomhole location approximately 508 feet to the southeast of the surface location. Anadarko therefore proposes to drill the Altamura # 1 as a directional well to the new BHL. The revised bottomhole location remains well away ftom all lease bow1daries. Attached is the directional program that indicates the wellbore trajectory to be used to achieve the desired bottomhole target. Sperry-Sun Drilling Anadarko Alaska Altamura Altamura 1 (South) WP04 ..., ~ ""V-5Ur1 CFUL.L..JIIIQ, 5EFlVICE5 A HoniOurtoo Cornpooy An-l'IqIft 0 -- - - - -- - - - - - -- 2000 - 4000 - - --- ã) ~ .$;. õ. Q) 0 ro u :e 6000- ~ 8000 - ö 0 0 N II '£ 10000 - ~ iri œ 0 00 4 1/2" 10124.400 MD 10032.00ft lVD ~End Dir, Start Sail @ 0.000° : 4817.48ftMD,4725.0OftTVD !; ~ ~ :!¡8 2 7" J l 8551.48ft MD -- -" - 8459,OOfUVD .!.L-Total Depth: 10124.48ftMD,10032.00ftTVD I I 0 2000 Scale: 1inch = 20olBection Azimuth: 161.115° (True North) \/ørtlr..,,,1 C:O/"hl'\n "^/Olt\ Begin Dir @ 4.0000/10Oft: 3000.000 MD, 3OO0.00ft TVD End Dir, Start Sail @ 25.006° : 3625.14ftMD,3605.48ftTVD Begin Dir@ 4.0000/10Oft: 4192.34ft MD, 4119. Scale: 1inch = 2o~~&tit1H:> (Well) 0 I 200 I \ """0 - -200 QJ ~ U'I C) C ~ - -400 ú Z End Dir, Start Sail @ 0.000° : 4817.48ftM"J,4725.00ftTVD ---- Altan/lIra 1 Total Depth: 10124.48ftM ~,10032.0OftTVD 8509.00 n.]), 480.9j s-. 164.51 J' <5 0 C\ - -600 II ..c 0 ,~ Well: Horizontal Coord nates: Ref, Global Coordna1Ss : Ref, Slrucllre : Ref, Geoga¡:tícal Coordnates : RKB Bevation : North Reference: I UriIs: 9 518" 2750,OOft MD 2750.00ft lVD J ~/Begin Dir @ 4.0000/100ft : 3000.000 MD, 3000.000 TVD ~~t, En"d" Dir, Start",:,.,s."a"i."I,,@,:,25.006O : 3625.14ftMD,3605.48ftTVD : _yBegin Dir @ ~~00/100ft: 4192.34ft MD, 4119.52ft TVD Current Well Properties Marrua 1 (Sou1h) 5888899,10 N. 284418.40 E 882423,71 N, 240718,59 W 70' 05'57,5662" N. 151' 43' 45,3985" W 149,OOft above Mean Sea Level 149,000 above Stru::b.Jre ~ rn 0 (fJ -~~~ Proposal Data for Altamura 1 WP04 Trœ North Feet(US) Vertical Origin: Well Horizontal Origin: Well Measurement Units: fI North Reference: True North Dogleg severity: Degrees per 100 feet (US) ---I Vertical Section Azimuth: 161.115" I Vertical Section Description: Well I Vertical Section Origin: 0.00 N,O.OO E --- Measured Incl. Azlm. Vertical Northlngs Eastlngs Vertical Dogleg Depth Depth Section Rate --- 0.00 0.000 358.374 0,00 O,OON 0.00 E 0,00 3000,00 0,000 358.374 3000.00 O.OON 0.00 E 0,00 0,000 3625.14 25.006 161.115 3605.48 127,04 S 43.46 E 134,26 4.000 4192,34 25,006 161.115 4119,52 353,89 S 121.06 E 374.02 0,000 4817.48 0.000 358.374 4725.00 480,93 S 164.51 E 508.29 4.000 8601.48 0.000 358.374 8509.00 480,93 S 164.51 E 508,29 0.000 10124.48 0.000 358.374 10032,00 480.93 S 164,51 E 508.29 0,000 l _-----.-J Sperry-Sun Drilling Services . Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Anadarko Alaska Sperry-Sun Drilling Altamura Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Easting$ Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) -(It) (°/1 0 Oft) 0.00 0.000 0.000 -149.00 0.00 0.00 N 0.00 E 5888BGG;10N .:.28#18AOE 0.00 100.00 0.000 0.000 -49.00 100.00 0.00 N 0.00 E 588$~9.1ŒN " 284418:40 E 0.000 0.00 200.00 0.000 0.000 51.00 200.00 0.00 N 0.00 E . 58888~åON 284418.40 E 0.000 0.00 ~~ 300.00 0.000 0.000 151.00 300.00 0.00 N 0.00 E . ~ 5888899:~10 N 284418.40 E 0.000 0.00 400.00 0.000 0.000 251.00 400.00 0.00 N O.OO.E~, ".5888899:tO N 284418.40 E 0.000 0.00 500.00 0.000 0.000 351.00 500.00 0.00 N .U~ Ê'5B88899.10 N 284418.40 E 0.000 0.00 600.00 0.000 0.000 451.00 600.00 0.00 N .:-~:tfOOÆ- 5888899.10 N 284418.40 E 0.000 0.00 649.00 0.000 0.000 500.00 649.00 O.OQ.N., " ~ cOA)(f E 5888899.10 N 284418.40 E 0.000 0.00 Base Permafrost 700.00 0.000 0.000 551.00 700.00 ~;OON~c:: Ô.ÓO E 5888899.10 N 284418.40 E 0.000 0.00 800.00 0.000 0.000 651.00 800.00 ,C~"O:oøN .' 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 900.00 0.000 0.000 751.00 900.00 '~¡ß~ø:O N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1000.00 0.000 0.000 851.00 100{f;OO . ~ 0.00 N O.OOE 5888899.10 N 284418.40 E 0.000 0.00 1100.00 0.000 0.000 951.00 ,1iDp;OO', 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1200.00 0.000 0.000 1051.0Q!; ~- -t20QtOO' 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1300.00 0.000 0.000 .1151.ÔØ~'. "i30{fQa 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 --:::--p -, 1400.00 0.000 0.000 ,.Jg51~pO' 1400.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1500.00 0.000 0.000 :~:1351.0n ~ 1500.00 0.00 N O.OOE 5888899.10 N 284418.40 E 0.000 0.00 1600.00 0.000 0.000 ~,1451.00 1600.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1700.00 0.000 0.000 1551.00 1700.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1800.00 0.000 0.000 1651.00 1800.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 1900.00 0.000 0.000 1751.00 1900.00 0.00 N O.OOE 5888899.10 N 284418.40 E 0.000 0.00 '-'--. 2000.00 0.000 0.000 1851.00 2000.00 0.00 N O.OOE 5888899.10 N 284418.40 E 0.000 0.00 2100.00 0.000 0.000 1951.00 2100.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2200.00 0.000 0.000 2051.00 2200.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2300.00 0.000 0.000 2151.00 2300.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2400.00 0.000 0.000 2251.00 2400.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2500.00 0.000 0.000 2351.00 2500.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2600.00 0.000 0.000 2451.00 2600.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2700.00 0.000 0.000 2551.00 2700.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0.00 2750.00 0.000 0.000 2601.00 2750.00 0.00 N 0.00 E 5888899.10 N 284418.40 E 0.000 0,00 9 518" Casing ------------ 12 February, 2002 -13:49 Page 10f7 DrlllQuest 2.00.09.006 Sperry-Sun Drilling Measured Depth (ft) Incl. Azim. 2800.00 2899.00 2900.00 3000.00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 3100.00 4.000 161.115 3200.00 8.000 161.115 3300.00 12.000 161.115 3400.00 16.000 161.115 3500.00 20.000 161.115 3600.00 24.000 161.115 3625.14 25.006 161.115 Sub-Sea Depth (ft) 2651.00 2750.00 2751.00 2851.00 2950.92 3050.35 3148.81 3245.82 3340.91 3433.61 3456 .48 Vertical Depth (ft) 2800.00 2899.00 2900.00 3000.00 3099.92 3199.35 3297.81 3394.82 3489.91 3582.61 3§Q5.4äó~:~ Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 3700.00 25.006 161.115 3524._43' ~ ~361~aa -, 3800.00 25.006 161.115'~3614.9& -~63t9~ 3900.00 25.006 161.115 ¡c:3Z9?58èt ,,3854.5Sc 4000.00 25 .006 161.11531'9l)~2l'" 3945.21 4048.32 25.006 161.115~;3840.00 4100.00 25.006 161.115 . 3886.83 4192.34 25.006 161.115 3970.52 4200.00 24.699 161.115 4300.00 20.699 161.115 4400.00 16.699 161.115 4500.00 12.699 161.115 4600.00 8.699 161.115 4700.00 4.699 161.115 4800.00 0.699 161.115 4817.48 0.000 0.000 4900.00 5000.00 5100.00 5200.00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 12 February, 2002 -13:49 3977.47 4069.70 4164.41 4261.11 4359.36 4458.65 4558.52 4576.00 4658.52 4758.52 4858.52 4958.52 3989.00 4035.83 4119.52 4126.47 4218.70 4313.41 4410.11 4508.36 4607.65 4707.52 4725,00 4807.52 4907.52 5007.52 5107.52 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 N 0.00 N 0.00 N 3.308 13.198 29.62~~L 54.50 '5< :081 :73'8 cj17.1'l~S 127.048 156.98 8 196.978 236.978 276.96 8 296.29 8 316.968 353.89 8 356.94 8 393.44 8 423.778 447.77 8 465.33 8 476.378 480.828 480.938 480.938 480.938 480.93 8 480.938 Global Coordinates Northings Eastings (ft) . . {It} . 0.00 E 588ê8~9;10J~ "~8~18.40E 0.00 E 588aa~,ß.1QJ~¡; 22~41.8.40 E 0.00 E , 588889!!,tÓN 284418.40 E 0.00 E '. .. 588889~aO N 284418.40 E ,;4':5]'£ ':1~1,3 E 17:'96 E 27.96 E 40.08 E -J1:¥~'~8895.77 N - 5888885.79 N 5888869.21 N 5888846.11 N 5888816.61 N 5888780.84 N 43.46 E 53.70 E 67.38 E 81.06 E 94.74 E 101.35 E 108.42 E 121.06 E 122.10 E 134.59 E 144.96 E 153.17 E 159.18 E 162.95 E 164.48 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E Page 2 of 7 5888770.88 N 5888740.66 N 5888700.30 N 5888659.93 N 5888619.56 N 5888600.05 N 5888579.19 N 5888541.92 N 5888538.84 N 5888502.00 N 5888471.39 N 5888447.16 N 5888429.44 N 5888418.30 N 5888413.80 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 284419.44 E 284422.54 E 284427.69 E 284434.86 E 284444.03 E 284455.14 E 284458.23 E 284467.62 E 284480.16 E 284492.70 E 284505.24 E 284511.31 E 284517.79 E 284529.37 E 284530.32 E 284541.77 E 284551.28 E 284558.80 E 284564.31 E 284567.77 E 284569.17 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E Dogleg " Rate (0/100ft) 0.000 0.000 0.000 0.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 . Anadarko Alaska Altam ura Vertical Section Comment 0.00 0.00 K3 Marker 0.00 0.00 Begin Dir @ 4.0000/10Oft : 3000.0Oft MD, 3000.00ft TVD 3.49 13.94 31.30 55.49 86.38 123,84 134.26 End Dir, 8tart Sail @ 25,006° : 3625. 14ftMD,3605.48ftTVD 165.91 208.18 250.45 292.72 313.15 Base Brookian 8ands 334.99 374.02 Begin Dir @ 4.000°/1 Oatt : 4192.34ft MD, 4119.52ft TVD ~ 377.24 415.82 447.88 473.25 491.81 503.47 508.18 508.29 End Dir, 8tart 8ail @ 0.000° : 4817.48ftMD,4725.00ftTVD 508.29 508.29 508.29 508.29 Dri/IQuest 2.00.09.006 Sperry-Sun Drilling Measured Depth (ft) 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6529.48 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7434.48 7500.00 7532.48 7600.00 7607.48 7641.48 7700.00 Incl. 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 12 February, 2002 -13:49 Azim. 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 Sub-8ea Depth (ft) 5058.52 5158.52 5258.52 5358.52 5458.52 5558.52 5658.52 5758.52 5858.52 5958.52 0.000 6058.52 0.000 6158.52 0.000 6258.52 0.000 6288.0Q , 0.000 c -~:6358.5~r~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 - ':~-,~:~~ -~;6658.52 6758.52 6858.52 6958.52 7058.52 7158.52 7193.00 7258.52 7291.00 7358.52 7366.00 7400.00 7458.52 Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Vertical Depth (ft) 5207.52 5307.52 5407.52 5507.52 5607.52 5707.52 5807.52 5907.52 6007.52 6107.52 6207.-g2, 63A?;52;:;~, ,_64(J~;52 "ýê: cfi431~{!{k;l ~01~5~ - 6607.52 "6707.52 6807.52 6907.52 7007.52 7107.52 7207.52 7307.52 7342.00 7407.52 7440.00 7507.52 7515.00 7549.00 7607.52 Local Coordinates Northings Eastings (ft) (ft) 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93,§ - , 4~;9.;3 Si.fc ':-:~. '48<J:93';S ' '480.93' S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S Global Coordinates Northings Easting~: (ft) 'tftt ' 164.51 E 588~~~.3=~1<t )t 164.51 E 5888413.7Q'N 164.51 E , 588B41~76N 164.51 E '~;58884f3,,10 N 164.51E~; c,:è'5888413';'lO N , J~~,1E~ ~c qß4':5l.;£ ' -l~$f'E 1&f51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E Page 30f7 5888413.70 N .. 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N , 284SE;92<rE ':284569~20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E Dogleg Rate (01100ft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section Comment 508.29 508.29 508.29 508.29 508.29 508,29 508.29 508.29 508.29 508.29 508,29 508.29 508.29 508.29 TI F.e. Slumps 508.29 508.29 508.29 508.29 508,29 508.29 508.29 508.29 508.29 508.29 BJ F.e. Slumps 508.29 508.29 TI HRZ 508.29 508.29 Base HRZ 508.29 K-1 508.29 . Anadarko Alaska Altamura DrHIQuest 2.00.09.006 Sperry-Sun Drilling Measured Depth (ft) 7800.00 7808.48 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8551.48 8600.00 8601.48 8700.00 8700.48 8774.48 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 9924.48 10000.00 10100.00 Incl. 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 12 February, 2002 -13:49 Azim. 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Sub-Sea Depth (ft) 7558.52 7567.00 7658.52 7758.52 7858.52 7958.52 8058.52 8158.52 8258.52 8310.00 8358.52 8360.00 Vertical Depth (ft) 7707.52 7716.00 7807.52 7907.52 8007.52 8107.52 8207.52 8307.52 8407.52 8459.00 8507:~~~- 8~?-:0ô'f- -c ~:~~~Ji:~~~~:g~~t~-/~~~~~ 0.000 :-{~~_~§33i{)O-~-- 8682.00 - 0.000 -~~ß558.52 0.000 8658.52 0.000 8758.52 0.000 8858.52 0.000 8958.52 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 9058.52 9158.52 9258.52 9358.52 9458.52 8707.52 8807.52 8907.52 9007.52 9107.52 9207.52 9307.52 9407.52 9507.52 9607.52 9558.52 9707.52 9658.52 9807.52 9683.00 9832.00 9758.52 9907.52 9858.52 10007.52 Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Local Coordinates Northings Eastings (ft) (ft) 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93~~L 1~-:g~ SHf' ~8n:~~ - -iâø~øg;;s 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S Global Coordinates Northings Easting( (ft) : Jft}. 164.51 E 588ti4J~~ffO~1\l - 164.51 E 58884;1~3.!0~ 164.51 E -_Òo.- 58884~¿ilON 164.51 E 'fj!, 588841'3:il0 N 164.51\~:--: :_~88413:r{) N :,:182fc[&1 EfL:; ~~5ð88413.70 N ":~1~~51£ --,c-5888413.70 N ':j'M~1iE 5888413.70 N 16;i[51 E 5888413.70 N 164.51 E 5888413.70 N 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E Page 4 of7 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N 5888413.70 N - -- - :'':~84@9~OE : '2845'69:20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E 284569.20 E . Anadarko Alaska Altamura Dogleg Vertical Rate Section Comment (~/1 0 Oft) 0.000 508.29 0.000 508.29 LCU 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 7" Casing 0.000 508.29 0.000 508.29 T/ Upper Jurassic Target - Altamura 1,200,00 Radius" Drillers 0.000 508.29 0.000 508.29 UJU 0.000 508.29 T/ Nuiqsut "A" 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 .- 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 0.000 508.29 T/ J-3 0.000 508.29 0.000 508.29 ---- DrlllQuest 2.00.09.006 Sperry-Sun Drilling Measured Sub-Sea Vertical Depth locI. Azim. Depth Depth (ft) (ft) (ft) 10124.48 0.000 0.000 9883.00 10032.00 Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - A/tamura 1 WP04 Revised: 12 February, 2002 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Ea~ng~~ (ft)oy(ft) ~ . '.~84569.26E 480.93 S 164.51 E All data is in Feet (US) unless othelWise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 161.115° (True). Based upon Minimum Curvature type calculations, at a Measured Deptttpf itØ'f24~ft., The Bottom Hole Displacement is 508.29ft., in the Direction of 161.121§jfTf!1~2: -F Comments Measured Depth (ft) 3000.00 3625.14 4192.34 4817.48 10124.48 12 February, 2002 -13:49 TVD S tat Ij¡;~OgZ~~d~:~.