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Home My WebLink About202-129 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/29/10 Inspector: Bob Noble Operator: Marathon Oil Co. Well Name: Abalone 1 • Oper. Rep: Kevin Skiba PTD No.: 202-129 Oper. Phone: 907-283-1371 Location Verified? Yes Oper. Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 03/09/03 Date AOGCC Notified: 09/14/10 • Sundry No.: Well Completion Rpt • Type of Inspection: Initial Wellbore Diagram Avail.? Yes • Well Pressures(psi): Tubing No Tubing Photos Taken? Yes • IA 0 " OA 0 SCANNED AUG 1 42D15 Condition of Wellhead: Well location was verified with the use of a plot plan.The wellhead looked to be in good working condition.The location had a locked - gate.The master valve on the wellhead was locked. Condition of Surrounding Surface The pad looked to be in good condition with clean gravel that had no signs of spills. Location: Follow Up Actions None Needed: Attachments: Photos(3) REVIEWED BY: Insp.Supry J -- Comm PLB 09/2010 2010-0929_Suspend_Abalone-1_bn.xlsx Suspended Well Inspection—Abalone#1 PTD 2021290 Photos by AOGCC Inspector B. Noble 9/29/2010 .T T w t►rM ` A f • .., a Mmi .10,amme ARATHON • .� ABALONE #1 _ r t t;1 PERMIT NO. 202-129 , •1F=,.. API NO. 50-133-20517-00r`' :`k;cso'.•• SURFACE LOCATION: • ''4 +Y,'' , • SE1/4;SW1/4;SEC 29,T2N; R12W SM • _,. / . f.A , AIF'_ s�� +I - r J jok !ilk l;; ? •'Till l , S $ , fit, < A ii-- E . � �� i / %'� A �;/✓7 2010-0929_Suspend_Abalone-l_photos.docx Page 1 of 2 r� • • : z ""w-- • ski • • • 2010-0929_Suspend_Abalone-1_pho to s.do cx Page 2 of 2 ) ) 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, d O~ - L 6l. 1- Well History File Identifier Organizing (done) o Two-sided III" 11111111111111 o Rescan Needed 11111111I1111111111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: NOTES: BY: C . Mari;j Date: J l~ 'of¡ OVERSIZED (Non-Scannable) ~09S of various kinds: LA h.T¡ ÖN ~~ M t'T tAQp ,i \.J~ ¢bther:: 'f" 'i P 6 L..oG- C f I ~... '-) 1M..f) /5/ D Other: Project Proofing BY: CMari~ 1111111111111111111 Date: J / (}.3 O~· t /5/ :!J m Scanning Preparation BY: ~ If) x 30 = "200 + 1 = TOTAL PAGES 307 Date: J /:):i3, 0" (Count does not i~~;ude covér sheet) m P 111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 3 () <6 (Count does include cover sheet) Page Count Matches Number in Scanning prraration: V YES BY: ( Maria) Date: 1/f)3/D0 If NO in stage 1, page(s) discrepancies were found: NO /5/ mp Stage 1 YES NO BY: Maria Date: /5/ 1111I111I1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc Regg, James B (DOA) From: Sulley, Michael B. (MRO) [msulley ©marathonoil.com] Sent: Tuesday, May 22, 2012 11:16 AM 51z51 To: Regg, James B (DOA) Cc: Ellis, Michael (MRO); Hill, Kimberly B. (MRO) Subject: Marathon Oil's Abalone # 1 Attachments: ABA -01 WBD 5- 4- 12.xls Dear Mr. Regg: As requested by your Mr. Maunder, we have installed a Back Pressure Check Valve in the tubing hanger of Marathon Oil's Abalone # 1 well in the Ninilchik Unit (Permit # 202 -129). Further, we have closed the Baker SSSV at 374', Locked Out the well head valves, and secured the location. I am inclosing an updated wellbore schematic and a picture of the well head. .i If I can be of further assistance, please contact me. Respectfully, Mike Sulley 907/394 -1334 ActiMMEDJUN 1 1 • • • Abalone #1 (PTD 2021290) 5/22/2012 Photo courtesy of Marathon Oil Company ti ",+. rrb _.. 1 N O il t : r . w- �, .:. ' 192, r A L . ,,/ � J I ri� . 411,,,,i'i/..-1:11;1111 0p ..- ,F t .:* ,..... F � .t - �.r �',a ,r ,,„ . ., 28 ,r 7-7.,,, — i ti ,' '� ,: > ,rr � Vi ""'.,,,, .. � s t.+ "" f r� � r l � `t l .�� , r /+/ICJ" . 1 / ' ' p1� I �j- ♦ r 1 fi ` i rl#'-. l _ A r e - :- '°" a ,x '�"' r < r� "are _ iK � -,,10......- its -�- am - ' y - . . • Abalone #1 iiiiwif ► perm #: 202 Ninilchik Field Marathon Oil API it: ` 50-133-20517-00-00 250 FSL, 3,000 FEL, Alaska Production LLC_ `Propert\Des ;, Sec. 29, T2N, R12W, SM KB Elevation: 92.36' ' Spud Date: 1/30/2003 Conductor TD well: 2/28/2003 20" K -55 133 ppf PE Rig Released: 3/09/03 © 12:00 hrs i Top Bottom Lae 60 °13' 42.50" North MD 0' 170' Long: 151 24' 2.12" West T VD 0' 170' Surface Casing 13 -3/8" K -55 68 ppf BTC / . k Tog Bottom Vetco 4" BPCV in tubing hanger MD 0' 2,208' Installed 5- 4- 2012 TVD 0' 2,098' 1 7 -1/2" holecmt /w ± 992 sks 12 ppg cmt. Cmt fell. WOC. Pumped top job @ 350' MD Baker TE - SSSV @ 374' MD with 335 sks 15.8 ppg recovering 20 bbls 2.313" ID cement to surface. Inhibited 6% KCL ♦ Tubing String: 2 -7/8" L -80 6.5 ppf 8rd -Mod Tom Bottom MD 0' 3,094' TVD 0' 2,953' lei *Baker SCSSV at 350' Model TE -5 flapper valve „- Sliding Sleeve 3,085' - rmr with 1/4 ", 0.049 ", SS control line 117 *Sliding sleeve at 3085' ID = 2.313" with X- profile Packer Assy: *Baker 3.25" OD seal assembly (2.406' ID) 9 -5/8" Baker Model "D" 3,094' ;: stung into tieback sleeve at 3,094' , 10' Baker Seal Bore 3.25" ID 3,104' .... " I F Intermediate Casing 2.313 X Nipple 3,119' --4 ` 9 - 5/8" 40 ppf L - 80 BTC Top Bottom WEG 3,130' - MD 0' 4,336' TVD 0' 4,194' 12 -1/4" hole cmt /w ±135 sks of 12 ppg & 550 sks of 13.5 ppg Stern rfo „Peratio ' r�' ei ', 3_'t64 3172 " -mi, y 6 spy (11-12.i `^ X 18,', 31.89'= MD TV', 6st5,f {11 d 1)I, ry 3202' 3 MR T. ,' 6 spf {11 fi 12 Class "G" cement: 75 sks 15.8 ppg Top estimated @ 4,233' MD. Bottom estimated @ 4,436' MD. .