~ t (ft) "~*/t.}:~¿. '-~~c (ft) 3000.00 3605.48 4119.52 4725.00 10032.00 0.00 N 127.04 S 353.89 S 480.93 S 480.93 S 0.00 E 43.46 E 121.06 E 164.51 E 164.51 E Comment Begin Dir @ 4.0000/100ft : 3000.00ft MD, 3000.00ft TVD End Dir, Start Sail @ 25.006° : 3625. 14ftMD,3605.48ftTVD Begin Dir @ 4.0000/100ft: 4192.34ft MD, 4119.52ft TVD End Dir, Start Sail @ 0.000° : 4817.48ftMD,4725.0OftTVD Total Depth: 1 0124.48ftMO, 1 0032.0OftTVD Page 50f7 . Dogleg ..Rate (0/100ft) 0.000 Vertical Section . Anadarko Alaska Altam ura Comment 508.29 Total Depth: 10124.48ftMD,10032.00ftTVD 4 1/2" Liner ~-'- DrlllQuest 2.00.09.006 Sperry-Sun Drilling Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 500.00 2750.00 3840.00 6288.00 7193.00 7291.00 7366.00 7400.00 7567.00 8360.00 8459.00 8533.00 9683.00 Casing details 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - AJtamura 1 WP04 Revised: 12 February, 2002 . Profile Penetration Point Measured Vertical Sub-8ea Depth Depth Depth (ft) (ft) (ft) 649.00 2899.00 4048.32 6529.48 7434.48 7532.48 7607.48 7641.48 7808.48 8601 .48 649.00 2899.00 3989.00 6437.00 7342.00 7440.00 7515.00 7549.Qgo' 77!§:ÍlO ' -8509i()0 500.00 2750.00 3840.00 6288.00 7193.00 , ~~~~ ' -:l400.(){k ~~7.00 8~6n.00 ~ . - -~ 0.000 ;\Ui~lPO.48:~ - 8tì()a.ooo~ 8459.00 0.000Y'á7q~Ø_8c:-~~ 8682.00:- 8533.00 0.000c-99g4:'4~: ': 9832.00 9683.00 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surtace> <Surtace> <Surtace> <Surtace> <Surtace> <Surtace> 12 February, 2002 ~ 13:49 2750.00 2750.00 8551.48 8459.00 10124.48 10032.00 Casing Detail 9 5/8" Casing 7" Casing 4 1/2" Liner Northings (ft) 0.00 N O.OQN 296,49:S'~::- 480;l)?c~F - 4~0:gaS- '4.80.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S 480.93 S Page 60f7 164.51 E 164.51 E 164.51 E 164.51 E 164.51 E Anadarko Alaska Altam ura - - F¿rmåtionName ~-- - Base Permafrost K3 Marker Base Brookian Sands TI F.C. Slumps BI F.C. Slumps TI HRZ Base HRZ K-1 LCU TI Upper Jurassic 164.51 E UJU 164.51 E TI Nuiqsut "An 164.51 E TI J-3 --~ --~_.- DrlllQuest 2.00.09.006 Sperry-Sun Drilling Sperry-Sun Drilling Services Proposal Report for Altamura 1 (South) - Altamura 1 WP04 Revised: 12 February, 2002 Targets associated with this wel/path Target Name Altamura 1 12 February, 2002 -13:49 TaÆS 1YØTê~- -IIi!) - 8509~OO -- Mean Sea Level/Global CoordinateS:-~r~ ~- 8360.aa', Geographical Cqg[s!inat~: - T~~~¡~- o---~200.00ft Page 7 of 7 nt-::~ço-or din ate s NcOjhirigs Eastings . (ft)- (ft) 480.93 S 164.51 E 5888413.70 N 284569.20 E 70° 05' 52.8360" N 151043'40.6489" W . Anadarko Alaska Altam ura Target Target Shape Type --, Circle Drillers -""- DrlllQuest 2.00.09.006 ~~/Æ~¡ ,~: :} /Æ~!Æ~~~!Æ f '\ ALASKA OIL AND GAS CONSERVATION COMMISSION Tommy Thompson Drilling Superintendent Anadarko Petroleum Corporation 3201 C Street Ste 603 Anchorage AK 99503 TONY KNOWLES, GOVERNOR 333 w. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Altamura # 1 Anadarko Petroleum Corporation Permit No: 202-010 Sur.Loc.331'FSL,2258'FVVL,Sec.30,T9N,R2E,~ Btmhole Loc. 331' FSL, 2258' FWL, Sec. 30, T9N, R2E, ~ Dear Mr. Thompson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits requireq by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 MC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation futegrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, C,,~~ ~ Cammy ~chsli Taylor Chair BY ORDER OF THE COMlVlISSION DATED this 8th day of February, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 12-1/4" 8-112" 6-1/8" 9-5/8" Weight 65# 40# 26# 12.6# STATE OF ALASKA ALAS~ IL AND GAS CONSERVATION CO~' 'SSION PERMIT TO DRILL 20 AAC 25.005 [ ] Redrill11 b. Type of well [] Service [ ] Development Gas [ ] Single Zone [ ] Deepen [X] Exploratory [] Stratigraphic Test [ ] Development Oil 5. Datum Elevation (DF or KB) 10. Field and Pool 29' RKB 6, Property Designation AA-081736 7. Unit or Property Name Altamura 8, Well Number #1 9. Approximate spud date 02/15/02 14. Number of acres in property 15. Proposed depth (MD and TVD) 5,744 10,003' TVD/MD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} NIA Maximum surface 3.481 psig. At total depth (TVD) Setting Depth Top Bottom MD TVD MD TVD 29' 29' 80' 80' 29' 29' 3000' 3000' 29' 29' 8430' 8430' 8278' 8278' 10003' 10003' VJ~Â- 2-/~ (o ÞL- ¡;¡.-' ~/''''i<:)~) ðM H- v?J ;;1<:;'?- 1 a. Type of work [X] Drill [ ] Re-Entry 2. Name of Operator Anadarko Petroleum Corporation 3. Address 3201 C Street, Ste. 603, Anchorage, Alaska 99503 4. Location of well at surface 331' FSL,2258'FVVL, Sec. 30, T9N, R2E, U.M. At top of productive interval Same (straight hole) At total depth Same (straight hole) 12. Distance to nearest property line 2,258' E. of lease line 16. To be completed for deviated wells Kick Off Depth: NIA 18. Casing Program Size Hole Casing 20" 16" [ ] Multiple Zone Wildcat 11. Type Bond (See 20 AAC 25,025) Blanket Number JX-8726 Amount $200,000 113. Distance to nearest well 4.7 miles S. of Rendezvous #2 Maximum Hole Angle: 4,581 psig 7" Specifications Grade Coupling H-40 NIA L-80 BTC L-80 BTC-Mod L-80 IBT-mod Length 51' 2971' 8401' 1725' Quantity of Cement (include stage data) ~1n" 237 sx AS1 Stage 1: 340 sx G, Stage 2: 324 sx AS3 421 sx G 118 sx G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Plugs (measured) Junk (measured) Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner RECEIVED JAN 1 4: 20D? AlaskaOi/& Gas c() ¡¡;. ~ AnChorage Perforation depth: measured true vertical [X] Filing Fee [X] Property Plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling Program [X] Drilling Fluid Program [X] Time vs Depth Plot [] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Contact Engineer Name/Number: Tommy Thompson 273-6300 Prepared By Name/Number: Bill Penrose 258-3446 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -'''\ ~ ' I U~. - ~~ Title Drilling Superintendent Date \ / \It- <> L- U Commission Use Only Permit Number IAPI N~mberJ /"') / /~'" ~ ðð I ~~J~~' I See cover letter -zé)Z ,- 0/0 ..56 - /ð'3 - L-'--' ~ - . ¡ , for other requirements Conditions of Approval: Samples Required: .j)(\'es [] No og Re uired ,)(rYes [ ] No Hydr~gen Sulfi~e Measures: WYes [] No Directional Survey Req'd [] Ye,~ WNO Required Working Pressu~e for BOPE: [] 2M, [] 3M, [15M, [] 10M, [] 15M 7.~{n(lh~ Ot'OY;giilãfSiJñelå'ft i-ð 5000 f ~. vJ~~P:;1)¡1 .svrll~ 'j)" C y , ammy Oechsli by order of Q ~ /) Commissioner the commission Date V' J 0\ Submit n l'iplicate 20. Attachments Approved By Form 10-401 Rev. 12-01-85 OR\G\NAL (- Anadarko Altamura #1 RI2CÐVI2D J A,II./ 1 4. ';'0 '7 ' ""- ¿ [;) Alaska Oil & G"r- (, " (Jð ...,Oi?s Co " ¡~nchor~ge' rntfJISSion Overview and Timetable Anadarko Petroleum Corporation plans t.9" drill two exploratory wells, Altamura #2 and #1, in NPRA this winter. Altamura #1, the first to be drilled, will be located approximately 19 mules southwest of the village ofNuiqsut. The well will be drilled from a temporary ice pad with spud~g estimated to occur approximately February 15, 2002. The well will be drilled as a straight hole. The well will be accessible by ice roads and rolligon across the frozen tundra. A map showing details of the ice road routes and lengths as well as the drilling location are enclosed in this application. ( Ice road and pad construction will begin as soon as the necessary permits and approvals are available and weather conditions allow. It is planned that the Altamura ice road ~ be a 4.7-mile extension off of Phillips Alaska's (PAl's) planned ice road to PAl's Rendezvous #2 wellsite. Anadarko anticipates using rolligons to transport water to the well site as soon as tundra travel is allowed and the necessary permits and approvals are in place. Construction of the ice road and ice pad will occur concurrently. While it is planned to use rolligons to transport Nabors' Rig #14-E to the wellsite, a backup plan involves using trucks to transport the rig if all ice roads, including PAl's road from 2P Pad to the Rendezvous #2 exploratory well site, are completed in time. j Well testing may be performed. Current plans are to plug and abandon the well prior to the end of the 2001/2002 winter drilling season; however, the well may be temporarily suspended if well evaluation cannot be completed prior to the closing of tundra travel in the spring of 2002. Any well suspension will be performed in accordance with applicable BLM and AOGCC regulations. Operational Considerations Permafrost Based on offset 'jells, permafrost is assumed to be present from the surface to approximately 620'. The permaftost is not expected to present any drilling difficulties as neither thawing nor gas hydrate problems were encountered in any of the offset wells. Lost Circulation Some of the offsetting wells encountered lost circulation in and near their target horizons. The Altamura # 1 casing and mud programs have been designed to take this possibility into account. Intermediate casing will be set just above the target horizon and the mud weight cut to avoid lost circulation. When TD is reached, the target interval will be cased with a production liner. { if { Pressures Anticipated pore pressures are derived primarily from the histories of offsetting wells. These wells, referenced in the Pressure section of this application, were all drilled in the past few years and are well documented. As shown on the attached pore pressure plot and ~imum ~tici~ted surface pres~ure (~SP) cal~ulations, the expected pressure. at TD IS 4,581 pSi (8.8 ppg E~' and will resuJt m a maxunum pressure at the surface, With a full column of gas, of 3,481 psi. A 5,600 psi WP BOP and wellhead system will therefore be used on this well. Shallow gas is not anticipated. The Pressure section of this application contains a Shallow Gas Hazard Evaluation that reviews offsetting stratigraphy and log indicators as well as seismic indicators. Drilling Within Annular Blowout Preventer Limitations As shown in the MASP calculations, no surfacJ"'pressures are expected above the surface casing setting depth that will exceed the 2,000 psi working pressure rating of the diverter. Below the surface casing, BOPs will be used in lieu of a diverter. Again, the }'!ASP calculations show that all anticipated surface pressures are well below the 5,000 psi working pressure rating of the annular preventer. ( BOP System and BOPE Testing The BOP system on Nabors Rig #14-E is rated at 5,000 psi working pressure and is described in the BOPE section of this application. Since the calculated maximum anticipated working pressure at TD in. this well is 3,481 psi, it ~planned to routinely test all BOPE to 100% of its rated working pressure (i.e., 5,000 psi). .// The BOP system will be tested initially (before spudding the....well) and weekly thereafter to a low pressure of 200 psi and a high pressure of 5,000 psi (100% of rated working pressure). Straight Hole The Altamura #1 will be drilled as a straight hole. Wellbore deviation will be monitored and recorded per applicable regulations and reported in the well's completion reports. H2S None of the offsetting wells encountered measurable amounts of H2S and it is not expected that Altamura #1 will encounter any. However, the drilling rig will be wired with operating sensors, enhanced by additional sensors tied into the mud logging syste~ to continuously monitor for the presence ofH2S ( Drilling Waste Handling Drilling mud and cuttings from the well will be pumped down the 7" X 9-5/8" annulus or will be hauled to an approved disposal facility. An average of 20,000 bbls of liquid waste from the well may require processing or disposal. t Prior to on-site disposal or hauling, mud and cuttings will be temporarily stored in a bermed storage cell on the ice pad. Diagrams are included with this application that show the ice pad layouts with the proposed location 0/ the storage cell and cross-sectional layouts of the storage cell. Approximately 15,000 cubic feet of cuttings will be generated by drilling the primary wellbore and a sidetrack. If disposed on-site, drill cuttings and gravel ITom the well will be ground in a portable ball mill. After ~ding, the mud and cuttings will be pumped into subsurface formations below 3,000' via the 9-5/8" surface casing X 7" intermediate casing annulus. Included with this application is a Shallow Sand Study in the Rendezvous Area by Anadarko's J.D. Kilgore. This study uses 1%/ analysis to show that the formations into which waste fluids will be injected are not of aquifer quality. Additional Information Additional information on operations such as formation tops, logging, mud logging, etc. can be found on the attached Altamura #1 Well Prognosis. Certified Location Plat An as-built location plat, certified by a Registered Land Surveyor, will be submitted shortly after construction of the drilling location is completed and the conductor set. Contacts The contacts within Anadarko for information are: Reporting and Technical Information Tonuny Thompson (907) 273-6300 Geological Data and Logs John Hartner (907) 273-6300 { J (' Well Name: Surface Loc.: Target Loc.: Bottomhole Loc.: Elevations: Planned TD: Formation Tops: ( Cores: Planned Logs: ( { Anadarko Altamura #1 Well Pro2Dosis Anadarko Altamura # 1 331~FSL,2258'FVfL,Sec.30, T9N,R2E~~ Same (straight hole) Same (straight hole) /' Ground Level 125' AMSL RKB 29' AGL I 10,003' TVDIMD TOPS Base Permaftost K -3 Marker Base Brookian Shelf Sands F.C. Slumps (Top) F.C. Slumps (Base) HRZ (Top) HRZ (Base) K-1 LCU Upper Jurassic UJU Nuiqsut A J-3 TD DEPTHS (MD/TVD) 620~ 2 870' . , - s....,J ~ ,(~ ~ 'S.'- 3,960' ~ 6,408' 7,3 13 ' 7,411' 7,486' 7,520' 7,687' - '. j~ .~" L 8 480' \ ,,~,'("\"\.