\„A �' fi Baker Cement Retainer set @ 4,283' MD 1 1 1 01.: -' :.: 4! Open Hole 6 -1/8" ' Tom Bottom MD 4,336' 10,356' TVD 4,194' 10,203' 61/8" hole filled with 9.5 ppg Flo Pro Fresh Water Mud TD PBTD 10,356' MD -4,233' MD 10,203' TVD - 4,091' TVD Well Name & Number: Abalone #1 Lease: Ninilchik Field Municipality: Kenai Peninsula Borough State: Alaska I Country: I USA Perforations (MD): 3,164' - 3,207' Perf (TVD): 3,023' - 3,065' Angle @ KOP & Depth: --3 185 ft @ 555' MD Angle @ Perfs: 27° max @ 1,600' ! 3° at perfs Date Completed: 11/12/2011 Ground Level: 245' (AMSL) 1 RKB:I 21' (AGL) Revised by: Mike Sulley Revision Date: 5/4/2012 Marathon Alaska Production LLC • W WA, Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 6, 2012 Mr. Daniel Seamount Alaska Oil & Gas Conservation Commission NED 333 W 7 Ave Anchorage, Alaska 99501 JAN 1 0 !0177 y!t pp 1 ',make it :1 2sl fi As itl�. PL91�laea�o Reference: 10 -421 Open Flow Potential Test Report r 9-1 Field: Ninilchik Unit Well: Abalone #1 StANNEVIAN LOIL Dear Mr. Seamount, Enclosed is the ABA -1 10 -421 Open Flow Potential Test Report as requirement by the approved 10 -403 sundry #311 -342. ABA -1 was completed into the Sterling formation on November 12, 2011. Efforts to establish gas production from ABA -1 have been unsuccessful to date as is stated on the enclosed 10 -421 form. Please call me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, r o - A 4 4 N 4 1)1 ` 4 Kevin J. Skiba Regulatory Compliance Representative I I Enclosures: 10 -421 Open Flow Potential Test Report cc: Houston Well File Kenai Well File (2) KJS • , • JAN 1 0 2012 STATE OF ALASKA 45 �' ALASKA OIL AND GAS CONSERVATION COMMISSION ° ° �'��° �OITNS�10l� GAS WELL OPEN FLOW POTENTIAL TEST REPORT '` .Drugs la. Test: El Initial ❑ Annual ❑ Special 1b. Type Test: U Stabilized ❑ Non Stabilized ❑ Multipoint ❑ Constant Time ❑ Isochronal ❑ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Marathon Alaska Production LLC 11/12/2011 202 - 129 3. Address: PO Box 1949 6. Date TD Reached: 12. API Number: Kenai Alaska, 99611 -1949 02/28/2003 50- 133 - 20517 -00 -00 4a. Location of Well (Governmental Section): 7. KB Elevation above MSL (feet): 13. Well Name and Number: Surface: 250' FSL, 3,000' FEL, Sec. 29, T2N, R12W, S.M. 21' KB 266' MSL Beaver Creek 16rd Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 495' FNL, 3,109' FEL, Sec. 32, T2N, R12W, S.M. 4,233' MD 4,091' TVD Total Depth: 9. Total Depth (MD + TVD): Ninilchik Field / Sterling Pool 287' FNL, 3,181' FEL, Sec. 32, T2N, R12W, S.M. 10,356' MD 10,203' TVD 4b. Location of Well (State Base Plane Coordinates NAD 27): 10. Land Use Permit: 15. Property Designation: Surface: x- 245,392.0 y- 2,278,133.0 Zone- 4 NA FEE -OSMAR TPI: x- 245,283.0 y- 2,277,385.0 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 245,211.0 y- 2,277,597.0 Zone- 4 Sigle Zone 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 9.625" 40 ppf, L -80 8.835" 4,336' 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 3164'3172', 3182'3189', 3,202' 3207' in MD 2.875" 6.5 ppf, L -80 2.441" 3,130' 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 3,094' - - 0.56 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): Tubing F° psia @ Datum TVDSS 14.73 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N % H Prover: Meter Run: Taps: 3143' MD 3002' TVD 0.56 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F psig F psig F Hr. Size (in.) Size (in.) 1. 3.826 X 1.000 - - - - 2. - - - - 3. - - - - 4. - - - - 5. - - - - Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24 -Hour) hwPm Pm Factor F Factor Q Mcfd Fb or Fp Ft 9 Fpv 1. 2. 3. 4. 5. Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. N/A 2. 3. Critical Pressure 4. Critical Temperature 5. RaDMS JAN 10 2012 Form 10 -421 Revised 7/2009 CONTINUED ON REVERSE S DE Submit in Duplicate r • • • Pc P 0 I Pf pf2 No. Pt pt Pc2 -Pt2 Pw pw Pc2-Pw2 Ps Ps Pe-Ps 1. 0 2. 0 3. 0 4. 0 5. 0 25. AOF (Mcfd) Remarks: No production was not established I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed f) v i \ Ai /&J Title Regulatory Comp. Representative Date 1/6/2012 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 1/Z dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air= 1.000), dimensionless Gg Specific gravity of separator gas (air= 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back Pressure Testing of Gas Wells , Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10 -421 Revised 7/2009 Side 2 • •` Marathon Alaska Production LLC • II ``ii P. Asset Team Marathon Oil P.O. O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 5, 2012 Mr. Daniel Seamount Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 201'; yyyp 94 o.JgIR S�i� 9. Reference: 10 -407 Well Completion Report and Log • Field: Ninilchik Unit Well: Abalone #1 Dear Mr. Seamount, SLANNED 1,R b 7 'NV, Submitted for your records is the Well Completion Report and Log for ABA -1 well. A 2 -7/8" tubing was installed to a setting depth of 3,130' MD. The ABA -1 well was then completed into the Sterling formation. Efforts to produce the Sterling formation were unsuccessful. ABA -1 is presently shut -in awaiting further evaluation of the utility of the Sterling formation at the Abalone location. Please contact me at (907) 283 -1371 if you have any questions or require additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -407 Well Completion Report & Log cc: Houston Well File Well Schematic Kenai Well File Operations Summary (2) KJS STATE OF ALASKA 4 ALASKAIL AND GAS CONSERVATION COMMIS. WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas 0 SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Well Class. 20AAC 25.105 20MC 25.110 Development Exploratory GINJ❑ WINJ ❑ WAG ❑ WDSPL El No. of Completions: 1 Service El Stratigraphic Test 2. Operator Name: Marathon Alaska Production LLC 5. Date Comp., Susp., or 12. Permit to Drill #: 202 - 129 Aband.: 11/12/2011 Sundry #: 311 - 342 3. Address: PO Box 1949 6. Date Spudded: 13. API Number: Kenai Alaska, 99611 -1949 January 30, 2003 50- 133 - 20517 -00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 250' FSL, 3,000' FEL, Sec. 29, T2N, R12W, S.M. February 28, 2003 Abalone #1 Top of Productive Horizon: 8. KB (ft above MSL): 266' 15. Field /Pool(s): 495' FNL, 3,109' FEL, Sec. 32, T2N, R12W, S.M. GL (ft above MSL): 245' Total Depth: 9. Plug Back Depth(MD +TVD): Ninilchik Field / 287' FNL, 3,181' FEL, Sec. 32, T2N, R12W, S.M. 4,233' 4,091' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 245,392 y- 2,278,133 Zone- 4 10,356' 10,203' FEE - OSMAR TPI: x- 245,283 y - 2,277,385 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 245,211 y - 2,277,597 Zone 4 374' 374' NA 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re- drill /Lateral Top Window MD/TVD: 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 133 K -55 21' 170' 21' 170' Driven 13 -3/8" 68 K -55 21' 2,208' 21' 2,098' 17 -1/2" 1,327 sks, Type - /Class - 20 sks 9 -5/8" 40 L -80 21' 4,336' 21' 4,194' 12 -1/4" 685 sks, Class -G - 24. Open to production or injection? Yes 0 No If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) MD TVD Perf Size Number 2 -7/8" 3,130' 3,094' MD 2,953' TVD 3,164'- 3,172' 3,023'- 3,031' 0.36" 6 spf - 3,182'- 3,189' 3,040'- 3,047' 0.36" 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3,202'- 3,207' 3,060'- 3,065' 0.36" 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: No production Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period --► 0 0 70 64/64 100% gas Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate --► 0 0 70 NA 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 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. AN 2 n1? RBDMS JAN 0 9 2012 ssior .41(647, AiZkittl U 6a6 "ns* Form 10 -407 Revised 7/2009 CONTINUED ON REVERSE SUI2p1 It original only 29. GEOLOGIC MARKERS ( List all formations and marker untered ) : 30. FORMATIO STS NAME MD TVD Well tested? Yes U No U If yes ntervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 MC 25.071. Permafrost - Base Sterling 3,071' 2,930' Attempted to flow Sterling formation,"' Beluga 3,240' 3,098' No gas production, bailed 70 bbls of water. Tyonek 6,590' 6,448' Formation at total depth: Tyonek 10,356' 10,203' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283 -1371 Printed Name: Kevin J. Skiba Title: Regulatory Compliance Representative Signature: 4 4 JATkikd CijL Phone: (907) 283 - 1371 Date: January 5, 2012 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 Item 1b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod 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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 in Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: 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 MC 25.071. Item 30: 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 MC 25.071. Form 10 -407 Revised 12/2009 9 *rations Summary Report by Job f) Marathon Oil Well Name: ABALONE 1 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country NINILCHIK - ABALONE ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date Rig Release Date 0.00 282.00 303.00 21.00 1/31/2003 3/7/2003 Daily Operations Report Date: 11/8/2011 Job Category: COMPLETION 24 Hr Summary Pretest casing to 2500 psi. Good test. Start setting matting boards and rigging location. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 09:00 1.00 SAFETY MTG AF Hold perjob safety meeting. Discuss Marathon JSA, Pollard JSA, and ASRC JSA. Issue permit and assign tasks. 09:00 11:00 2.00 RURD OTHR AF RU Pollard test pump to pretest casing. Test lines 250 psi / 3000 psi. 11:00 12:00 1.00 TEST CSG AF Pressure up 9 -5/8" casing to 2500 psi. Casing lost 10 psi in 30 min. 12:00 16:00 4.00 RURD OTHR AF Start spotting pit liner and matting boards. Discuss equipment placement and pipe handling system. 16:00 16:30 0.50 SECURE WELL AF Secure well and location. Lock gate and leave location. Report Date: 11/9/2011 Job Category: COMPLETION 24 Hr Summary Perform official casing test. Pull hanger and run packer. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 08:00 09:00 1.00 PREP LOC AF Meet with ninilchik operators and prepare permit. 09:00 10:00 1.00 SAFETY MTG AF Hold PJSM with crew. Discuss Marathon JSA, ASRC JSA and Pollard JSA. Assign tasks and issue permit. 10:00 13:00 3.00 RURD OTHR AF RU pump and chart recorder. Fill casing with McOH. (22 gal). 13:00 14:00 1.00 TEST CSG AF Pressure up 9 -5/8" casing to 2500 psi and chart results. Pressure dropped from 2525 psi to 2520 psi in 30 min. Matt Herrera of AOGCC witnessed and ,/ approved the test. 14:00 15:30 1.50 RUNPUL TBG AF Remove tubing bonnet and pull hanger and 2 jts 4 -1/2" tubing. LD same. 15:30 16:30 1.00 RUNPUL ELEC AF Run GR / CCL log from 4200' to 2900'. Good tie in to openhole log. 16:30 18:00 1.50 RUNPUL ELEC AF _ Run 9 -5/8" Packer assy. Set packer at 3.094'. WEG is at 3.130'. POH and LD eline. 18:00 18:30 0.50 SECURE WELL AF Secure well and location. Lock gate and leave location. Report Date: 11/10/2011 Job Category: COMPLETION 24 Hr Summary Continue rigging up location. Spot test equipment. Spot pipe handling equipment, tubing, and completion equipment. ' Ops ' Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 08:00 09:00 1.00 PREP LOC AF Meet with Ninilchik operators and fill out permit. Discuss operations. 