~c::; ,~"\(( , 8,579' 8,653 ' 9,803' 1 0,003' Two (2) 60' cores are planned in the 6-118" hole 12 ~ Surface Hole" 80'-3,,000' L WD Only - GR, Res, DenslNeutron, Sonic 8-112" Intermediate Hole.. 3..000' - 8.,430': L WD Only - GR, Res, Dens/Neutron, Sonic 6-1/8" Production Hole" 8,,430' - 10,,003' TD: L WD - GR, Res, Dens!Neutron, Sonic E-line - RFT, NMRI, Side Wall Cores Mud Logging: Contingent Logging: ( ( ( .,/ Mud logging will be in operation from the base of the 16" conductor to TD. Service will include sample collection, ROP, lithology, show description, hot wire, gas analysis of cuttings, gas chromatography, and drilling parameters. Thirty-foot (30') samples will be collected from the base of the surface casing, and 10-foot (10') samples will be collected in zones of interest. The wellsite geologist will adjust the interval or sample frequency as required. Planned Sampling 1 set unwashed each: Anadarko 3 sets washed and dried: Anadarko 1 set washed and dried: Partners (2), State of AK, BLM 1 set canned ditch samples for geochemical analysis collected at 30' intervals from base of the structural casing toTD. If conditions dictate, electric line confirmation of the L WD logging suite is planned. ( ( ( Shallow Sand Study in the Rendezvous Area 1. D. Kilgore Anadarko Petroleum A study has been undertaken to understand the shallow lithologies in the Rendezvous area. The purpose of this study is to detennine the proper casing programs to use in upcoming wells that will protect fresh water aquifers. The Rendezvous A well has been studied and few sands were found above 3,000 feet. In addition all of the sands and shale below 600 feet appear to be saline with total dissolved solids (TDS) approaching 9,000 ppm. Above 600 feet the resistivity data seems to indicate hard pennafrost. In the study of Rendezvous A wireline well logs were used to examine the lithologies and water chemistries. The gamma ray, resistivity, sonic, shear, density, and neutron logs were utilized. Various calculations were made to obtain porosity and salinity estimates from these logs. ( The gamma ray was affected by an enlarged bore hole. The gamma ray tool measures natural gamma radiation that is present in the rocks. Proper measurement of the natural gamma radiation requires that the tool is close to the formation. In larger holes the tool is often far away from the formation and the gamma ray tool undercounts the formation gamma rays. The muds in larger bore holes act as a shield absorbing the gamma rays before they can be read by the tool. To correct this problem gamma ray tools are environmentally corrected for the large bore hole effect. The gamma ray in this well was corrected using the reported drill bit sizes. Shale volumes were calculated from gamma-ray and density/neutron where available. The sonic was logged over the entire bore-hole and was used for porosity calculations. The "Hunt-Raymer"¡ algorithm was used to obtain porosity from the sonic. ø =0.6* (ð.T -56)/ ð.T Salinities were calculated using the RW A or "Rw Apparent" technique. In this technique it is assumed that all sands are 1 00% water bearing and that no excess conductivity ftom the shales in the system are present. The Humble coefficients were used for values of a and m (ie:a=0.62 and m=2.15). The temperature gradient was taken 1Ì"om the bottQffi hole temperature measured by the wireline tools. All RWA values are converted to 750 F for easy comparison. Salinities have been converted to total dissolved solids, TDS, in units ofppm at 750 F. Rwa=aRw/Øm Based on the results of this study we conclude that there are no ftesh water aquifers below the planned casing point at 2600 feet. ( I Raymer, LL., Hunt ER, & Gardner J8., "An Improved Sonic Transit Time-to-Porosity Transform", Transactions of the SPWLA 21st Annual Logging Symposium( 1980). ....... 1, Rendezvous A: The Rendezvous A well logs over the shallow section are displayed in Figure 1. The well encountered few sands above 3,000 feet. Most of the thin sands encountered appear to have low porosities based on the sonic. There is no density or neutron data above 2700 feet. The gamma ray is displayed in track one with an environmentally corrected gamma ray. The increase in resistivity above 600 feet occurs mainly in shales and probably indicates hard permaftost and perhaps a reduction in salinity. A resistivity curve, a calculated R W A curve and the TDS curve are presented in track two. Density and neutron logs are presented in track three. Sonic and shear logs are presented in track four. A calculated porosity curve is given in track five and shale volume is presented in track seven. ( Rendezvous A well logs from surface to 4000 feet. _'(t!m¥å'qtI~~'~"V~'''.f'f'V~IV'I1.W-YW~'''''._. ~'\'~'~~'~''-" . );'" !.j.I~~=;""J~r" '!:,~;(,;,~ií ~~~'(;(;à(:vi,~t!:i, .;'i~i';(;\;'((':'" 1m ,~"'.'~'" ,',';,!.n";':I:¡ffii,""'~' ,,!tI""'~~~'~~~i';~'~'~;f ,,} ';~~": '\\i:)+iiY:!':i ';"I;\.'I'J;(', h¡;"!@', ""~' 'iWI;:i,<::1,,;,i~ ""..":;';I}li.:\I)I",I'¡:'i:,::)\,li::{~(\;!.~I': .,i~i::',i.."'}', ',>t:',!:(i,/¡\,jlj" ":.i,r~"."..".¡,t:":¡,1':;':'\ ' , '.,'" ',',:"",:',., II,',':'" i, ,l"li\'!I,:,~,:" ' ",i,,~il"I':"I' 'I':t, , ""I,,l ,1¡;1; """:i\,I"...,l'j"'I,,,\, t't,!:- II, 1::.l:I,I',/:,II"."I'III':, 'l"(' :I"I,MI ì ,..f '.",I. ,lt,li\ ,,' 111,,':,'.'1,.,1'1': "'~, ,I "¡,!ž C1Ur>£R-'V9IS.TtJ'l;.1 , " ¡ \' ".,~"",!",,,,,,,,,,'.j,,,,,',",' ......... .,"""'. 2ò tOm- ':',1,:1, (.;,,\';~ 4 Ul~OOR-: po AN.l.LVSI5,11,vA..RWL' , \~~1 ,!,,~~ j".""."."":IIIb 02 O"~~" :!IIÞ: ,.., '. ""'" :,:, "-",,,' '1"[\ .',',",:,',1,','.'",',',',',""',',,'.',",,',' ":~'I':'I'il:':'ijï¡¡"i...ií'¡;¡¡¡"I":',":""I"':' DE' PTH , 1;,"""1\",;/,,';,1.)'1.1,',_, ';.1', 'JJ1j ANAL V'51~.N[VTrI, 011.1 " 11;:'¡ltl~,~rl!~, ANAl Y$1$,$H[þ.R.-11;1¡~\,'~) , AN" ""'I'" C"'Jt. ENT.REt.tA.R""- ',' " , " " .., '", .,"', ;\:I:~\;;; ~'~':~';'(.I.~~;'¡'':';~ø fEET \1 ~ ,'(ÙI~~~A , ?ÜC';D:r""'''''~'~'''''''v:Aí8(",....",~~",41'Ô 3eÐ1" ,,''',''"'' 'lß/~h" ,,'-"" ..;-, IEI'~ . P"L I oJ ~- vm "'~ ~~.~... ~ ~~,~ ".\::~ .wAJ,1".;1S.roIffilX'TION_1 l¡W,\l'l'$l$lÍr(p~.. "I"LI'):>I':,J;~I'I~;¡¡Yì ,""'NAþ~r¡~9NI<'_Z. or.N4lYfi.1ll1A,.1 ~7l"+.;;t:~..:u ~ -¡-4~- -s~ .~Fí~~i~\jt'::í~~~Sí :;,~~b::FI~ì;;;tl'~I~,_,~~1;it~~~:ijf~,~~;2f. Figure 1 " MQ E3 . , ( Shale salinities at Rendezvous A ~ x ';''f~:':'~;',1)~!:')'f~;'ri.\7]_':':'',''V':'''\:': "":::,:.""-",,,, ':':'-":,'r: ',':>:,1"':':""':, ',"i"I","I'\',"':", ',"1' """, ""':""""""'-''''~''''''':'''''''''''-'':''''''''",''''':~:,"'.:"~':' D'Ç¡f:rïl'Ü!Ø~~!~I!eJ~~~€A;tiI,-êf~r",' ". "',¡~:.. .", ", .',.... '" '"""'".,,,,:',,',ri{ , .',.'.', ..,.,1:"..,.,/' """,,",< """"",-,' '."~""""':"""""'I ',I.," '"".' "'., """","'"",,,".',- ,',i":, it:'" ~t'I';I'~l:,h:l'l:il:I~I,; 1.'¡lí "IN j l,i,f.,:1 :~1(1':I,I,~I~:j ,~:I,~:' I~I"I',I:;I-IJ'?I'II ,J,~'J ,~ .II,j: 111!il.l'¡i~;;':I,'i.~:'!"I:I,:illnIJ(1 'C ~:,';, ri ,~ ;1:: :;:I\iii; a.o3O. ":II!"i"": " ",'~,:,;\'¡", <O.OZ5. a ,;!:(ii~ ~O20. Y1~ 0.015. :il MfO. ,i!:!',\',~ <J..005. '(:,::I\;~ :~ " {;~ ,I, ~,~ ~:!;\i, :.I~ ;~ j~ :i::W\~ ,I~ ~ \ ( ( ( Formation Water Salinities: A histogram of the shales is presented in Figure 2. The histogram of the RW A curve in the shales shows a mean value of 0.6446 ohm-meters. Converting ohm-meters to total dissolved solids yields a value of about 9,000 ppm. .~ FIVQ1II'q' ~IJIOQrom of RWA in 'Shal.1 \\,\!I:RE~ 82..0 - B~I.5 FtET F1ttr; 0EP1H<~ ð: VSH>.!) - c.. -:-, - -,~ - \ 1,1 J;'" , .¡ 'I J ./1 - / ! ~( 1.0 .o.~ .0.8 '0.7 .o.e ~ .M - .o.~ I 'O.J I I' llnr~ 01 0 II! - ¡.. IX! .0.2 . 0,1 - c¡ 0.0 0 C'>I n ~ <:f\ '" ... 0 , In 0 - , " 0 ~ ",I St<I\ItIII:~ PO!I'!1:ÞI. IIOIun IUel.q IIOluH IIhlmum IoII2løe U(7Iilmum fIG'u. Røroqe Ueon <1eømttrlc Ueøn Hørrnon1c ioIoon 4<421 0 0.00000 1.33.8:mS 133.B2738 O.8~60 Vorb"CI Sklndard 0!Yi0t1on 'Sq.","- Kurlosi:l lIedion UocIc: 5.28580 2.29909 49.BUOf 2707.2.978 0,62565 0.67700 I '1:~7J,~i~~~j¡~:jii~~¡I:~~~å(~~;¡'li;.~~~;~!!' Figure 2 .¡' .. ' ,~'~. i :'~~;"(j¡¡rJz;f ~~I'.#~...,),~~í~i;¡~,lit~~~~:~~~¡¡i¡l~~~~~~:";}~;d~;~1'(.' i ( Unfortunately there are really no clean sands to examine in this well in the shallow section. Figure 3 displays the lack of sands with VSH used as the color bar displayed against the RW A curve. "-' 0 (1 ;'1),1 . ßOO. Æ()O t- W W ~(I :J: t- 1:hJO 0 v) '1j}(I ~ ~ùO Z,1IJO }7(fO ,'Sooo ( ;s. or' q~ ~ ~ 102:16 [, " 0 èUO . . .":-:<'~. .. eoû gOO , . ... . . . ,,- 1 200 . - 1 ~,O(1 '180';) ,2jOO 2,100 non 3000 - ~. C "¡'¡'\i':":MIII.i"il,"~.''''~¡¡;':~'I¡I''''¡1i11<l~II~~\t!),,~~\,,~~f"rI-J.~'\ - 1 Color: (' ~ DATE By CK APP' D~PllON REV DAlE BY f a< APP ø 8/13/ØI RLS CC ( ( -}~ .~ ~~ø . '/¥fl N~ '28 c:;:::, 27 V...t NOTE S: ,~ ~ ~\ ~ ~ ~ ~ /\ 0 3 ~ -'- tV 31 32 33 V\..J 34 1. COORDINATES SHOWN ARE ALASKA STATE PLANE' T 1 ~ \fTlrT1; ~;:> QO Y ZONE 4, NAD 27. T 90 N "~~\ &.\ \1' " 3. ALL DISTANCES ARE TRUE. I> () o"J ': ~.... CJ ~ 1:::)12 -" - () 4. ICE PAD ]S ROTATED 70. EAST FROM NORTH. 7'~1 .2 7. 9 ~ Bø'Q :,.I~ø '2 5. VERTICAL DATUM IS ASSUMED. ~. v - OJ> ' ,a "" ~ .. (') ~ ø, ." Q\:j' ~ ~, " N 0 \ 18,~ ~~ 0\ ¡,o, '. ~5. 1 4 ~ 13 0 ."', I> \ ~ l \ 0 Q, n - L -)~ 1)( N qO~TA¿UR'~~0~ 2 g . \1" ..~ ~ -? p 23. '. 14 ~' t9cP~ eo I 22 2~ 24 ~Q" I \1> . C \ <:I ' ". . 2£& ciS" ~ . ~ ~. ~ 28 ~TA'~ ~I . , 28 26 J~/ ,. \~~ V'\ A ~J T:" ~ ~.. "J . ,cG ,. I:' ~ .,,- or' .~~~ 0 36 --;;- Jri ~~~ 34 ~ ~ "., li¿>:Þ ~ / ¡VICINITY MAP SCALE: 1" = 2 MILES \ \ ~ ~ ALTAMURA No.1 ~ \ ~ 0 LOCA TED WI1HIN PROTRACTED SEC. 30. T 9 N. & R 2 Eo UMIAT MER[DIAN. ~ 331' F.S:L, 2?58' ~;W.L. D.O.F. (t~) LA T = 70°Ø5 57.57 LONG = 151'43'45.40" Y = 5.888,899.1 X = 284,418.4 DESCRJPl10N SCALE: 1" = 20Ø' . \ ..... ~ ALTAM~RA :; /r I I .fÇ L ~ ~ to OJ ÌJ"\ ) r- Anadarko S Petroleum Corporation CADD F1LE NO. DRAWING NO: LK601D432 08/13/01 AL TAMURA NO 1 DRILL RIG, WELL PAD CONFIGURATION AND SPILL TRAJECTORY NSK 6,Ø1-d432 SHEET: 1 OF 1 REV: ø , ~ (' 1 Dike Dike ' . P' Reserve fJ' ~ Pit ~ ' . 80.0' ,6.0' I'V' 6.0'. ??S' ,~181.0' , I 1 Ice PoJdt is> Rig PoJd:-" ~ Ice Pad ,-r'_U0.'L - - - Tundæ. - -- - - - - - - - - - - -"'.:- - -- - - - - - - -.1 Tundra TYPICAL CROSS SECTION (N.T.S.) , ' Dike 1 Dike , (:J' Reserve Q' Pit CJ.l . . l' - 237.0' ' - 6.0,16O,O'", 7 6.0' I' 95.0'. 11 1 ø' Kig Pad ,ès T Ice Pad .1 . , . '0,5' --r----fundra-------~---------~ndra-----~1-- ., ,TYPICAL CROSS SECTION (N.T.S,) ( Total Capacity = 441800 cubic feet Free Board == 2 feet ' 'Usable Storage Volume = 19,200 cubic feet A 80.0' Reserve' Pit .. , 160.Ø' v TYPICAL RESERVE PIT (N.T.S.) . Pkm View Ana r 0 a p'etroleum Corporation . CADD FJLE NO, I DRA'NING NO: LK601D429 8/01/01 - ~~SK 6.01 - d429 3.0' t f ) RESERVE PIT PLAN AND PROFILE PERMIT EXHIBIT I SHEET: I REv: 1 OF 1 ø Revision 0: 13 August 2001 ~ 0 1000 I I I I I \ Iset 16" @ 80' I 2000 Altamura # 1 Days vs Depth 3000 Set 9-5/8" @ 3,000' 4000 5000 g \ 0 ::E 6000 I .c .... Q. CÞ 0 7000 ( 8000 set 7" @ 8,430' 9000 10000 11000 12000 0 5 ~! Potrc>loum COfpOta t¡Qi~ core @+/- 8,475'-8,595' I set 4-1/2" @ 10,003' 10 15 Days from Spud 20 I Run 3 1/2 Completion I 25 30 AItamura Drilling Pro~. dm NPRA Alaska 2001-2002 Drilling Season ~t Petroleum CorporatlOi' ( ( AItamura #1 Drilling Procedure ( 1. MIRU Nabors rig 14E. 2. Install Slip-Lock starting flange on the pre-set conductor. y/ 3. N/U diverter sys and test per AOGCC and BLM requirements. 4. MfU 12-Y.4" BHA and MWD/LWD tools. / 5. Dri1112-Y.4" surface hole to +/-3,000' MD. Wiper trip as necessary. Circulate and condition hole for 9- 5/8" casing. TOOH, L/D BHA. /" 6. RIU casing tools and run 9-5/8" casing and accessories per casing program. Thread lock float equipment and Istjt above float equipment Verify circulation through float equipment 7. M/U casing mandrel, landing joint, and stack centralizer. 8. Circulate and condition hole for cementing. 9. RID cementing equipment. Test lines to 3,000 psi. 10. Cement 9-5/8" casing per program. Slowly reciprocate the casing with 10' to 15' strokes if possible. Land casing. Check floats. RD cement equipment. Drain conductor. 11. WOC. 12. Back out 9-5/8" landing joint, N/D Diverter and remove Slip-Lock starting flange. Prep and install 9- 5/8" x II" ~ multi-bowL ./ 13. N/U BOP's. Test per AOGCC and BLM requirements. Pick up and stand back enough 4" DP to drill to TD. /,-, 14. Install wear bushing. MU 8-~" BHA and test. TIH to TOC. Test casing to 3,000 psi. 15. Drill out ßoatequipment and 20' ofn~w formation. Circulate and condition mud for FIT test. 16. Perform FIT test to 13.5 ppg EMW. v<" 17. Drill to +/- 8,350' TVD. Perform wiper trips as needed. Reference mud program for mud weight and properties. 7" casing point is projected to be 8,430' TVD. DriH ahead slowly, circulating up samples as needed. Note: Casing point of this hole section is critic;t1 Confirm shoe depth with town. 18. Circwate and condition mud for casing. TOOH. LO BHA. 19. RIU casing tools and run 7" casing and accessories per casing program. Pull wear bushing and install 7" rams in the top gat,e BOP.. Test accordingly. Thread-lock 60at equipment and Istjt above float equipment. Verify circulation through float equipment. 20. MlU casing mandrel, landing joint and stack centralizer. 21. Circulate and condition hole for cementing. 22. RJU 'cementing equipment Test lines to 5,000 psi. 23. Cement 7" casing per program. Slowly reciprocate the casing 10' to IS' strokes if possible. Land casing. Test floats. Drain stack. RID cement equip and back out landing joint. 24. Run pack off assembly. Change out the 7" rams for variables and test accordingly. Install wear bushing. 25. MlU 6-1/8" rotary BHA. Use mill tooth rock bit per recommendation for better samples. TIH to TOC. /"- 26. Test casing to 4,000 psi./" Perform LOT on 7" x 9-5/8" annulus. Freeze protect 7" x 9-5/8" annulus by bullheading 2,700 gals of diesel into annulus. 27. Drill out tloat equipment and 20~ of new formation. Circulate and condition mud for FIT test. 28. Perform FIT test to 13.5 ppg EMW./ 29. Drill ahead looking for core point. Reduce mud weight per program. Circulate up samples as necessary. Confirm core point with town. 30. Circulate and condition as necessary and TOOH for coring tools.. 31. M/U coring BHA. TIH and 'cut core per procedure. TOOHand LID core balTel. Confirm recovery and w/o orders ftorn town. 32. M/U 6-1/8" BHA C/W PD0it and test. TIH and ream/log over core interval. 