09:00 10:00 1.00 SAFETY MTG AF Hold Prejob safety meeting. Discuss Marathon JSA, Pollard JSA, Weatherford JSA. Assign tasks and issue permit. • 10:00 14:00 4.00 RURD CSG AF Spot and rigup pipe handling equipment. Spot tubing and completion equipment. Spot cranes for pipe handling and discuss pipe handling. 14:00 17:30 3.50 'RURD OTHR AF Spot test equipment and flare boom. Berm pit liner around test equipment. 17:30 18:00 0.50 SECURE WELL AF Secure well and location. Lock gate and leave location. Report Date: 11/11/2011 Job Category: COMPLETION 24 Hr Summary Run and land 2 -7/8" completion. Test hanger and nipple up master valve. Ops Trouble Start Time _ End Time Dur (hr) Ops Code Activity Code Status Code Cem . 07:30 08:30 1.00 SAFETY MTG AF Hold prejob safety meeting. Discuss Marathon JSA, ASRC JSA and assign tasks. Issue permit. 08:30 09:30 1.00 RURD OTHR AF Pre' to run tubin•. P • • - • • • • • u . _, • - - • • - - • • • • • • -Z crane. Move first load of tubing to catw- . 09:30 17:00 7.50 RUNPUL TBG AF Run seal assy, sliding sleeve, 86 jts tubing SSSV, 11 jts tubing, and hanger. Connect SSSV control line. Land and test hanger to 5000 psi. Seals are 1. / spaced out 2' off bottom of seal bore. 17:00 19:00 2.00 RURD OTHR AF Nipple up tubing head and master valve. SD due to cold temperatures and wind. 19:00 19:30 0.50 SECURE WELL AF Secure well and location. Lock gate and leave location. Report Date: 11/12/2011 Job Category: COMPLETION 24 Hr Summary Perform witnessed MIT on A annulus to 2500 psi. Nipple up and test tree to 2500 psi. Pump N2 to sliding sleeve. Ops Trouble Start Time End Time Our 01r) Ops Code Activity Code Status Code Com 08:00 09:00 1.00 PREP LOC AF Meet with Ninilchik operators. Fill out permit and discuss days activities. www.peloton.com Page 1/3 Report Printed: 12/29/2011 i /j� . # *rations Summary Report by Job • Marathon Oil Well Name: ABALONE 1 Qtr /Qtr, Block, Sec, Town, Range Field Name I License # State /Province Country NINILCHIK - ABALONE ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) I KB- Ground Distance (ft) Spud Date Rig Release Date 0.00 282.00 303.001 21.00 1/31/2003 3/7/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 09:00 10:00 1.00 SAFETY MTG AF Hold prejob safety meeting with Weatherford, Baker, ASRC, Inlet drilling, CH2MHiII,Pollard wireling, and Marathon. Discuss JSA's and assign tasks. Issue permit. 10:00 11:00 1.00 TEST CSG AF Perform state witnessed MIT on inner annulus. Tested to 2500 psi for 30 minutes with Matt Herrera as witness. Good test. Pressure dropped 20 psi in 15 minutes and an additional 5 psi in 15 minutes. Outer annulus remained at 0 psi during the test and the tubing increased to 5 psi. Test charted. 11:00 14:00 3.00 RURD EQIP AF Nipple up tree 14:00 15:00 1.00 TEST TREE AF Fill and test void and tree to 5000 psi. Good test. 15:00 16:30 1.50 RURD EQIP AF Finish rigging testers to tree. Pump off plug out of WEG. RU slickline lubricator with blind box. RU N2 pump and lines. 16:30 17:00 0.50 TEST EQIP AF Pressure test well test eauioment to 1000 psi and to 35no psi. Test slickline lubricator to 3500 psi. Test N2 line to 4000 psi. 17:00 17:30 0.50 RUNPUL SLIK AF RIH 2" blind box and tag pump out plug. Knock plug out of WEG. RIH shifting tool and open sliding sleeve. RIH shifting tool and position below sliding sleeve to close after N2 is pumped. 17:30 18:00 0.50 PUMP N2 AF Pump 9000 SCF N2 to sliding sleeve. Take 20 Bbls returns to open top tank. Close annulus and close sliding sleeve. POH Slickline. Trapped 1200 psi on tubing. 18:00 19:00 1.00 RURD SLIK AF Rig down slickline and N2 unit. 19:00 19:30 0.50 SECURE WELL AF Secure well and location. Lock gate and leave location. Report Date: 11/13/2011 Job Category: COMPLETION 24 Hr Summary Tag fluid level with slickline. Shoot 3202' - 3,207'. No response. Shoot 3,164' - 3,172' and 3,182' - 3,189'. Pressure increase of 160 psi /hour. Approximate flowrate of 50 MCF /day. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 07:30 08:00 0.50 PREP LOC AF Meet with Ninilchik operators. Fill out permit and discuss days activities. 08:00 09:00 1.00 SAFETY MTG AF Hold prejob safety meeting with Weatherford, ASRC, Inlet drilling, CH2MHiII,Pollard wireline, and Marathon. Discuss JSA's and assign tasks. Issue permit. 09:00 10:00 1.00 RURD ' SLIK AF RU slickline. PU 2.25" swage. test lubricator to 3500 psi with McOH. 10:00 11:00 1.00 RUNPUL SLIK AF RIH 2.25" swage. Tag fluid level at 2800'. Adjust surface pressure for 300 psi underbalance. 11:00 12:30 1.50 RURD ELEC AF RU Eline. PU gun #1. Stab on well and pressure test lubricator to 3500 psi.., 12:30 13:30 1.00 PERF TBG AF RIH gun #1. Shoot 3,202' - 3,207' with 2 -1/8" Shogun Raptor. 6 SPF, 0 deg • phased with magnetic decentralizer. POH. No response from well. 13:30 14:00 0.50 RURD ELEC AF RU Eline. PU gun #'A. Stab on well and pressure test quick test sub to 3500 psi. o� 14:00 14:30 0.50 PERF TBG AF RIH gun #2. Shoot 3.164' - 3,172" - 3,207 and 3.182' - 3,189" with 2 -1/8" Shogun Raptor. 6 SPF, 0 deg phased with magnetic decentralizer. POH. Well is building pressure at 160 psi /hour (approximately 50 Mcf /day. 14:30 16:00 1.50 RURD ELEC AF Observe well and RD eline. Discuss options. 16:00 16:30 0.50 SECURE WELL AF Secure well and location and leave. Weatherford testors will observe well through the night. Report Date: 11/14/2011 Job Category: COMPLETION 24 Hr Summary Delay due to wind. RU and tag fluid at 2200'. Run Static pressure. BHP = 1217 psi. Tag fluid at 2050'. Blow down from 650 psi to 50 psi. Tag fluid at 730 psi. Reduce pressure to 0 psi. Tag fluid at 375'. No indication of gas. Ops ' Trouble. , Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 06:30 07:00 0.50 WAITON WTHR TA WD Wind at 30 MPH. Call and delay Pollard. 07:00 09:00 2.00 WAITON WTHR TA WD Wait on wind. 09:00 11:00 2.00 MOB RIG AF Mobilize Pollard wireline. Wind at 15 MPH. 11:00 11:30 0.50 SAFETY MTG AF Hold prejob safety meeting. Discuss Pollard JSA and safety checklist. Assign tasks and issue permit. 11:30 12:00 0.50 RURD SLIK AF RU slickline. PU 2 -1/4" swage and stab on. 12:00 12:30 0.50 TEST BOPE AF Test lubricator to 3500 psi with McOH. Good test. 12:30 13:00 0.50 RUNPUL SLIK AF RIH 2 -1/4" swage and tag fluid at 2200'. SIWHP = 650 psi. POH. www.peloton.com Page 2/3 Report Printed: 12/29/2011 0%11 *rations Summary Report by Job • Marathon Oil Well Name: ABALONE 1 Qtr /Qtr, Block, Sec, Town, Range Field Name I License # State /Province Country NINILCHIK - ABALONE ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date Rig Release Date 0.00 282.00 303.00 21.00 1/31/2003 3/7/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 13:00 15:00 2.00 RUNPUL SLIK AF PU memory PT gauges. TEst QT sub. RIH gauges. Stop 5 min at hanger, 15 minutes at 3180', 5 minutes at 2300' and POH 60' /min. LD gauges. Good data. 15:00 16:00 1.00 RUNPUL SLIK AF RIH swage and tag fluid at 2050'. Drop WHP from 650 psi to 50 psi. Wait 30 min and tag fluid at 730'. BHP calculates to 1200 psi. Drop WHP to 0 psi. Tag fluid after 5 min at 375'. No indication of gas. R 16:00 16:30 0.50 RURD SLIK AF RD and release slickline. 16:30 17:00 0.50 SECURE WELL AF Secure well and location. Leave location. Cancel night shift for testers. Report Date: 11/15/2011 Job Category: COMPLETION 24 Hr Summary Check well. Bleed off 50 psi with N2 and some methane. Rig down and release Weatherford well testers. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 09:00 09:30 0.50 SAFETY MTG AF Hold prejob safety meeting. Discuss Weatherford JSA. Assign tasks and issue permit. 09:30 10:00 0.50 BLOWDN TBG AF SIWHP = 50 psi. Bleed pressure to 0. Start at 70% LEL, 100% LEL 1/2 way through venting and 10% LEL toward the end of venting the tubing. Pressure vented to 0 psi in 5 minutes. 10:00 13:00 3.00 RURD OTHR AF Rid down Weatherford well testing. 13:00 16:00 3.00' RURD OTHR AF Load out and release all equipment except open top tank and gas buster for swabbing operations. '16:00 16:30 0.50 SECURE WELL AF Secure location and lock gate. Report Date: 11/18/2011 Job Category: COMPLETION 24 Hr Summary Swab Well 20 runs. Recover 70 Bbls water and take samples. - Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 09:00 09:30 0.50 SAFETY MTG AF Hold prejob safety meeting. Discuss Pollard Wireline JSA and safety meeting checklist. Assign tasks and issue permit. 09:30 11:00 1.50 RURD SLIK AF RU Slickline PU 2" LIB. Stab on well. 11:00 11:30 0.50 TEST EQIP AF Test lubricator to 3500 psi. 11:30 12:00 0.50 RUNPUL SLIK AF RIH past SSSV and back to surface to verify SSSV is fully open before running through with swab cups. 12:00 17:00 5.00 RUNPUL SLIK AF PU 2 -7/8" swab cups and stab on. Tag fluid at 375' on first run and pull from 1000'. No problem at SSSV. RIH 19 additional runs. Tag fluid between 510' and 590' on every run. Pull from 1800' on each run with about 4 bbls recovery on each run. Recovered a total of 70 Bbls. Took samples on next to last run. Small amounts of dissolved gas after formation water reached surface but no gas under cups. Well goes on vacuum as soon as swab cups pass tree cap. No indications of flow and no change after completion fluid is removed from well. 17:00 17:30 0.50 RURD SLIK AF RD and release slickline. 17:30 18:00 0.50 SECURE WELL AF Secure well, close permit, and leave location. <;'-i-,-- s 55(-1' www.peloton.com Page 3/3 Report Printed: 12/29/2011 • 1 • Abalone #1 /�iVW Permit #: 202-129 Ninilchik Field Marathon Oil API #: 50- 133 - 20517 -00 -00 250' FSL, 3,000' FEL, Alaska Production LLC . Property Des: Sec. 29, T2N, R12W, SM KB Elevation: 92.35' Spud Date: 1/30/2003 Conductor TD well: 2/28/2003 20" K -55 133 ppf PE Rig Released: 3/09/03 @ 12:00 hrs Top Bottom Lat: 60° 13' 42.50" North MD 0' 170' Long: 151° 24' 2.12" West T 0' 170' Surface Casing 13 -3/8" K -55 68 ppf BTC Top Bottom Baker TE - 5 SSSV @ 374' MD MD 0' 2,208' ■ 2.313" ID TVD 0' 2,098' 17-1/2" holecmt /w ± 992 sks 12 ppg cmt. Cmt fell. WOC. Pumped top job @ 350' MD with 335 sks 15.8 ppg recovering 20 bbls Inhibited 6% KCL 1 cement to surface. Tubing String: 2 -7/8" L -80 6.5 ppf 8rd -Mod Top Bottom MD 0' 3,094' TVD 0' 2,953' Sliding Sleeve 3,085' ♦; -4 *Baker SCSSV at 350' Model TE -5 flapper valve 9 with 1/4 ", 0.049 ", SS control line *Sliding sleeve at 3085' ID = 2.313" with X- profile Packer Assy: *Baker 3.25" OD seal assembly (2.406' ID) 9 -5/8" Baker Model "D" 3,094' f►' stung into tieback sleeve at 3,094' 10' Baker Seal Bore 3.25" ID 3,104' t Intermediate Casing 2.313 X - Nipple 3,119' ■ . 