33. Drill to +/- 10,003' TVD. Confirm TD and if electric line logs are necessary. Short trip, circulate and condition. TOOH for liner. ( - I - " Altamura Drilling Prog. dffi NPRA Alaska 2001-2002 Drilling Season ~! PetrOleum COI'OOt'atlon t' / 34. R/U casing tools and run 4-1,6" liner and accessories per program. Allow for 150-200 ft of liner lap. Notel: RA pip to be run below liner hanger assy. Record exact distance ftom pip to landing area at top of PBR. Note2: RWI short joint approximately 100 ft below pay zone. 35. MIU liner hanger assembly. 36. TIH with liner and DP to liner setting depth. Circulate and condition for cement. 37. RID cementing equipment. Plan to reciprocate liner during job. Cement liner per recommendation. Set liner hanger per procedure. Note: Contact town ASAP if returns are lost during job and/or cement is not circulated out after cement job. Do not set ZXP packer WItil approved by town. Sting out of liner hanger~ stand back 2 stands and reverse out cement. TOOH. 38. MID liner clean-out BHA. ¥H. 39. TEST liner top to 4,000 psi. 40. Clean out 4-1,6" liner to PBTD. Do not drill out float equip. Circ clean. ./ 41. Pump Hi-Vis sweep and displace well with inhibited, kill w4 6% KCL packer fluid. Test casing to 4,000 psi. TOOH laying own DP. Circulate briefly while pulling through liner hanger assembly and PBR. 42. MOVE TO COMPLETION PROCEDURE ( -2- Altamura DrillingProJ'. ..m NPRA Alaska 2001-2002 Drilling Season ...........~ PetrOleWTI Corpor3tJOn ~," Altamura #1 Completion Procedure 1. RIU ELU. RIH wI Gamma ray and CCL and log across short joint, pay zone and RA pip below liner hanger assy. Confinn exact distance from pay zone to RA pip. POOH and RID ELU. 2. MlU perforating gun and spacer assembly per procedure and TIH. 3. M/U gun drop and seal assemblies and TIH. Prep to run the electric cable for the Promore gauges. 4. M/U Promore gauges and remainder of 3-~" tubing string per procedure and TIH. Prep to run control line for the SCSSV and injection sub. 5. Circulate very slowly while the seal assembly is approaching the PBR. A circulating pressure increase indicates that the seals are entering the PBR Note: the peñorating guns have a back up firing head that is set at approximately 4,000 psi! Be extremely careful not to trap any pressure in the tubing. 6. P/U and space out to land 10M lbs down weight on PBR MIU tubing hanger and landing joint. M/U TIW valve and pump-in sub. Lower tubing assembly until mandrel is just above the BOP stack. 7. RID pump truck and nitrogen equipment Pump 3,300 gals diesel down tubing. Immediately start displacing the tubing with nitrogen until 58 bbls ofKCL water is recovered from returns. 8. Sting seals into PBR. ~d tubing and lock down mandrel. Bleed nitrogen off tubing. 9. Test annulus to 4,000 psi. Remove landing joint 10. Instan BPV in tubing hanger. 11. NID BOP's and NIU THA and tree. Test wellhead equip per procedure. 12. RDMO Nabors 14E. ( ( - 1- ( Pot'ole~,..n COtpetltkK'II (" 20" Hole B/ Pennafrost @ 620' 12-1/4" Hole ¡Note: All depths are estimated lin I measured depths from RKB ( Altamura # 1 NPRA - North Slope, Alaska Planned Well bore Sketch Projected TOC is 100' above FC Slumps @ 6,30S' .// 8-1/2" Hole ( "\ 6-1/S" Hole L (" Rig: S: Nabors 14-E GR: I T: I KB: R: 16", 65ppf, H-40 @ SO' Cmt to surf ~ z - ,// _--TAM port collar @ 900' (contingençy) 'V" . -- SCSSV clw 2.81 X-nip @ 1000' '1.'/ Injection sub @ 1,093' ¿, ~ 9-5/S", 40ppf, L-80, BTC @ 3,000' Cmt to surf J -"""'"'' Side Pocket Mandrel @ +/- 3200' -'.-,---- 3 1/2, 9.3 ppf, EUE Srd-mod, L-80 tubing ë:'ii J~ Side Pocket Mandrel @ +1- S,030' ] ~ Pressure Gauge Mandrels@ S,154', 8,092' 1 y:::¡: if;:'!:.',. Baker BX 2.750 X'N-nip@8,216' I ~: ;'i ~,~ 0 ~ :~:;:I, - Promolle Surface Read Out Pressure Guag,es @ 8,247' '-- i~f,',; ~;;,,~: Baker 7x4112 Lnr Hngr clw ZXP Packer and 10' PBR @ 8,27S' o.!1!ff1!r,.,',:,;:I;:,::,,:,., 2 7/8" Seal Extension, flow sub, and GDAlWLEG r\i'& 7" , 26ppf, L-80, BTC-mod @ +J.- 8,430' I$'\~'{ 1'1, :: 60' perfs @ +/- 8,505' - S,565' (TCP- dropped) ..... -:-::-=-; /' ¡j¡jj Dropped TCP perf gun .'.., ~ 4-1/2", 12.60ppf, L-80, IBT-mod, Liner @ 10,003' \..DIVERTER HEAD ASSY.16 SLIP-LOC BTI.I W, FS SEALS X 21-"~ 2K ~~~~'r:!~1 Z- LP OUTLET .. ~ 1 15.0. 1381.0 nvn) 80.41' (2043.9 mm) 43.31' 11100.1 minI 28.31' 1719.1 mm} 8.S9" t217.3 1\11111 26.44. [671.6 IDIIII 51.18' 11467.6 mm) 22.15' (511.6 mml f 9.13' 1231.9 IM'II DIVERTER HEAD " -""' t . 3 "8-5000 \0100 120 GV 3 1'8-5000 110-;) 120 GV WI ACTUATOR 3 "8-5000 UOO 120 GV , 9.50" 1241"ì mOIl 3 1/8-5<100 (R-3S1 10 LOCKOOWN SCREWS 10 LOCKJ)()WN SCREWS 21.18' 1538.0 INÑ 25.0 4_00' 1101.6 nvn) 0 0 I'J 0 F14~ ~ REF. 0000DII1023235 - ~:=M 0 OOCODNI027368 -J ~~;~.;¡¡¡. THROuGH BORE WEL.LHUD ~.,. lJJ æ:=~ær:t&-~ 11-5000 COUP"LETION .=a = ~ OJ ~.-==r-=.;::-:--- 16 x ~ X" x 3'12 ==----= , --- (}) $=.~~ CASING PROGRAI.I --::.. OOIDlI073862 I'J ANADARKO ~ 11-5000 THROUGH BORE SYSTEM l'X 9&/8 X 7X 11/2 '-- 0 11. A . 1000 . 2000. . 3000. ... / 4000. . 5000 g c ,- ~ 6000 .s::. - a. ~ ... 7000 . 8000 - , 9000 .- 10000 . 11000 .------ 12000 - 8.0 10.0 11.0 9.0 ..- ---Planned Mud Wt ',,-/ A ,"'- -. .-- .1& "" rtIl.Ci'llUlø. Tr ; 12.0 13.0 14.0 15.0 16.0 17.0 18.0 ..u... '.'-:-L..1L ,___, muu .:~IYIn. \i"PY --- Est Frac Gradient --Ir- Est Pore Pressure -"-~ ~ 1000 2000 3000 - 4000 Ê a i:: 5000 1: Q. Q) a 6000, 7000 8000 9000 - ---- 10000 8.0 --~ ~~ Offset Well Data Mud Weight vs Depth 0 118 : ..., ..... ~ . . ..... ,.. \ I] Ï~ \1 :::»£= . x x .n . 9.0 10.0 11.0 Mud Weight (ppg) -+-- Rendezv0us#2 --- Lookout #1 --- Rendezvous-A- ----- Nanuk #3 Clover-A- -t- NigIiq #1 .,,<-~/ ~i ~'r~urrl Cof~ 12.0 13.0 14.0 ----*- Moose's Tooth -SparK #1 S:\Alaska\Dri iii ng\WeI I Info Days vs Depth.xls Offset MW vs Depth --- ---.../ Altamura Shallow Gas Hazard Evaluation '---- Stratigraphy and Log Indicators: In this area, the interval from zero to approximately 4,000' Measured Depth (MD) consists of sands and shales from the Brookian Megasequence. They were deposited at a very low angle and have since undergone very little deformation.. Correlation and mapping of markers within this interval in ne-arby wells indicate that there will be less than 100' MD difference between the proposed wells and the Phillips Alaska Rendezvous #2 (See 6, T9N R2E) which is less than 6 mi from the proposed locations. In the Rendezvous #2 well, base of permafrost is at approximately 600'MÐ. From 600' MD to 2,250' MD, sands are less electrically resistive than the surrounding shales and only methane gas is detected in the mudstream. These are interpreted to be / water-wet sands with some biogenic gas present. The potential exists for natural gas ./ hydrates to be stable at these depths and temperatures; however; there have been no unusual conditions or problems in nearby wells. From 2,250'MD to 3,000' MD, the sands are less electrically resistive than the surrounding shales and only methane and ethane (C1 & C2) gases are dete-eted in the mud stream . These are interpreted to be water-wet sands with some biogenic gas and thermogenic gas present in small percentages. No significant problems or conditions were encountered in nearby wells. -- From 3,000' MD to 4,150' MD the sands gradually transition to being more electrically resistive than the surrounding shales, and density porosity in excess of200...lo is recorded. These sands are interpreted to be water-wet in the upper depths (note sands at 3,050' and 3,335') but increasing in hydrocarbon saturation with depth. The sand at 3,900' MD has a poor oil show. No significant problems or conditions were encountered in nearby wens. Seismic Indicators: RAP (relative amplitude preserved) processed seismic lines highlight areas of anomalously high amplitude, which could be an indication of natural gas drilling hazards. Eleven (11) 2-D RAP seismic lines in close proximity to the proposed wells were used for this evaluation (Figure 1). One (1) 2-D line (line 27-74) runs within 200 feet of proposed location Altamura 2. Proposed location AItamura 1 is 2,870 feet ftom the closest 2-Dseismic line (line NPR96-14). 2-D seismic data (rather than 3-D data) were utilized as the primary evaluation tool because they contain the most near-offset information to provide a more accurate image of the shallow depths that are the focus of '''-r ".-" this evaluation. Also, RAP-processed data were readily available. Conventionally processed 3-D data is~ however ~ available over the proposed locations, and both full- offset and near-offset migrated stack volumes were examined. No anomalously bright amplitudes were observed at the proposed well locations and no other indirect indications of shallow gas (velocity sags, "chimneys," frequency shadow, etc.) were noted. Amplitude minima and maxima were highlighted on each 2-D line. Anomalously high amplitude minima were flagged as indications of potential drilling hazards and their two- way travel times (TWf) were recorded. The TWTs were converted to an equivalent depth using a time to depth function from the nearest well, the Phillips Alaska Rendezvous 2, which is less than 6 miles away in Sec 6, T9N R2E (Figure 1). This time to depth function is a result of a Vertical Seismic Profile survey conducted 21 April, 2001. Five (5) seismic lines exhibited areas of anomalous amplitude: NPR95-06, NPR96-14, NPR95-10, NPR95-19, and 29-74. Snapshots of these areas are include-d in Figures 2 - 6. The largest anomalous event appears on two tie lines (NPR95-19 and 29-74). All other anomalies are only observed on single seismic lines, as shown in Figure 1. Interpretation of the seismic data suggests very low potential for drilling hazards at proposed locations Altamura 1 and Altamura 2, as the nearest anomalies to the west are fairly small and do not appear to extend eastward onto line 27-74 or the eastern part of 1ine NPR96-14. Summary: 500'MD -2,400' MD Potential for Natural Gas Hydrates. Low Potential for significant accumulation/drilling hazard 2,150'MÐ-2,900'MÐ Water wet sands ,vith very low potential for natural gas drilling hazard 2,900'MD-4,200'MD Partially to fully hydrocarbon charged porous sands. Low potential for natural gas drilling hazard (1) ~ ""d v I TWT E 127 iê~ e~ ~ 190 S 112 200 210 96 220 ~ 230 ) C/'J 80 240 250 ;j 260 0 64 270 ?-""4 280 ~ 48 290 S I 300 32 310 0 320 § 330 16 340 350 ~ 0 360 0 370 -16 380 rfJ 390 ~ 400 (j,) -32 410 ~ 420 .48 430 4-1 440 -- 450 0 I -64 460 ~ i 470 -80 480 ) ~ 490 . -,...4 -96 500 :> - 510 ~ -112 - - 520 - 530 .?1'00 ~ l!5r1 / ~J ~ ff ~/ \ \ ! -128 - - 549 .. ~ Q) HRZ:(174,QO,S48,SQ) jd_-..rd fd.lheUowhuerd ~ :::$ öJJ . -,...4 0' 4000' 8000' ~ 5íI5iiiI ,. . .tOOO rMl ~ t ) ,II - "-/ Figure 2: Anomalous amplitudes and approximate depths '..~ 'Ji"¡.I~!~~!$" , ..' ,L_'=' >1:: '0 ~ '-=o,..~ 'Š" . " ,I;' ,~,', ]'.h'i:..,> Q ::a J :,:,=< ~' i::!::::J::-.:;::;:::.:::::;.~.=::.::...--..... ~'- '.. J / r I ~ ~ 8-CO) C2Ji) D "', ~ - '-'" "c- Figure 3: Anomalous amplitudes and approximate depths -- ,Š" I': II <:!~ 'J' jii' ~}ðÞo- fgtc M;- ,If' ~. ~; , '¡'-y,,::;~¡;", ,.,.:-:::::-=.::;----:::::-...:::::;;.:;;;::. ~ '/ ~ I ~ ~ 8{C;) CSnJ 0 "', ~) - ~--' Figure 4: Anomalous amplitudes and approximate depths - II'f~;/!f.il ~ ,.. š" 'f ~ ' l .C) L".~ 'm 1..:&,' fi,'ê g" $ g' ;;"., t~~t,-~.._,~ . I ~ ~ I ~ Cð ~ @JïJ .0 (c J) ~ -~ -- ~ Figure 5: Anomalous amplitude and approximate depth '~- ,1~ljf!JIJI :L :æ ", J! I :/ r= I ~ ~ 8-Cë3) C?¿]U 0 ", 8-Cë3) ~ š'. ,:s', '(tj' m ':i' '~: ~ 8- : ..J~- ~."""""'--"""""""---- ~~----.....,,--._- ¡ ----- Figure 6: Anomalous amplitude and approximate depth ~ ~ '. 'l!f~!I<lt ,5":" , - .i)II'~'l ß (3(0) D ~ ~~ i.. ~~, ~I~ ~é' ..~, ¡W' ~i1 ~Z f~~ :S'.". ~. --' "'- Formation Intee;rity Test (FIT) and Leak-Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as fol1ows: . Formation Integrity Test (FI'!) - Formation is tested to a pre-determined equivalent mud weight. Leak-Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first oc-eurs is the lemc-offpoint. LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined ttom previous experience with formation breakdown problems by attempting higher leak -offs. Open Role LOTs (OR LOTs)- Leak-off tests performed with open hole ttom the casing shoe to some point above the target reservoir. Generally done when lemc-offis required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is re-quired of being able to achieve estimated mud weight. . . . "- Procedure for FIT: / 1. Drill 20' of ~ew hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. PIU into the shoe. 3. Close the blowout preventer (ram or annular)/ 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already sho~ plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in I-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a ,veIL the formation below the surface shoe is taken to leak-off This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak-off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open-hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. '- --- Altamura #1 .~~ Maximum Anticipated Surface Pressures The following presents data used for calculation of maximum anticipated surface pressures (MASP) during drilling for the Altamura # 1 well: Casing Pore Casing Setting Fracture Pressure Pore MASP Size Depth Gradient Gradient Pressure Drilling (in.) (ft TVD RKB) (lbs/gal) (lbs/ gal) fuW (W} 16" 80' 11.0 8.3 35 963 9-5/8" 3,000' 14.8 8.3 i ,294 1,980 / T' 8,430' 17.6 8.8 3,858 3,481 4-1/2" 10,003' 17.6 8.8 4,577 NíA Procedure for Calculating Maximum Anticipated Surface Pressure (MASP) 1. Drilling Below Conductor Casing -~~ MASP while drilling below the 16" conductor shoe will be the formation pore pressure (less a full gas column to the surface) at the next (9-5/8") casing shoe. Based on offset well dat(4 the highest formation pressure expected in the 12-1/4" hole section is 1,294 psi at the 9-5/8" casing setting depth of 3,000' TVD (or 0.431 psilft). Complete evacuation of the wellbore, except for a 0.11 psilft gas gradient, is assumed. MASP Calculation for Drilling 12-1/4" hole section MASP (pore pressure) (3,000 ft)(0.431 - 0.11) = 963 psi y" Thus, MASP in the 12-1/4" hole section is below the diverter's 2,000 psi rated working pressure. 2. Drilling Bclow Surface Casing MASP while drilling below the 9-5/8" casing shoe ",ill be the lesser of the formation pore pressure (less a full gas column to the surface) at the next (7") casing shoe or the formation ftacture pressure at the last (9-5/8") casing shoe, less a full gas column to the surface. Based on offset well data, the highest formation pressure expected in the 8-1/2" hole section is 3,858 psi at the 7" casing setting depth of 8,430' TVD (or 0.458 psÿft) and the formation ftacture pressure at the 9-5/8" shoe depth of3,000' TVD is a minimum of 14.8 ppg EMW (0.770 psÿft). Complete evacuation of the wellbore, except for a 0.11 psilft gas gradient, is assumed. -' >- MASP Calculations for Drilling 8-1/2" hole section MASP (pore pressure) (8~430 ft)(O.458 - 0.11) = 2,934 psi MASP (fin breakdown) (3,000 ft)(0.770 - 0.11) = 1,980 psi .,r/ Therefore, MASP in the 8-1/2" hole section is 1,980 psi. It is planned to routinely test the BOPE to 5,000 psi. 3. Drillin~ Below Intermediate Casin~ MASP while drilling below the 7" casing shoe will be the lesser of the formation pore pressure (less a full gas column to the surface) at TD or the fonnation fracture pressure at the last (7") casing shoe, less a full gas column to the surface. Based on offset well data, the highest formation pressure expected in the 6-1/8" hole section is 4,577 psi at the TD of 10,003' TVD (or 0.458 psvft) and the formation Hacture pressure at the T' shoe depth of 8,430' TVD is a minimum of 17.6 ppg EMW (0.915 psi/ft). Complete evacuation of the wellbore, except for a 0.11 psvft gas gradient, is assumed. MASP Calculations for Drilling 6-1/8" hole section MASP (pore pressure) - (10,003 ft)(0.458 - 0.11) = 3,481 psi ,./'/ MASP (fin breakdown) (8,430 ft)(0.915 - 0.11) = 6,786 psi Therefore, MASP in the 6-1/8" hole section is 3,481 psi. It is planned to routinely test the BOPE to 5,000 psi. Altamura #1 Casine: Properties and Desie:n Casing Performance Properties Internal Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD rvm Design Safety Factor* (in. ) (lb/ft) Grade Cnxn ~ ~ (LOOOlbs) (ft RKB) (ft RKB) T B C 16 65 H-40 N/A 80 80 9-5/8 40 L-80 BTC 5,750 3,090 947 916 3,000 3,000 8.97 2.90 2.39 / 7 26 L-80 BTC-Mod 7,240 5,410 641 604 8,430 8,430 3.22 2.08 1.40 / 4-1/2 12.6 L-80 IBT -Mod 8,430 7,500 209 209 10,003 10,003 11.19 1. 84 1.64 * Tensile design safety tàctors are calculated using pipe weight less buoyancy. Burst design safety factors for 9-5/8" and 7" casing are calculated using ASP calculations. Safety factor for 4-1/2" liner is calculated using TD formation pressure with no formation backup pressure at TOL. Collapse design safety factors are calculated assuming conlplete evacuation of the casing. ç~sÎIlg Setting Depth Rat.ional~ ( 7" 8,430' TVD,:MD Conductor casing to support unconsolidated surface deposits and provide initial hole stability. Surface casing to provide sufficient ftacture gradient and well control until TD is reached. The BOP stack will be installed on this casing. Intermediate casing to provide hole stability and pressure integrity during drilling of the final portion of the well. Production liner to provide hole stability and pressure integrity during well testing operations. 16" 80' TVD, 'MD 9-5/8" 3,000' TVD, :MD 4-1/2" 10,003' TVD, MD ~ BOP Control System The BOPE control system on Nabors Rig #14-E is an NL Koomey Model 40200-3S blowout preventer control unit with a 202-gallon volume tanle Main energy is provided by a 40 HP electric motor driven triplex plunger pump rated at 20.2 gpm at 3,000 psi. The pump charges twenty (20) eleven-gallon bladder-type separator accumulators. A second energy charging system consists of two Model 31-00103 air pumps rated at a combined volume of 11.0 gpm at 1,200 psi, or 7.2 gpm at 3,000 psi. The above two energy systems are backed up by six 220 cubic foot nitrogen bottles connected to the manifold system All of the systems are controlled by a Model SU2KB7 series manifold with seven manual control stations at the unit. ( ~-'--r+-,r--.~~--- ~~nv'-----''-----'.--.---:-1~' I-:- ~ I' \ Q ð 0 D g D "[~Î~ r' lid h':iI1 . \, I . 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VAtV£' ANSI JOO Fwa:s ,( & lGØ'-ø"1f . == è= I ~ " r::::: [I ¡r-i~M ~ ...... - " / '"b.Jf H:\ACADFILE\14E\ANADARKO-2001\14EOO03,DWG. 11/28/01 04:14:36 PM 19JUN01 D JA CONVERTED DRAWING TO HAD FORMAT 24FE899 C PM Ie ~Ut, I!fUCI\ItJI tMANCH tHOM '150EC92 8 PM ~/1&L, APØtU IIIW«;H IU IIlYtKltJ( 19NOV92 A PM D(YAfltll,:íI'OOL AND /CtLCJCAIW PAA DRAWING 004,0115 DIllE 'IfK.'''' APU' DESCRIPnON PIICoJ!CT mu: 1\I:è~~~~"~$L~0I' flltNabonAlc8ø ~~l8c A= ~~I~J& AfMIOII_a...r MohoraQ8. Alollko 119503-285 907-283-8000 NABORS ALASKA RIG 14£ Df'ÆRTER LINE LAYOUT 16" DIVERTF:R SYSTF:M DfWIN J8f AlSTON I CItw<w B'I' - N'PRO'ÆD III' - II!.V' 0 SCAtj/32"./'-O" II/IT19 JUN£ 2001 cwo. NO. '4eOOOJ $I/I'{ of (' ~ ::::- d¡ i i I i ¡ i i i ¡ 3/a'r--------------------------------- (g: I ~ gJ . ClAMP CONNECTOR 2'.'/a' C! =>. SINGLE 4 1/2" x 7" VARIABLE RAM 3/B.l ------------------------------- ~ I I I ~. ClAMP CONNECTOR r 3" 5000# "~KVALVE I I L 2' ; 1/a' 3" 5000/1 GATE VI>J..Vf. l ~ I=>' SHEAR RAMS 3/a' ! --~~~~-~_~~_~AL~~_-+--t--,~ (0 I I I oí . C~MP C~NNECTORV r- -t~ÇJ ~ J I 1 I ~ ~ ÇJ :.,., , 3 5000" HCR VAL. E 1'10 3/8"2" KILL UNE~I~~-- ,--~I~ 3" CHOKE UNE 3/s"r--------------------------I---/ ~ I ~ '\:: 3" 50001 GATE VALVE . 2 9/16" x 2 1/16" ADAPTER FLAN~.-- 0 J I L 0 CLAMP CONNECTOR 3 1/16" x 2 9/16" ADAPTER FLANGE ~ ' ~ ~!' (, 1/S" ~ II ~ SINGLE 3 1/2" x 6" VARAIBLE RAM ~ I , 3/S"r-------------------------------- (g I gJ . CLAMP CONNECTOR l' 4~ I I 1---- t I I I I I ~--I--~ I I I ~-¡--~~----- . I I I I - 13 5/8" 5000# HYDRfL ANNULAR BOP 4' 3 7/S" ~ ~ ADAPTER SPOOL HUB x FLANGE BOP STACK ELEVATION HMCADFILE\ 14E\ 14E-AOGCC\BOP-14E-ANADARKO.DWG, 11/28/01 04: 19:04 PM 11/27/01 A J.A. ROD K. cREATED FOR RIO 14~ ANARDARKO PROJECT MlE ~ T '1{' OESCRlP11OII PROJECT mu: ( < { ~~~~~~~wlW=smOF ~ßI~ ft,..hor'J IJafIm =roS ~ Drilling Inc. 11'1 ANUCIII"""c... ~~~~:.:ollf« 99503 NABORS ALASKA RIG 1 4E BOP STACK DRAWN B1' J.A. CHEdŒD B'1' R.K. ,.lPPRfNED IJ1 R.K. ¡REV. A SCALE NTS DAT~ NOV 01 IMII. NO. 14eOOO9 S~, of 1 Client: Anadarko Well: Altamura #1 String: 9-5/8 District: AAK Country: USA Loadcase: 9-5/8 Surface Casing (a) "- '--"'" SiI.berger Fluid Description: 9-5/8" Surface Casing Mud DESIGN Fluid No: 1 Rhea. Model At temp- : BINGHAM : 80 degF Density Pv : 9.50 Ib/ga! : 15.000 cP Tv : 15.00 Ibf/10Oft2 Gel Strength: (1bf/100ft2) MUD Mud Type: WBM Water Type: Fresh VOLUME FRACTION Solids : 7.0 % Oil :4.0% Water : 89.0 % Job volume: 221.4 bbl Tail Slurry DESIGN Fluid No: 3 Rhea. Model At temp. : BINGHAM : 75 degF Density : 15.80 Ib/gal Pv : 35.700 cP T y : 56.20 Ibf/100ft2 Gel Strength: (!bf/100ft2) "~ DESIGN BLEND Name : G Dry Density: 199.77IbIft3 Sack Weight: 94 Ib BASE FLUID Type: Fresh water SLURRY Mix Fluid: 5.098 gallsk / Yield : 1.17 ft3lsk .r Porosity: 58.2 % Job volume: 70.8 bbl Quantity: 339.60 sk Density: 8.32 Ib/gal Base Fluid: 5.098 gaf/sk Additives Code 0065 0046 S001 Cone. 0.300 %BVVOC 0.200 %ß\NOC 1.500 %BWOC Function DISPERSANT ANTI FOAM ACCELERATOR Thickening Time Compressive Strength Schedule ( ) Schedule (Bc) at (hr:mn) at ~~ Page 4 Altamura #Lcfw ; 01-09-2002; LoadCase 9.5/8 Surfac-e Casing (aì; Version wcs-c-em43_62 Client . Anadarko Well' Aitamura #1 String: 9-5/8 District : AAK Country: USA Loadcase: 9-5/8 Surface Casing (a) .~ Fluid No: 4 Rheo. Model At temp. : BiNGHAM : 80 degF Fluid No: 5 Rhea. Model At temp. : BiNGHAM : 75 degF DESIGN BLEND Name : G Dry Density: 199.77 Iblft3 Sack Weight: 94 Ib BASE FLUID Type : Fresh water Additives Code 0124 0053 S001 0046 0079 0044 0065 Cone. 50.000 %BWOC 30.000 %BWOC 1.500 %BVVOC 0.600 %BVVOC 1.500 %B\NOC 9.000 %BVVOW 0.500 %BWOC Thickening Time Com pressive Strength Fluid No: 6 Rhea. Model At temp. : NEWTONIAN : (degF) --- ~ -.....--- ScllllRltIger MUDPUSH XL DESIGN Density : 10,20 Iblgal Pv : 20.028 cP Ty : 18.00 Ibf/100ft2 Gel Strength: 20.28IbfI1{){)ff,2 Job volume : 50.0 bbl ASL Lead DESIGN Density : 10.70 Ib/gal Pv : 1.000 cP T y : 0.00 Ibf/100ft2 Gel Strength' SLURRY Mix Fluid: 20.722 gaVsk - Yield: 4.45 ft3/sk .,/ Porosity: 62.3 % Job volume: 256.2 bbl Quantity: 323.62 sk Density: 8.32 Ib/gal Base Fluid: 20.153 galfsk Function EXTENDER THIXOTROP. ACCELERATOR ANTI FOAM EXTENDER ACCELERATOR DISPERSANT Schedule Schedule 70 Be at at 06:00 hr:mn CW100 DESIGN Density : 8.50 Ib/gal Viscosity: 5.000 cP Gel Strength. Job volume: 50.0 bbl Altamura #Lcfw ; 01-09-2002; LoadCase 9-5/8 Suïfac-e Casing (a) ; Version wcs-œm43_62 Page 5 Client : Anadarko Well . Altamura #1 String: 7 District: AAK Country: USA Loadcase: 7 Intermediate (a) '"--,, -' Scillnllepgep Fluid Description: 7" Intermediate Casing Mud DESIGN Fluid No: 1 Rhea. Model At temp. : SINGHAM : 110 degF Density : 11.50 Ib/gal Pv : 15.000 cP Tv : 15.00 Ibf/10Dra Gel Strength: (lbf/100ft2) MUD Mud Type: WBM Water Type: Fresh VOLUME FRACTtON Solids : 7.0 % Oil :4.0% Water : 89.0 % Job volume: 319.5 bbl CW100 DESIGN Fluid No: 2 Rheo. Model At temp. Density : 8.32 Ib/gal : NEWTONIAN : 110degF Viscositý : 5.000 cP Ge! Strength: (lbf/10Qff.2) Job volume: 60.0 bbl MUDPUSH XL DESIGN Fluid No: 3 Rhea. Model At temp. : BINGHAM : 110 degF Density Pv : 12.50 Ib/ga! : 30.000 cP Ty : 25.00 tbf/100ft.2 Gel Strength: 20.28Ibf/100ft.2 Job volume: 40.0 bbl "c_~ Page 4 Altamura #1.cfw ; 01-09-2002; LoadCase 7 Intermediate (a) ; Version wcs-ceìï143_62 Client : Anadarko Well : Altamura #1 String : 7 District: AAK Country: USA Loadcase: 7 Intermediate (a) ~--- Fluid No: 4 Rhea. Model At temp. : BINGHAM : 110 degF DESIGN BLEND Name : G Dry Density: 199.77IbIft3 Sack Weight: 94 Ib BASE FLUID Type : Fresh water Additives Code 0065 0800 0046 Cone. 0.300 %BWOC 0.190 %BWOC 0.200 %BWOC Thickening Time Com pressive Strength -- '-"" Intt Tail DESIGN " ---' Sållllberger Density : 15.80 Ibfgal Pv : 20.500 cP Ty : 7.60 Ibfl100ft2 Get Strength: (lbf/100ft2) SLURRY Mix Fluid: 5.101 gaVsk ./ Yield : 1.16 ft3lsk -/ Porosity: 58.8 % Job volume: 86.9 bbl Quantity: 420.81 sk Base Fluid: 5.101 gal/sk at at 03:35 hr:mn Density: 8.32Ib/gal Function DISPERSANT RETARDER ANTI FOAM Schedule 26 Schedule 748c Altamura #1.cfw ; 01-09-2002; LoadCase 7 Intermediate {a); Versìûn wcs-cem43_62 Page 5 Client: Anadarko Well : Altamura #1 String : 4.1/2 District 'MK Country: USA Loadcase: 4-1/2 in liner (a) ""-- c_'~-,,' ScbllDlJIgep Flu id Description: 4-1 í2" Production Liner Mud DESIGN Fluid No: 1 Rhea. Model At temp. : BINGHAM : 145 degF Density : 9.20 !b/gal Pv : 15.000 cP Ty : 15.00 Ibf/100ft2 Gel Strength: (!bf/100ft2) MUD Mud Type: WBM Water Type: Fresh VOLUME FRACTION Solids : 7.0 % Oil :4.0% Water: 89.0 % Job volume : 151.5bbl CW100 DESIGN Fluid No: 2 Rhea. Model At temp. Density : 8.32 !blgal : NEWTONIAN : 145 degF Viscosity Gel Strength : 5.000 cP : (lbf!100ft2) Job volume: 40.0 bbJ MUDPUSH XL DESIGN Fluid No: 3 Rhea. Model At temp. : BINGHAM : 145 degF Density Pv : 11.00 Iblga! : 30.000 cP Ty : 25.00 Ibf/100ft2 Gel Strength: 20.28Ibf!100ft2 Job volume : 40.0 bbl -"-~ Page 4 Mamura #1.cfw ; 01-09-2002; LüadCase 4---1/2 in Lineï (a) ; Veïsiün wcs-cem43_62 Client: Anadarko Well . Altamura #1 String : 4-1/2 District: AAK Country: USA Loadcase: 4-1/2 in Liner (a) Fluid No: 6 Rheo. Model At temp. : BINGHAM : (degF) DESIGN BLEND Name : G Dry Density: 199.77IbIft3 Sack Weight: 94 Ib BASE FLUID Type' : Fresh water Thickening Time Compressive Strength .~ '-- Lite CRETE DESIGN '~ Scilllllepgep Density : 12.00 Ib/gal Pv : 60.000 c-P T¡ : 10.00 Ibf/100ft2 Gel Strength' SLURRY Mix Fluid: 8.060 gallsk ./ Yield : 2.39 ft3lsk v Porosity: 45.2 % Job volume: 50.0 bbI Quantity: 117.59 sk Density: 8.321b/ga! Base Fluid: 8.060 ga!lsk Schedule 4G 1 Schedule 74Bc Altamura #1.cfw: 01-09-2002: LoadCase4-1/2 ¡n Liner (a); Version wcs-cem43_62 at 04:15 hr:mn at Page 5 Altamura Drilling Program NPRA Alaska 2001-2002 Drilling Season ~_/ '<-~ 'c.."".... Drilling Fluids Program General Discussion: A 6% KCl/Polymer Mud will be used to drill this well Horn spud to TD. This inhibitive mud will reduce dilution rates and the subsequent drilling waste while providing maximum wellbore stability. This mud system has evolved over the last to drilling seasons in the NPRA and has been recognized for success in both of these areas. However, it is a very «fine" line between running this mud system with minimum dilution rates to reduce drilling waste while maintaining a quality mud system for good hole cleaning support and effective wellbore stability and to enhance the overall drilling operations. Please refèr to the Mud Program for specific details concerning this mud system. SUl!l!ested Mud Properties Surface Hole (12 W' Hole fISpud to 9 5/8" Casing Point at 3000' TMD): Mud Density (ppg) Viscosity yp PV 10 S. Gel API FL (cc'sf30 Properties (seclqt) min) Initial 10.0 80 - 100 35 - 45 13 - 21 10-15 <15 Base PF 10.0 50 - 70 20 - 30 15 - 23 10-15 6-10 Final 10-10.2 "/ 50 - 70 15 - 25 15 - 23 10 - 15 6-8 Comments: This interval of the well will be drilled with a 10.0 ppg KClIPolymer mud Horn spud to TD. Primaty focus for this interval of the well will include basic hole cleaning support for the large diameter drilling (12 W' hole) and close attention for the possibility of shallow gas. (See Mud Program for details.) Intermediate Hole (8 Yz" Hole fIBase Suñace Casing to top "Slump" at 6408' TMD): API FL Mud Properties Density (ppg) yp PV 10 S. Gel CI (cc' sf3 0 PH min) Initial 9.5 10-15 6-12 2-5 27- 6-10 9-9.5 32K Final 9.5 '/ 15-25 8-14 2-6 27- <6 9-9.5 32K Comments: The mud fÌ'om surface hole drilling operations will be conditioned and used to drill ahead in this interval of the well. The mud should be «cleaned-up" prior to drilling out of the surfàce casing to optimize drilling conditions in the initial 8 W' hole. While drilling the 8 Yz" hole, the mud should be kept in good conditions