9 -5/8" 40 ppf L -80 BTC I I Top Bottom WEG 3,130' •1 { MD 0' 4,336' 1 TVD 0' 4,194' IC , O / ,Si-S 12 -1/4" hole cmt /w ±135 sks of 12 ppg & 550 sks IC 1 t of13.5ppg .......... j Sterling Perforations: 3164' - 3172' MD 7' 6 spf (11- 12 -11) 3182' - 3189' MD 7' 6 spf (11- 12 -11) '; 3202' - 3207' MD 5' 6 spf (11- 12 -11) Class "G" cement: 75 sks 15.8 ppg Top estimated @ 4,233' MD. Bottom estimated @ 4,436' MD. _} Baker Cement Retainer set @ 4,283' MD Open Hole 6 -1/8" Top Bottom MD 4,336' 10,356' __it TVD 4,194' 10,203' 61/8" hole filled with 9.5 ppg Flo Pro Fresh Water Mud TD PBTD 10,356' MD - 4,233' MD 10,203' TVD - 4,091' TVD Well Name & Number: Abalone #1 Lease: Ninilchik Field Municipality: Kenai Peninsula Borough State: Alaska Country:) USA Perforations (MD): 3,164' - 3,207' Perf (TVD): 3,023' - 3,065' Angle @ KOP & Depth: -3 °/ 185 ft @ 555' MD Angle @ Perfs: 27° max @ 1,600' / 3° at perfs Date Completed: 11/12/2011 Ground Level: 245' (AMSL) I RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 1/3/2012 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission • TO: Jim Regg DATE: Friday, November 18, 2011 P.I. Supervisor 1 Q l((1 SI i I SUBJECT: Mechanical Integrity Tests MARATHON OIL CO FROM: Matt Herrera ABALONE 1 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: ABALONE 1 API Well Number: 50 - 133 - 20517 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFHl1 1 1 13 193336 Permit Number: 202 - 129 - Inspection Date: 11/8/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 Type Inj. N TVD J f - IA 250 2525 2520 2520 • P.T.D1 2021290. TypeTest SPT Test psi 2500 - OA o 0 0 0 Interval OTHER p/F P - Tubing o 0 0 0 Notes: Well work run tubing and flowback • • • • • Friday, November 18, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, November 18, 2011 TO: Jim Regg '� P.I. Supervisor < l (I( l (tl SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 1 FROM: Matt Herrera ABALONE i Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: ABALONE 1 API Well Number: 50 133 - 20517 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111113193758 Permit Number: 202 - 129 - Inspection Date: 11/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 -Type Inj. N ' TVD 3094 - IA 0 2525 • 2505 2500 P.T.D 2021290 'TypeTest SPT Test psi 2500 - OA o 0 0 0 Interval OTHER P/F P - Tubing 0 5 10 5 Notes: Well work run tubing and flowback. . f !,V rL 0 Friday, November 18, 2011 Page 1 of 1 • • SMITE OF ALASEA ft SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMI'IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production, LLC _ P.O. Box 1949 p�©, I Kenai, AK 99611 -1949 Re: Ninilchik Field, Exploratory Pool, Abalone #1 Sundry Number: 311 -342 ; I 1; . .I eg Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 7 day of November, 2011. Encl. . r Marathon Alaska Production LLC `.e,►,r Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 November 1, 2011 RECEIVED Mr. Daniel Seamount NOV j s 2Ot Alaska Oil & Gas Conservation Commission 333 W 7 Ave ' e, Alaska 99501 �� ®�� & Gas Cons. �• Car�usstan Anchorage, Andros e Reference: 10 -403 Application for Sundry Approvals Field: Ninilchik Unit Well: Abalone #1 Dear Mr. Seamount, Submitted for your approval is the10 -403 Application for Sundry Approvals to recomplete and flow -test ABA- lwell. Marathon proposes to install a 2 -7/8" tubing string to surface with the wellbore packer set at -3,100' MD. Perforations will then be added to the Sterling -C formation (9 -5/8" intermediate casing) with perforation activities being conducted through the 2 -7/8" tubing. Plans are to flow tested (flared /vented) the well up the 2 -7/8" tubing string until reaching the target volume of - 40MMcf. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, 5 kL Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Proposed Well Schematic Kenai Well File Completion Procedure (2) KJS ATE OF ALASKA (, CE I D ALASKA OIL AN AS CONSERVATION COMMISSION it,tt APPLICATION FOR SUNDRY APPROVALS NOV 0 ° ' /11 '� 20 AAC 25.280 t3 /1-3-g 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool 0 - Repair well ❑, l%ka Oil lerGase60&4916610M Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Areify)rt,ITIlie Extension ❑ Operational shutdown ❑ Re -enter Susp. Well 111 Stimulate ❑ Alter casing ❑ Other: Flow test 0 2. Operator Name: Marathon Alaska Production LLC 4. Current Well Class: 5. Permit to Drill Number: Development ❑ Exploratory 0 202 -129- 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20517 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Abalone #1 - 9. Property Designation (Lease Number): 10. Field / Pool(s): FEE - OSMAR Ninilchik Field / NA - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,356'- 10,203' - 4,233' - 4,091'— 4,233 " - NA Casing Length Size MD TVD Burst Collapse Structural Conductor 149' 20" 170' 170' 3,060 psi 1,500 psi Surface 2,187' 13 -3/8" 2,208' 2,098' 3,450 psi 1,950 psi Intermediate 4,315' 9 -5/8" 4,336' 4,194' 5,750 psi 3,090 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA 4 -1/2" L -80 —81' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): _ _ Packers: NA - - 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 - Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: November 5, 2011 Commencing Operations: Oil ❑ Gas 0 - WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Sklba (907) 283 - 1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative oy... Signature Phone (907) 283 -1371 Date November 1, 2011 COMMISSION USE ONLY �j Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 / ,.3 60 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: AO3 kO V.Slt-,_t_.s5 N^0.