so as to be receptive the mud weight increase which will be required beginning at the top of the "Slumps". (See Mud Program for details.) Intermediate Hole (8 Yz" Hole f/Top "Slumps" to 7" Casing Point at 8430' TMD): HTHP API FL Mud Properties Density (ppg) YP PV 10 S. Gel (cc'sf30 CI (cc'sf30 PH min) min) Top "Slumps" 9.5-12.0 15-25 15-25 5-10 <10 27- <6 9-9.5 to HRZ 32K Top HRZ to 8 11-12 / 15-25 15-25 5-10 <10 27- <6 9-9.5 Y2"TD 32K Comments: The mud weight will be increased fÌ'om 9.5 ppg to 11-12 ppg while drilling Hom the top of the "Slumps" to the top of the HRZ (7520' TMD). The mud weight will then be maintained at that elevated level while drilling to the final 8 W' TD at 8300'. (See Mud Program for details.) Production Interval (6 118" Hole fI7" Casing Point to the Final WeD TD at 10,003' TMD): HTHP API FL Mud Properties Density (ppg) YP PV 10 S. Gel (cc'S/30 CI (cc'sf30 PH orin) min) fiT' Casing to 9.5-1O* ~' 15-25 10-20 5-10 <10 27- <6 9-9.5 Well TD 32K Comments: If no "special" drill-in/coring fluid is needed for this interval of the well, this interval will be drilled with "conditioned" mud Hom the preceding interval of the well. The mud weight will be reduced as allowed to the 9.5-10.0 ppg range. * - The reduced mud weight for this interval of the well is based on the assumption that the 7" casing effectively isolates the troublesome shales above the target sands behind casing. Altamura Drilling Prograln "'-' NPRA Alaska 2001-2002 Drilling Season <-..,.' -~ Anadarko Petroleum Corporation AItamura No.1 Mud Program General Discussion: This exploration well will be drilled from an ice pad in the northeastern NPRA. The well will be drilled as a straight hole and spudded with a 12 ~" bit and drilled to a surface hole TD of @3°00' TMD where 9 5/8" casing will be run and cemented. An 8 ~" intermediate hole will then be drilled to @8,430 TMD where 7" casing will be run and"cemented. A 6 1/8" hole will then be drilled/cored to TD @ 10,003' TMD where a 4 ~" liner may be run and cemented. / ¿' Spud the well with an inhibited 6% KCl/PHP AlClayseal mud weighted to 10.0 ppg per the current trend f/NPRA drilling. The mud weight will then be held at that 10.0 ppg mud weight to the surface hole TD unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. This spud mud is formulated with several mechanisms to provide effective weIlbore stabilization and to reduce drilling waste, i.e., ionic inhibition (KCI), polymer encapsulation (pHP A) and anionic bonding (Clayseal). ' For the 8 ~" intermediate hole, the continued use of the inhibited KCI mud is suggested with again the primary focus being to provide effective wellbore stabilization and the reduction of drilling waste. The top-set casing program as planned for this well, is designed to better isolate the target sands to avoid the lost circulation/differential sticking problems which have been associated with previous long-string casing designs. (Note: As the current 7" casing point is above the Jurassic age .-c formations, there is the possibility that the higher mud weights of the 8 ~"hole (11.0+ Ppg) will be required for effective shale stabilization in the 6 118" "tail" section of the weD.) When drilling this interval of the well a certain amount of new mud will be required for whole mud replacement to keep the low gravity solids content within acceptable limits. The mud weight for this interval of the well will range :trom 9.5 to 12.0 ppg~The use of the 7" as an intermediate casing string also offers the possible use of annular injection as a disposal mechanism for drilling waste (mud and cuttings). To enhance the potential, a ball-mill should be considered to slurry the cuttings for annular injection. For the 6 1/8" tail section of the well, two drilling mud alternatives are possible. First, one could drill ahead with the inhibited mud from the 8 ~" interval of the well, OR as an alternative based upon the coring interests, a custom core fluid could be used. Obviously, the continuation of the KCI mud from the 8 ~" hole would offer a significant economic advantage as well as being a very good drilling fluid for this interval of the well. However, if specific coring objectives dictate the use of a "bland" core fluid with specific bridging capabilities to minimize invasion, then a custom core fluid should be considered and is the base case for this mud program. As for the mud weight for this interval of the ,ell, if the T' casing effectively isolates the troublesome shales behind the casing, a reduced mud weight of 9.5-10.0 ppg may be used to drill/core this interval. However, as indicated above, the mud weight for this interval of the well may continue to be in the II.O+ppg range if the 7" casing does not cover all the troublesome shales above the target sands. Special Considerations: * Maintain a sufficient quantity ofDriltreat (lecithin) to accomplish a 2 ppb treatment in the event gas hydrates are noted. * Lime and zinc carbonate should be on location for H2S contingency (@I pallet No Sulf and 2 pallets lime). * Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@1000 sxs barite on location at all times). * Due to the remote nature of this location, maintain an adequate supply of LCM and the other mud additives, which may be required to support this drilling program. * To reduce the potential for hole erosion/wellbore de-stabilization, hold the jet velocity below 200 ips and minimize ECD "drive" when drilling the 8 ~" and 6 1/8" intervals of the wen. * Possible shale instability issues in the "Slumps"/Jurassic interval of the well (tight filtrate control/mud weight). Altamura Drilling P,'ogram '- NPRA Alaska 2001-2002 Drilling Season -' P~ttOI:6Um çt<"1'~Jfati~l -- * Possible lost circulation problems in target sands with the elevated mud weights that are often required in this area for shale stabilization. .. .-. Altamura Drilling Progranl '~ NPRA Alaska 2001-2002 Drilling Season .~ ~a ~ðtf&,{jt~1 CÜf~~t¡ôt, Formation Tops/Casine Proeram: Condition mud for casing (ppg)* Mud Wt 10.0 10.0 10.0 10.0 9.5 9.5 10.9 11.3 11.3 9.5 9.5 9.5 9.5 Spud Base PermafTost K3 Marker 9 5/8" Casing Point B/Brookian Sands T/F.C. Slumps B/F.C. Slumps HRZ 7" Casing Point Top Jurassic Nuiqsut "A" J-3 Well TD TVD/TMD 0' 620' 2870 ' 3000' 3960' 6408' 7313' 7411 ' 8430' 8480' 8653' 9803' 10,003' Comments 10.0 ppg density Possible gas hydrates Begin mud weight increase 11.3+ ppg mud/Baranex treatment Condition mud f/casing Possible shale problems Condition/displace f/coring Condition mud f/liner . - Based upon an effective 7" top-set which allows a reduced mud weight in the 6 1/8" hole. Surface Interval (12 ~" Hole to 3.000' TMD): The surface interval of this well will be drilled with a 6% KCl/PHP AlClayseal spud mud as formulated below: ] Oppg Formulation Water KCI EZ Mud DP Clayseal Dextrid Barazan-D KOH Aldacide-G Baroid .905 bbl 21.61bs (30K ppm chlorides) .75 lbs .84 gal 3lbs ] -2 lbs .llbs .2lbs @74.5 lbs (API filtrate of6-12 cc's) (as required for an initial 35 YP) (pH = 8.5-9) (X-Cide 207 for rig maintenance) (10.0 ppg) Spud the well with maximum flow rates to ensure good cuttings transport. Target an initial yP in the 35 range then adjust as dictated by the actual hole cleaning requirements of the well (no gravel is anticipated - mostly clays and sand). Reduce viscosity as allowed (previous wells in the area have TD'ed the surface with a ~25 YP). However, if hole cleaning appears to / be inadequate, do not hesitate to quickly raise the viscosity as required. Polymer viscosity in the form ofBarazan-D additions./ should be utilized to provide rheological support as needed. Utilize high viscosity sweeps to supplement the hole cleaning capabilities of the system. Spud the well with a 10.0 ppg density mud and hold that mud weight unless dictated by actual hole conditions. * Make sure all members of the drilling team are aware of the potential of encountering gas hydrates. * If gas hydrates are encountered, close monitoring of the system volumes and mud properties at the flow-line by rig crew members and mud engineers is of critical importance. * Frequent checks of fluid density at the suction pit are critical to ensure that gas is not re-circulated down the well. * A mud weight of 10.0 ppg range is currently programmed for drilling the gas hydrate interval of the well, if encountered. * As lower viscosities are predicted due to the absence of gravel, gas break-out should be enhanced. .. 1_- Altanlura Drilling Prograln .",-/ NPRA Alaska 2001-2002 Drilling Season '.~ ~lfot€Hlf11 COt~fatìrn"" "-~..:- * If gas hydrates are noted, treat the system with 2.0 ppb ofDriltreat (Lecithin) and ~% by volume Dril-N-Slide. (The mud engineers who are working the Milne Point operations have reported that the addition of the Drill-N-Slide acts as a mud conditioner that facilitates the breakout of the gas from the mud and helps keep the mud on the shaker screens.) * Maintain the mud as cool as possible. Hydrates that have been studied at the Cascade Project in the Milne area appear to be / more stable at temperatures under 60°F. Efforts to keep the fluid cool include mudding up with cold water and diluting the mud with cold water. The Baroid mud plant in Prudhoe Bay can be utilized to supply the initial volume of fluid for the spud. Make every effort to maintain the system as clean as possible through the normal dilution process and maximization of solids control equipment utilization. Other mud maintenance issues are as follows: 1. If possible, use 6% KCI water to maintain volume while drilling ahead. Maintain the mud chlorides at @30,000 ppm with KCI 2. Use Dextrid and PAC's for API filtration control. Target 6-12 cc's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface hole TD. 3. Hold the pH in the 8.5-9 range with KOH. 4. By material balance, maintain the Clayseal concentration in the 2% by volume range. 5. By material balance, maintain the EZ Mud DP in the .75 ppb range. /' 6. Keep penetration rates below 150'!hr for controlling the clay "chunks" as seen on some wells in the area. 7. Daily additions ofX-Cide 207 are needed to control bacterial action. 8. Corrosion inhibitors should be run with this mud system (Baracor 700 / Barascav D). 9. Keep MBT <11 ppb. Heavy amounts of clay may be present below the permafrost that could require additions of ConDet and Dril-N-Slide to reduce BHA baIling and screen blinding. Sweeping the hole with high viscosity sweeps prior to the short trip at TD and again prior to coming out of the hole to run the surface casing is recommended. If possible, reduce the fluids rheology to <20 yP after the casing is on bottom prior to starting the cement job (dilution can be used as a lower weight will be desired to drill the initial 8 ~" hole). Surface Hole Mud Properties (12 ~" Hole fISpud to 9 5/8" Casing Point at 3000' TMD): Mud Density Viscosity yP PV 10 S. Gel API FL Properties (ppg) (sec/qt) (cc's/30 min) Initial 10.0 80 - 100 35 - 45 13 - 21 10 -15 <15 BasePF 10.0 150-70 20-30 15-23 10-15 6-10 Final 10-10.2 v- 50-70 15-25 15-23 10-15 6-8 Intermediate Interval (8 ~" Hole to ~8430' TMD): (Drill-out to top "Slump") Prior to drilling out the surface casing water back/centrifuge the spud mud to 9.5 ppg. Ensure the chlorides are in the 30K ppm range. Maintaining the chlorides in this range will reduce dilution rates and ease the displacement to the 6% KCl, coring fluid ifused :~r Initially, target a mud density of 9.5-9.6 ppg and a yP of the fluid in the 10 to 20 range and maintain until out of the sticky clays usually found below the casing seat. Then, adjust yP as required with Barazan-D polymer as needed for efficient hole cleaning. If screen blinding ITom heavy clays is a problem, use ConDet and Dril-N-Slide treatments. Once through the sticky .. '_1 Altamura DrillingProgram'-- NPRA Alaska 2001-2002 Drilling Season -~ Pf;rrD1wÜ~T] CfXpQfaf~ clays, adjust the yP up to the 15-25 range with Barazan-D to ensure good hole cleaning support. Regular sweeping of the hole with high viscosity sweeps is recommended every 4-6 hours while drilling to supplement the hole cleaning ability of the fluid. Flow rates of 400-450 GPM will provide annular velocities of 200-225'/m,Jn (5" pipe / 8 1/2" hole) which should suffice in this near vertical hole. All personnel should be aware of the possibility of encountering unexpected pressure. Close monitoring of return mud weights, pit volumes, and the flow-line flow meter are 7 utmost importance at all times and will give warning of changing pressures. Maintain ample stocks of barite on location. Maintain the mud as clean as possible through the use of solids control equipment and dilution as required. Maintain the API filtrate <6 with PAC/Dextrid. Maintain the chlorides in the 27,000-32,000 range with KCI. Daily additions ofX-Cide 207 should be made to control bacterial action. KOH should be used for pH control. Keep MBT <11 ppb. Intermediate Hole (8 ~" Hole fIBase Surface Casing to top "Slump" at 6408' TMD): ) Mud Density API FL yP PV 10 S. Gel CI (cc' s!3 0 PH Properties (ppg) min) Initial 9.5 10-15 6-12 2-5 27- 6-10 9-9.5 32K Final 9.5 15-25 8-14 2-6 27- <6 9-9.5 32K (Top of "Slumps" to 7" Casing Point) As has been seen of several of the off-set wells, the mud may need to be weighted-up (to 11.0+ ppg) prior to entering the "Slump/Disturbed" zone for effective wellbore stabilization. However, for tIlls mud program, begin increasing the mud weight at the top of the "Slump" fÌ"om the 9.5-9.6 density of the upper 8 ~"hole to 11.3 ppg by the top of the HRZ at 7411'. Weight-up as required using barite down to the top of the HRZ.. The"HTHP should also be lowered to <10 cc before entering the HRZ. Maintain this tight filtration to TD of the interval with N-Dril HT and Baranex. A 2 ppb treatment with Soltex will be made once the weight-up is complete and the HfHP has been reduced to the targeted value. Keep low gravity drilled solids to a minimum «6% by volume if possible). Maintain the MBT at <11 ppb through dilution. Maintain the pH between 9.0-9.5 with