\ -1 \�`aSvc--rC.g1c- Qc s N Nr. -� `C3 "3 r <0 vN cs'O? c ,i\c i p vcss� cC. VC 5N R sz,. , � Subsequent Form Required: r ]� ",,t� LA j \ t\ < ;a j ' ' 1� R'`!' o 4 / � APPROVED BY / / �� i �' Approved by: COMMISSIONER THE COMMISSION Date: RBD S NOV 07 261i CY RIGINAL Form 10 -403 Revised 12/2009 Submit in Duplicate • • • � Marathon Oil Alaska Production LLC,. MARATHON ALASKA PRODUCTION LLC ALASKA ASSET TEAM Abalone 1 Ninilchik Unit Abalone Pad Well completion and flow test Procedure APPROVALS: Mickey Mullin Program Writer Latest Version Date: 11/1/11 Well Status: The well is plugged back into the Intermediate casing and is in suspended Status. Obiectives: Complete well in the Sterling formation and flow test to determine production capabilities. Resources: Crane E -Line Unit Test Flow equipment Flow -back Tanks SPIDR Gauge Procedure: e--� 3:7 a-kN t,�cx -k A 1. Pressure test 9 -5/8" casing to 2500 psi. Casing is full of 3% inhibited KCI and was tested to 2500 psi in 2003. C A()cCs,_ ; 2. Pull hanger and 2 jts 4 -1/2" currently in the well. 3. Deliver clean 500 bbl. Rain - for -Rent tank, MOC flow back tank and MOC gas buster to location — build liner around same. Load 300 Bbls water in supply tank. RU Pollard pump to annulus valve. ABA -1 Perforate & Test Flow Procedure Page 1 9/19/11 4. MIRU Pollard Eline. PU 9 -5/8 packer assy with 3.25" seal bore, x -• le, and p Y pp WEG with pump out plug. Barriers are unperforated pressure tested casing and kill weight fluid. S Q g S 5. RIH and set packer with WEG at 3135'. POH. 6. MIRU work platform, 2 -7/8" tubing and jewelry. 7. RIH 2 -7/8" tubing with 3.25" seal assy, sliding sleeve, and Baker TE -5 SSSV with control line. Stab seals in to seal bore. Space out and land tubing. Barriers are 9- 5/8" casing, packer with plug, and kill weight fluid. 8. Nipple up tubing bonnet and 4- 1/16" 5K tree. Test tree to 5K psi. Verify with hand pump that SSSV opens and closes with the correct amount of hydraulic fluid. t---'t r�" -' ."7 / t \CL - 4 9. Test backside to 2500 psi. Step up pressure on tubing until pump out plug releases. 10. MIRU BJ nitrogen unit. RU MOC 2" hard line, MOC flow -back tank and a 5K manifold between tree and tank. Pressure test flow -back iron with water to 250 low /4500 high psi. 11. RIH slickline and open Sliding sleeve. 12. Pump 9000 SCF N2 down tubing. Take 20 bbls returns from 2 -7/8" X 9 -5/8" annulus. Close backside. Close sliding sleeve and rig down slickline. Final N2 pressure should be 1350 psi. 13. MIRU Pollard electric -line and underbalance perforate the proposed Sterling intervals. 3,164' — 3,172' MD (8') 3,182' — 3,189' MD (7') 3,202' — 3,207' MD (5') Pressure test lubricator and BOPE to 4500 psi. PU and RIH w/ CCL, 2.125" guns loaded 6 SPF 0 degree - phased. Maintain nitrogen pressure on tubing while RIH and perforate Sterling interval 30% underbalance. Monitor tubing for signs guns have fired. POOH. 14. RIH and obtain a static BHP immediately following perforating the Sterling interval. 15. Turn well over to well testers and flow for 5 -7 days. Expected flow rate is 5 — 7 MM SCF /day. Perform a 4 point test and submit to State of Alaska. No more than a 50% drawdown with nitrogen or methane gas in the wellbore is permitted for the lowest open interval. Obtain stabilized flow within the 50% drawdown limit. Continue flowing well to flare until total recovery reaches 40MM SCF. ABA -1 Perforate & Test Flow Procedure Page 2 9/19/11 • • I • D Trap gauge on tree cap flan and monitor 16. Shut-in well. Install SP DR or Data p g g p g pressure build -up. When build -up test is complete, RIH slickline memory gauges and record static BHP. 17. Release all rental and test equipment. Chain and lock all tree valves. Remove liner and berm. Inspect location and lock gate. ABA -1 Perforate & Test Flow Procedure Page 3 9/19/11 • Al3'alone #1 • M Ninilchik Field MARATHON Permit #: 202-129 250' FSL, 3,000' FEL, API #: 50- 133 - 20517 -00 -00 Sec. 29, T2N, R12W, SM Property Des: Tubing (2 joints) KB Elevation: 92.35' 4 -1/2" 12.6 L -80 Mod IBT Spud Date: 01/30/03 Top Bottom Rig Released: 03/09/03 © 12:00 hrs MD 0' "'81' Lat: 60° 13' 42.50" North Long: 151° 24' 2.12" West TVD 0' "81' Well Suspended Conductor 20" K - 55 133 ppf PE Top Bottom MD 0' 170' TVD 0' 170' Surface Casing Inhibited 6% KCL ■ 13 - 3/8" K - 55 68 ppf BTC Top Bottom MD 0' 2,208' TVD 0' 2,098 ' 17 -1/2" holecmt /w ± 992 sks 12 ppg cmt. Cmt fell. WOC. Pumped top job @ 350' MD with 335 sks 15.8 ppg recovering 20 bbls cement to surface. Class "G" cement: 75 sks 15.8 ppg Top estimated @ 4,233' MD. Intermediate Casing Bottom estimated @ 4,436' MD. 9 - 5/8" 40 ppf L - 80 BTC Top Bottom MD 0' 4,336' TVD 0' 4,194' 12-1/4" hole cmt /w ±135 sks of 12 ppg & 550 sks of 13.5 ppg Baker Cement Retainer set @ 4,283' MD 9.5 ppg Flo Pro Fresh Water Mud TD PBTD 10,356' MD -4,233' MD 10,203' TVD -4,091' TVD Well Name & Number: Abalone #1 Lease: County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:) USA Perforations: (M D) TVD: Angle @ KOP and Depth: - 3° / 185 ft @ 555' MD Angle Perfs: NA Date Suspended: 3/9/2003 Completion Fluid: 6% KCL Revised By: Kevin Skiba Last Revision Date: 10/27/2010 r • Abalone #1 r» Proposed Marathon Oil Permit #: 202-129 Ninilchik Field API #: 50 -133- 20517 -00 -00 250' FSL, 3,000' FEL, Alaska Production LLC Property Des: KB Elevation: 92.35' Sec. 29, T2N, R12W, SM Conductor Spud Date: 01/30/03 20" K -55 133 ppf PE Rig Released: 3/09/03 @ 12:00 hrs Top Bottom Lat: 60° 13' 42.50" North MD 0' 170' Long: 151° 24' 2.12" West TVD 0' 170' Surface Casing 13 -3/8" K -55 68 ppf BTC Top Bottom MD 0' 2,208' TVD 0' 2,098 ' Baker TE - SSSV 350' 17 -1/2" holecmt /w ± 992 sks 12 ppg cmt. 2.313" ID Cmt fell. WOC. Pumped top job @ 350' MD with 335 sks 15.8 ppg recovering 20 bbls Tubing String: 2 -7/8 ", 6.5 ppf, L -80, 8rd -Mod 3100' Inhibited 6% KCL Baker SCSSV at 350' Model TE -5 flapper valve with 1/4 ", 0.049 ", SS control line Sliding Sleeve 3 085' � Sliding sleeve at 3085' g , ID = 2.313" with X- profile j . Baker 3.25" OD seal assembly (2.406' ID) stung into Baker Packer 3,100' i