KOH. Daily additions ofX-Cide 207 should be made to control bacterial action. The chloride level should be kept in the 27-32K range through additions ofKCI. The Clayseal and EZ Mud concentrations will be maintained at their respective programmed concentrations. A 20-25 yP should be maintained using N- VisIBarazan D. Special efforts should be made to keep ECD's and surge/swab pressures to a minimum to reduce damage to the exposed shales. In past drilling in this area, the targeted 11.3+ ppg mud weight should give @ 100 psi differential on the shales which doesn't allow for much swab. Prior to tripping, a 10-12 ppb Barotrol pill should be considered for spotting across the lower shales. The yP of this pill should be raised to the 35 range with N- Vis/Barazan-D. Short trip the well and condition the mud as needed prior to the TOOH to run and cement the 7" casing. After running the casing, condition the mud as needed (YP <20 if possible) prior to beginning the cement job. Intermediate Hole (8 ~" Hole f/Top "Slumps" to 7" Casing Point at 8430' TMD): Mud Density HTHP API FL yP PV 10 S. Gel (ce'S/30 CI (ce' s/30 PH Properties (ppg) min) min) Top j 27- 9-9.5 -~- "Slumps" 9.5-12.0 15-25 15-25 5-10 <10 32 <6 to HRZ K Altamura Drilling Program '- NPRA Alaska 2001-2002 Drilling Season "-' - 6 _J1 P~t(ûï~jrf) CvtfJOf~J¡ûf~ Top HRZ to 11-12 8 ~" TD 15-25 15-25 5-10 <10 27- 32 <6 K 9-9.5 ProductionlCorin~ Interval (61/8" Hole to 10,003' TMD): For this interval of the well, two options are possible. One option, would be to clean-up the current mud system and drill ahead to TO with re-conditioned mud fTom the 8 ~" hole reducing the mud weight as allowed (to 9.5 ppg ifpossible). This would certainly be the most cost effective option and the 6% KCI fluid design should be well suited for the drilling of this interval of the well. For this option, the mud would be maintained in the same manner as fTom the preceding interval of the well targeting basically the same mud properties with the exception of the mud weight which can hopefully be reduced to the 9.5-10.0 ppg range. For this option, the basic mud properties would be as follows: Production Interval (6 1/8" Hole fl7" Casing Point to the Final Well TD at 10,003' TMD): Mud Density HTHP API FL yP PV 10 S. Gel (cc' s/3 0 CI (cc's/30 PH Properties (ppg) min) min) fl7" Casing 27- 9.5-10* 15-25 1 0-20 5-10 <10 32 <6 9-9.5 to Well TD K The second option would be dictated by the need for a low-invasion "bland" core fluid if the well is to be cored. This special core fluid is outlined below and would be displaced into the well after as successful drill-out to include a satisfactory LOT/FIT. In this situation, kick-off the cement plug with the used KCI polymer system. The system should be maintained within the parameters set forth in the "Slump" to 7" casing point section of this program. Once core point is reached, the hole should be swept with weightedlhigh vis sweeps to remove cuttings. Short trip, then displace to the core fluid before tripping out for the core barrels. / The core fluid formulation is as follows: 1 Barrel (9.5-12.0 ppg) 6% KCl Core Fluid Soda Ash .1 ppb Aldacide G .25 ppb (X -Cide 207 for rig maintenance) Aquagel 5 ppb Dextrid 8 ppb PAC L 1.75 ppb N-Vis .5-.75 ppb (as required for a 15-25 YP) KCl 19.5 ppb Baracarb 36.25 ppb ( 12 ppb of5,12 ppb of25, 12.25 ppb of 50) KOH as needed for an 8.0 pH. Baroid as needed Target Properties Density HTHP (200 deg. F) yp PH 9.5-12.0 ppg or as required. <7.5 cc's 15-25 Ibs/lOO sq. ft. 7.5-8.5 / Displace the used KCl polymer mud with the new core fluid as follows: L__~' 1. Reduce the yield point of the KCI polymer mud to the 12-15 range on this final circulation and prepare the rig pit system to receive the coring fluid fTom the Baroid mud plant and to build the low viscosity and high viscosity spacers. Dump and clean the rig pits and flush all pumps, solids control equipment, and lines with ftesh water and discard this water. It is very .. .-- Altamura Drilling Program <°- NPRA Alaska 2001-2002 Drilling Season ~ ~tr~um C~Xm!Uñ important to get everything extremely clean and dry before bringing the core fluid into the pits. Take the coring fluid into the pits and proceed with the displacement. 2. Pump a 30 barrel low viscosity sweep consisting of mud from the previous section which has had the yP reduced to the 6 to 9 range through additions of Therma- Thin/SAPP and dilution. This spacer should be weighted to the equivalent mud weight as the base mud. 3. Pump a 30 barrel freshwater high viscosity spacer consisting ofN- Vis mixed to a yP of 45 to 65 ( approximately 2.5 ppb N- Vis) and weighted to the equivalent density of the base mud with Baroid. Manipulation of the pH to ensure proper polymer dispersion and hydration along with slow mixing of the polymer will prevent the formation of polymer fish eyes. 4. Once the high viscosity spacer is away, begin displacing with the coring fluid. Pump at rates of no less than 230 gpm, which should allow for efficient displacement. The drill string should be rotated while displacing to disturb any solids. Once displacement has started, the pumps should remain on until clean returns are seen. 5. Ensure the bit is on bottom as the new fluid exits the drill string. 6. Monitor the flow line for break through of the spacers and the new coring fluid. Discard the low viscosity and high viscosity spacers as they will be contaminated with unwanted drilled solids and cuttings which would compromise the integrity of the coring system. 7. Pull inside the casing and clean the possum bellies, under the shakers, and any pits which were taking the dirty returns. Mud maintenance while coring should focus on the following: 1. Maintain mud weight at as needed with Baracarb 50lbarite (50/50 ratio). Target 34 ppb of Baracarb(s) and run tourly CaC03 checks to keep this amount in the mud. 2. If liquid additions are required, add 6% KCI brine or new 6% KCI Core Fluid. Do not add ftesh water. Do not add any mud additives outside those in the base mud formulation without approval from the operator. Maintain the mud salinity at 27-32K ppm. 3. Control API filtrate and HTHP filtrate with Dextrid/P AC L additions. 4. Use N- Vis as required to adjust yP for good hole cleaning. 5. The pH should remain in the 7.5-8.5 range. 6. Continue with aggressive X-Cide 207 treatments to control bacterial activity. 7. Dry jobs should be mixed using Baracarb 50. After the coring work is complete, the core fluid can be treated as required to TD the well and in preparation for the various end-of well activities, i.e., logging, running liners, etc. These treatments may include but are not limited to CausticIKOH for pH control (8.0-9.0 target range), Th erm a- Thin and/or Desco CF to control mud rheology, high vis/high fiber sweeps to assist hole cleaning, barite for slugs, Baranex, etc. Condition the mud as allowed prior to the TOH to run the 4 ~" liner. The yP should be reduced to the 10-15 range with the liner on bottom prior to beginning the cement job. ".....,.- ( . .J . It .. .. .. DERRICK 20 CONE DESJLTER ~ ~ B-1 1-- Y - - - '0; -" I~ .1. .....:~,-" I ~ ~ iii -...... ~ MOD, 2000 I . a .. 1~EA. 1m. '00 QF J f\ f\ ^ f\ f\J\ ^f\f\ f\f\ f\ f\~,~ f\ f\f\f\f\ f\ f\ f\f\ f\ f\f\r..f\f\f\ f\1l MJŒR COMÐt.W el : ':rOM ' ~ I ;- - . '..-~ ~ ~ ~. " ~ iWDERFlf1I . ~ ã I r9 e;1 ' ;~ EDUCTORJET I ~ I ... 414 II .. . h 'lr.&fn.-. =-' ~ ~ , '. ' "':'" æ= I ::w :: " 1M. ! IIIUD HOPÆRS " - -. ..~" t (H-pþ'ss DnCH, ,Q I T.. ~ ~, ' :---:--,',u;"; .,-,. '"'/" n". '~" .'.' "'!..,.., "'rn;-",.,n~. "'~ I f- ,,¡ I ¡ I r.oQlM I ~ I I ¡ . ¡ . w , ¡'. . " I :Î,_,,~i, !I.~ ~'",~lrWD'~-;;-=I" ~owP" 'l~",r r.1 -r.i~jrl : 'ci,~~z:r "}~. 1 ... , - t. ,n, "': '! -. , ......" -!~: 7' J¡ ¡I ¡:::: :: TANKTAHK &. A t t A ...fð .fð.. .... tJA II 4 "A &. lJA. " 9111.~8BL .. ~~ tJA .. .. w ONLY CHARGE: .&. ØESANDER MIlD CI.fANER .. '~" PUMPS II ".. -. i. PUIIP PIJI.1P 1ALIGtÐ ., '" ~ TAN~ oo::fR", ~~ERR\ -Muþ¡\rA,¡g9~Ptr - ~X~ ~1~~ " ~,o:R: ro HOlE F1/.L . V V tpJ.-F1£J. UHf , V V Plii8IY ~ V. ..,~ II 14 .. . , . . f . : :: & CASING FI.I. LIIÆS t! - ,. ' " . :: " 4 .' '" III OILI(£IJ. A-' 700PT ~ MUD PUIIPS ..~ + CUTTINGS :1:) ... ~ ,~ ~ ' L/N£ 8I./NO 80 .- ~ TANKj , --.---:: 169.0 BBL ..b I!OI.L-FIL /IN£ , . . . . . . i &. ... 1 .... f " II . CRIS,WJJ PfAIJ 'f " ro~ t 1'1 .. ; Øjr, ~D " .a-Itr,lAI~ .. ~ I~ ro~~ g~ ~r " "t l b 'I": ::: (NOÞO .." U~ :: H .\+"\ =--:.G¡ '. ~ ~ ~D JNDErflIJ'f ~COVER& TANK 'tUID TNJ/i IDO BBf. 70 881. /' \ .. L .--.J r i \.. ~ II II> . , . SUCTION It DlSCIWIGE ro i ".. ~=~OR =:~~:O}~~"~~IM" "t NaIaortAladw =-c ~ ~:02~8õ 11'11 ~1IMIOItI--. AnQ/laraal. Ala.ko i8S03-265 0(17-283-8000 ~ NABORS ALASKA RIG 14£ 111\.! MUD SYSTtM SCHÐM TIC 1000 88L AC71'Æ SYSTfM WITH DEWATERING UNIT 0IWiN 8'1' PMIOH!CIŒD 8'r' - ;IPf/fJ/£tJ !II' -11ItV. 8 SCÞJ.E NON£ ~1, JUN£ 2001 D'IIO. Nò, 14e0008 SIIf" OF I H:\ACADFILE\ 14E\ 14E-AOGCC\ 14EOO06,DWG, 11/28/01 04:17:16 PM PM DRAWING 004.0206 '11 NI:1I 01 ø 7CR RME/) H£tfION /'WP /II) DIWIS I1S1IM/) 20 JUN 0' Á 061 Ct.W\£!f1E ) M4W/NG ro HAD FlWl4T ~T£ 'Ir "ð¥' ",. 0ESCRIP110N ~ .. ~ ANADARKO PETROLEUM CORPORATIOI" '.......... 3201 MAIN 907/ 273-6300 ~EET, SUITE 603 . ANCHORAGE, ALASKA 99503 ""..,.., Anad..rIqI~ January 11, 2002 Ms. Cammy Oechsli- Taylor, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 1 4 20D2 Alaska Oil & Gas Cons Comm' . Anchoragë ISSiOn RE: Application for Permit to Drill: Anadarko AItamura #1 Dear Ms. Oechsli- Taylor, Anadarko Petroleum Corporation hereby applies for a Permit to Drill an onshore exploratory well in the NPRA area of the North Slope. The well, called the Altamura # 1, will be located approximately 19 miles ~uthwest of the village ofNuiqsut and 4.7 miles south of Phillips Alaska's Rendezvous #2 well. Anadarko plans to spud Altamura #1 approximately February 15, 2001. Upon receipt of all necessary permits and approvals (including tundra travel authorization), construction equipment will be mobilized to the Altamura #1 location via rolligon and an ice drilling pad built. Meanwhile, an ice road will be constructed from /' Phillips' Rendezvous #2 well site to the Altamura location. The drilling rig, Nabors 14-E, will then be mobilized via rolligon (or truck, if the ice road infrastructure is in place) to the ice pad and the well drilled to TD and tested if log results warrant. The rig will be demobilized via ice road. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill (Public Information) - 1 copy 2) Form 10-401 Application for Permit to Drill- 3 copies 3) Fee of $1 00.00 payable to the State of Alaska 4 ) Well Prognosis and discussion of Operational Considerations 5) Location Plat and Drill Pad Layouts 6) Days vs. Depth Drilling Curve 7) Drilling Procedure 8) Wellbore and Wellhead Schematics 9) Pressure Information including pore pressure, mud weight and £facture gradient curves, offset well mud weight curves, maximum anticipated surface pressure calculations, FIT and LOT procedures, and casing properties and design factors. 10) Diverter, BOP and choke manifold schematics 11) Cement Program 12) Directional Program 13) Drilling Fluid Program - Ms. Cammy Oechsli- Taylor Page 2 / As part of this Application, Anadarko also requests approval for the annular injection of drilling wastes as discussed in the attachments. The AOGCC is requested to keep confidential all information included in the Application for Permit to Drill (except the Public Information copy) as information in these documents is drawn from research and data proprietary to Anadarko. For your information, this permit request is being simultaneously submitted to the U.S. Bureau of Land Management. If you have any questions or require additional information, please contact me at (907) 273-6300 Sincerely, '\ ~ i>\\-_~$ø~ LJUL) Tommy Thompson Drilling Superintendent enclosures ~ - TOMMY W. THOMPSON 4-93 MELISSA K. THOMPSON 3 GREYCREST PL 281-364-8186 THE WOODLANDS, TX 77382 3073 37-65/11192731 Date 14:r~ Z~ Q 2.. ~ I $ (DD- ; :¡ f , 0 ~~~;~~~e A D G ~ ~ ~~ ~~~<:("t-7":,<&, t--Jð¿~~ I~~~~~~!~;~~a~ab ~I~ CÛ~b M' Dollars tð =""= ~ ----- ..._~.......~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITIAL LETTER WELL NAME 4/ k¡j{ur~ #/ CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORAT~ INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL L-)NO AN~~~ ANNULAR DISPOSAL THIS WELL. "CLUE" The permit is for a new wellbore segment of existing well ----' Permit No, ,API No. - ' Production should continue to be reported as a function of the original API number stated above. ' In accordance with ~O AAC 25.005(t), aU records, data and logs acquired for the pilot bole must be clearly , differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logS acquired for well (name on permit). Annular disposal has ~ot been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS L-J YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to tbe spacing exception tbat may occur. C'Ifh44v 4: lIuul ~ð .{. ð~~ ~. ~ c¡f~ ~+CI.L:' .~.þ 7: b . ~- ~I ~V~ Templates are located m driye\ ody\templates ~ p 'I ~ /¿~( WELL PERMIT CHECKLIST COMPANY Anadarko WELL NAME _Altamura #1 PROGRAM: Exp l Dev - Redrll- Serv - Well bore seg - Ann. disposal para req - FIELD & POOL NA INIT CLASS EXPL (WILDCAn GEOLAREA 890 UNIT# NA ON/OFF SHORE ON ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . .~Not required: minor change in total depth and bottom hole location prior to spud 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . âJN ' 3. Unique well name and number. .. . . . . . . . . . . . . . . . C:D@ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y TD and BHL are the only changes to the originally approved Altamura #1 drilling program. 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N ~ DATE - 12. Permit can be issued without administrative approval.. . . . . N 1JJ../ "'j!. Zf1'.D 2---- 3. Can permit be approved before 15-day wait.. . . . . . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . .. ~.. .. N 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . @ N 18. CMT will cover all known productive horizons. . . . . . . . . . @ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . Y N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . Y N 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N 22. Adequate we II bore separation proposed.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N 24. Drilling fluid program schematic & equip list adequate. . . . . Y N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Y N 26. BOPE press rating appropriate; test to psig. Y N 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . Y N 28. Work will occur without operation shutdown. . . . . . . . . . . Y N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y N 30. Permit can be issued w/o hydrogen sulfide measures. . . . . cæ' cß) 31. Data presented on potential overpressure zones *. . . . . . . N * None expected based on offset wells. 32. Seismic analysis of shallow gas zones**. . . . . . . . . . . . N **NothinQ observed in offset wells. No shallow gas indicators were seen in 3D seismic dataset. AP~ DATE, 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . AJfi:x. M 'Scattered bright spots were seen on 2D seismic data, but nothing anomalous wis indicated on 2D ./ J I ') ~. N.D ~4. Contact name/phone for weekly progress reports [exploratory onlyC-) N dat~ within ab~ut 8.000 feet of the A~a~)Jra #1 site. ANNULAR DISPOSAL 35. With proper cementing records, this plan ..J~ R ~~ '~..:'73 -4..'> 3LY-f' (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPC, ..::f-EMm-?7Yl ~l,\ COT SFV~ WGA yJ4/1r DTS 03)01/°2- -J JMH d1\!\ +\- 3( :.51 () é.- APPR DA 1E WGI' -;,q(~n- '~~/f.\ð,;) GEOLOGY APPR DATE ¡?7'~o~ ~/.~ c..- . . i ~<-T7 /r~I->?~~.;.ç as£;i.J.o A ( <).¿L ø vl "ð;' k{ ~ p Y"01Iev/. ( SR.f t9 (i c;~ .I'.'V ( crPf~~ /. Commentsllnstructions: G :\geology\permits\checklist.doc WELL PERMIT CHECKLIST COMPANY Jl;.1.A~L-) WELL NAME Alk~\rr4..rIf1 PROGRAM: Exp ~ Dev - Redrll- Serv - Wellbore seg - Ann. disposal para req- FIELD & POOL NA' INIT CLASS EXPL- (0/L.DCm-) GEOL AREA ~)9/) UNIT# Nil- ON/OFF SHORE DI'1 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . .. ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . .~ / / ~ / J ~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . E¡<ffð/4y'"C7:J ~¡/C1 C4 f 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N J ~ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . .NA~' Vb">-f'Zc ' tLx.¡r 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . 'N 11. Permit can be issued without conservation order. . . . . . . . N APff.13 DATE~D2- 12. Permit ca~ be issued without administrativ~ approval.. . . . . N þ7:> /2.1 13. Can permit be approved before 15-day walt.. . . . . . . . . . Y ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . N v:-.t @ 80' 7 \I Ò . I' /:? 1 .j, --- ,-} /../. / ,./I /J / /" 15. Surface casing protects all known USDWs. . . . . . . . . . . N ~~'fì'r'm¡:.d -ïo:s c...lc,-,'(P¡.ha-x.: .À- .f¿;'~vDv.S. rr. t6~~f. r.1'Z>r~ ...5WG?- 16. CMT vol adequate to ~ir~ulate on ~onductor & surf csg. . . . . N /+:œ1J tv<--1-f R4 Ci'c,). Uv0-.e£.-L l f rf)/2-D P-d , ~~JjJZ( l' G2lJ o;y 17. CMT vol adequate to tie-in long stnng to surf csg. . . . . . . . N 1 ~ :z . ¿ , ó-i- 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N., </ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N AlcJ>ov s ¡ £ 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N N/A 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N ¡...L/A 23. If diverter required, does it meet regulations. . . . . . . . . . N ¡J Io¡. ¡; 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N " . AP~R DAT,E 26. BOPE press rating appropriate; testto 5000 psig. N,uLASP =- 3if-f3t f't. W6A t/41 c' Z 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N )/0' " 28. Work will occur without operation shutdown. . . . . . . . . . . N rrst1!y\ '(,,-0).. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . ~"G>. / _J' - ~ - £ _0 ¿ /', If... // 31. Data presented on potential overpress re nes?t'-...... N 1Vø-: ~ <) '1 ~ tJ''?t ~:Y: .i&-e./(S. '. ' 32. seismiCanaIYSiSOfShaIlOWgaSZone~~ . . . . . . . . . N f:* ~,.«<~ o6S<-r¡;.-/, , , ~J o//J~, ~,~¡t}¡;',fer7() ~O-4~r> A%P. DATE., 33. Seabed condition survey (if off-shore) . . . . . . . . . . . .. A.lA@N :1 e"~k. ~U 31> :5€-1~~, ~"llkf.! .::)C4./-kJ hl,~lr.f 6~ ~ ~ /'2-q"()~4. Contactname/phoneforweeklyprogress~rts[exew~~!o!yonlyj Y N :2-t:> 9-1'ifnt'~ J b:.J..f r¡olÁ.i~<. _~~loû!J. l/.f~/"l/1- CY?1r:z..'D ¿,~,.~. . ~ (6')~t' I~~t-#<- . - X> ttbcv(- " I ~ ¿I!--'- V:;éf-(' ANNULAR DISPOSAL 35. With proper cementing records, this plan -..J 2.73-~~3' &;~ /) ~,~r<.tLr4- ' (A) will contain waste in a suitable receiving zone; . . . . . . . N APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. N to surface; (C) will not impair mechanical integrity 0, f the well used for disposal; fY) N (D) will not damage producing formation or impair recovery from a ~ N pool; and. /£) (E) will not circumvent 20 MC 25.252 or 20 AAC 25.412. '(!J N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPC, TEMh~y? .?--l"t COT SFD ;-.ðÐ WGA WGPr DTS ~ I!> JMH ð1V\ H ¿I 8'1 07~ (' I Commentsllnstructions: G :\geology\permits\checklist.doc 8604.6' June 26, 2002 Anadarko Petroleum Corporation 17001 Northchase Dr. Houston, TX 77060 Attn: Mr. Don Kilgore Final Core Analysis Report Altamura No. 1 North Slope Alaska CPI File No. HOU-020315 Dear Mr. Kilgore Conventional cores from the subject well were retrieved at the wellsite by Core Laboratories personnel. The cores were then shipped to Core Laboratories’ Houston, Texas laboratory where analysis was performed as directed by representatives of Anadarko Petroleum Corporation. The following documentation includes procedures for sample preparation and petrophysical measurements, and the resultant data reported in tabular and graphical formats. We appreciate this opportunity to be of service. If we can be of further assistance, please do not hesitate to contact us. Sincerely, CORE LABORATORIES, INC. Art Curby Core Analysis Manager i SAMPLE PREPARATION & PETROPHYSICAL MEASUREMENTS CORE EXTRUSION: Upon arrival at the lab, the cores were extruded from the aluminum liner sections onto a core layout table. The cores were wiped to remove excess drilling fluid, and labeled with depth marks and orientation stripes. CORE GAMMA: The natural total gamma radiation count of the core was recorded as a function of depth and was recorded in API units of gamma activity. The instrument was calibrated against API standards and adjusted for background. The core gamma log is presented in this report. PLUG DRILLING and TRIMMING: Conventional, Scal and vertical core plugs were drilled at points designated by Anadarko Petroleum Corporation representatives. The plugs were drilled using 4 % KCl brine as the drilling lubricant. The conventional plugs were placed overnight into a low temperature oven @ 150 o F to drive off the water. After the overnight drying plugs were marked and submitted to the cleaning process. Scal and vertical plug samples were faced (1 inch each side from the center point), using a diamond-facing tool to provide right circular cylinders. Trimmed ends and plugs were wrapped in several layers of Saran wrap and stored in a sealed plastic vial. Core sections were removed from the sides of the plugs holes and returned to the state of Alaska. A full inventory of the plugs and the core sections removed is included as an appendix in this report. PLUG CLEANING: The untrimmed conventional samples were batch cleaned of hydrocarbons and salts in a soxhlet extractor. Toluene was used as the refluxing solvent until clear. Samples were placed overnight into a low temperature oven, followed by batch cleaning with chloroform/methanol azeotrope. Extraction was continued until the returning solvent was clear. Samples were dried overnight in a low temperature oven and methanol was used to leach them of salts. Extraction was continued until a test of the returning solvent with AgNO3 solution yielded no precipitate. Solvents were maintained at approximately 150 o F during the extraction process. PLUG DRYING: Cleaned plugs were dried in a low temperature oven for 24 hours. At this point samples were faced using a diamond-facing tool to provide right circular cylinders. A 3/8” section from one end and ¼ ” section from the other end, were trimmed from the plug. End trims and plug samples were loaded into a humidity oven at 140 ºF and 40% relative humidity until weight stabilization was achieved. GRAIN VOLUME: Direct grain volume measurements were made using a helium porosimeter. This instrument utilizes the principle of gas expansion as described by Boyle's Law. The instrument was calibrated daily and test standards were run to verify instrument accuracy. GRAIN DENSITY: Calculated grain density was obtained utilizing grain volume measurements and clean, dry sample weights. Grain density was checked against lithology standards. PLUG DIMENSIONS: Sample lengths and diameters were measured using digital metric calipers. ii CMS-300 PLUG ANALYSIS: A. PERMEABILITY "k": Permeability was measured by flowing helium from a reference cell of known volume through the plug samples. The downstream end of the plug was maintained at atmospheric pressure. The upstream pressure was initially at 240 psig and was allowed to decay through the sample. The pressure decay vs. time was monitored and recorded digitally. The net confining stresses used for this project were 800, 1227, 1654, 2081 and 2510 psig. 1. K-air: Permeability to air at the designated net confining stresses was calculated from time/pressure decay data. 2. K-Klinkenberg: Unsteady state equations were used with time/pressure decay data to calculate the Klinkenberg slip corrected permeability at the designated net confining stresses. B. POROSITY: A reference cell of known volume was initially pressurized with helium to approximately 240 psig. As the pressure was allowed to expand into the core sample, pressure decay was monitored. At pressure equilibrium, Boyle's Law was used to compute pore volume. Pore volume was measured at the designated net confining stress. Porosity was then calculated by using the pore volume from the CMS-300 and the grain volume from the automated porosimeter. The results of the plug analyses and average statistical data are presented in tabular format on pages 1 through 14 of this report. Graphical presentations of Permeability vs. Porosity, histograms of permeability and porosity, and depth plots of permeability, porosity and grain density are included in the Figures section. PROFILE PERMEABILITY: The Pressure - Decay Profile Permeameter was used to measure permeabilities on the top surface of the whole core. Measurements were made at approximately 0.1-ft intervals from 8561.17’ to 8663.25’. The PDPK device measures permeability by flowing nitrogen gas through a portion of the sample. The nitrogen flows from a selected reference volume into the sample through a probe which seats on the sample face using an o-ring seal. The decay of the initial reference cell pressure (approximately 12 psig) was monitored vs. time. The permeability was calculated from the pressure decay/time data. A subset of 15 readings was re-measured on the slabbed surface of the core. The results of the profile permeability are presented in the figure section of this report. CORE SLABBING: A band saw was used to cut the cores into 1/3-2/3 sections (dry cut). The 2/3 section was preserved in Saran wrap (6 layers) and aluminum foil (3-layers). CORE PHOTOGRAPHY: The 1/3 section of the slabbed core was photographed under white light (dry and wet), and U.V. light conditions. A "box" format, which displays an entire slab box in an 8 x 10 photo, was used. Digital files and hard copies containing the core photography images were previously distributed to Anadarko Petroleum Corporation. iii APPENDIX A: EXPLANATION OF CMS-300 TERMS "b", "Beta, and "Alpha" K = Equivalent non-reactive liquid permeability, corrected for gas slippage, mD Kair = Permeability to Air, calculated using K and b, mD b = Klinkenberg slip factor, psi (Beta) = Forcheimer inertial resistance factor, ft-1 (Alpha) = A factor equal to the product of Beta and K. This factor is employed in determining the pore level heterogeneity index, Hi. Hi = log10 (ø/RQI) , microns = 3.238E-9 K Ø = Porosity, fraction RQI = Reservoir Quality Index, microns RQI = 0.0314(K/ø)0.5 For further information please refer to: Jones, S.C.: "Two-Point Determination of Permeability and PV vs. Net Confining Stress" SPE Formation Evaluation (March 1988) 235-241. Jones S.C.: "A Rapid Accurate Unsteady-State Klinkenberg Permeameter," Soc. Pet. Eng. J. (Oct. 1972) 383-397. Jones, S.C.: "Using the Inertial Coefficient, , To Characterize Heterogeneity in Reservoir Rock: SPE 16949 (September 1987). Amaefule, J.O.; Kersey, D.G.; Marschall, D.M.; Powell, J.D.; Valencia, L.E.; Keelan, D.K.: "Reservoir Description: A Practical Synergistic Engineering and Geological Approach Based on Analysis of Core Data,: SPE Technical Conference (Oct. 1988) SPE 18167. iv APPENDIX B: REPORT DISTRIBUTION CORE LABORATORIES, INC. FILE NO. HOU-020315 Altamura – No.1 WELL North Slope, ALASKA FINAL REPORT Anadarko Petroleum Corporation 17001 Northchase Dr. Houston, TX 77060 Attn: Mr. Don Kilgore Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 99503 Attn: Mr. John Hartner Anadarko Petroleum Corporation Altamura No. 1 WELL North Slope Alaska Report No. HOU-020315 Date of Report: June 27, 2002 Table of Contents Discussion Pages i - ii Data Tables Core Analysis Data Pages 1 – 43 Statistical Averages Page 44 Abbreviation Codes Page 45 Figures Permeability vs. Porosity Figures 1-5 Core Gamma Figures 6-7 Probe Permeability Plot Figure 8 Depth Plot Figures 9-10 Permeability & Porosity Histograms Figures 11-15 Appendix A (Explanation of CMS-300 terms) Page 1 Appendix B (Report Distribution) Page 1 Appendix C (Plug & Core Section Inventory) Page 1-10 CD - ROM ( Excel Format ) Includes all data tables, figures, and appendices