tieback sleeve at 3100' 10' Seal Bore 3,115' Packer Assy 71 i, 9 -5/8" Baker Model "D" 3100' Baker Seal Bore 3.25" ID 3115' 2.313 X- Nipple 3 X-Nipple 2.313" 3125' WEG 3,135' i WEG 3135' = Proposed Perforations 3164' - 3172' MD 7' 6 spf (11 -2011) — 3182' - 3189' MD 7' 6 spf (11 -2011) 3202' - 3207' MD 5' 6 spf (11 -2011) Class "G" cement: 75 sks 15.8 ppg Top estimated @ 4,233' MD. ' Baker Cement Retainer set @ 4,283' MD Bottom estimated @ 4,436' MD. . Intermediate Casing ', 9 -5/8" 40 ppf L -80 BTC T2Q Bottom MD 0' 4,336' TVD 0' 4,194' 9.5 ppg Flo Pro Fresh Water Mud 12 -1/4" hole cmt /w ±135 sks of 12 ppg & 550 sks of 13.5 ppg TD PBTD 10,356' MD —4,233' MD 10,203' TVD -4,091' TVD Well Name & Number: Abalone #1 Lease: County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:/ USA Perforations: (MD) TVD: Angle @ KOP and Depth: - 3° / 185 ft @ 555' MD Angle Perfs: 27° max @ 1600' / 3° at perfs Date Suspended: 3/9/2003 Completion Fluid: 6% KCL Revised By: Mickey Mullin Last Revision Date: 10/27/2011 • 1110 � Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 03, 2011 7:00 AM To: 'Mullin, Mickey (MRO)' Cc: Miller, Nick (MRO); Skiba, Kevin J. (MRO); Ellis, Michael (MRO); Mclninch, Bruce E. (MRO) Subject: RE: Mickey, Thanks for the note. We will return the sundry. Q� Tom Maunder, PE AOGCC From: Mullin, Mickey (MRO) [mailto:mmullin @marathonoil.com] Sent: Monday, October 03, 2011 3:50 AM To: Maunder, Thomas E (DOA) Cc: Miller, Nick (MRO); Skiba, Kevin 3. (MRO); Ellis, Michael (MRO); Mclninch, Bruce E. (MRO) Subject: Hi Tom, Y " "ft t. i r(i We would like to withdraw the recent sundry submitted for Abalone 1. I will be in contact to discuss options as soon as possible and hope to resubmit the sundry in the near future. Please include me on your correspondence on this well. Regards, Mae, Melia Senior Completions Engineer WWD &C Deepwater/ AK Marathon Oil Company Office 713 - 296 -2397 cel 281 - 413 -5088 10/3/2011 Maunder, Thomas E (DOA) From: Miller, Nick (MRO) [njmiller @marathonoil.coml Sent: Friday, September 30, 2011 10:54 AM To: Maunder, Thomas E (DOA) Subject: Re: Abalone #1 (202 -129) We'll most likely want to withdraw and resubmit, sounds like the best plan forward, Thanks, Nick From: Maunder, Thomas E (DOA) <tom.maunder @alaska.gov> To: Miller, Nick (MRO) Sent: Thu Sep 29 14:20:36 2011 Subject: RE: Abalone #1 (202 -129) OK Nick. Do you want to withdraw what has already been submitted? That will likely help reduce confusion. Tom From: Miller, Nick (MRO) [mailto :njmiller @marathonoil.comj Sent: Thursday, September 29, 2011 11:03 AM To: Maunder, Thomas E (DOA) Subject: Re: Abalone #1 (202 -129) Tom, Ok, I see where your values are coming from now. I don't expect surface pressures to exceed 1500 psi. We'II regroup and fine tune our proposed completion design, then resubmit for approval. Thanks, Nick From: Maunder, Thomas E (DOA) <tom.maunder @alaska.gov> To: Miller, Nick (MRO) Sent: Thu Sep 29 13:45:58 2011 Subject: RE: Abalone #1 (202 -129) Nick, In the procedure you plan to have 1500 psi N2 pressure at surface and state that the well will be shot -30% underbalance. Based on that input, I get a potential surface pressure of -2140 psi. As I remember, and 1 have not checked the records, I don't believe the configuration you propose has been approved for surface pressures in excess of some hundreds of psi. Tom Maunder, PE From: Miller, Nick (MRO) [mailto :njmiller @marathonoil.com] Sent: Thursday, September 29, 2011 10:40 AM To: Maunder, Thomas E (DOA) Subject: Re: Abalone #1 (202 -129) Tom, Page2of3 • 1 Thanks for the background information. You mentioned a potentially higher surface pressure...what value did you have in mind? Thanks, Nick Miller From: Maunder, Thomas E (DOA) <tom.maunder @alaska.gov> To: Miller, Nick (MRO); Skiba, Kevin J. (MRO) Cc: Mullin, Mickey (MRO); Ellis, Michael (MRO) Sent: Thu Sep 29 13:30 :16 2011 Subject: RE: Abalone #1 (202 -129) Nick, et al, I do not know the content of your conservations with Winton. He recently resigned and is no longer with the Commission or in Alaska. The configurations of your Ninilchik wells differ greatly from Abalone. The Ninilchik wells have smaller "tubing sized" pipe extending to surface rather than 9 -5/8" casing. If it is your desire to complete the well as submitted, then a request to not have the well equipped with tubing and packer must be made. I don't remember all the wells where such larger bore completions have been allowed, but I suggest you look at those files. It is possible that a hearing will be necessary to allow the exception since there does not appear to be waiver language in 20 AAC 25.200. Again, I see this well as different due to potentially higher surface pressure. If I remember correctly, there may have been a request to allow annular flow or no tubing in a well that did have "high" surface pressure and it was not approved. Tom Maunder, PE AOGCC From: Miller, Nick (MRO) [mailto:njmiller @marathonoil.com] Sent: Thursday, September 29, 2011 10:04 AM To: Skiba, Kevin J. (MRO); Maunder, Thomas E (DOA) Cc: Mullin, Mickey (MRO); Ellis, Michael (MRO) Subject: Re: Abalone #1 (202 -129) None of the Ninilchik monobore completions have a packer and tubing. When I spoke to Winton Hebert with the AOGCC (sp ?) a few months ago he thought our 9 -5/8 "monobore" in the Abalone #1 wouldn't be a problem. Nick From: Skiba, Kevin J. (MRO) To: Maunder, Thomas E (DOA) <tom.maunder @alaska.gov> Cc: Mullin, Mickey (MRO); Ellis, Michael (MRO); Miller, Nick (MRO) Sent: Thu Sep 29 12:58:03 2011 Subject: RE: Abalone #1 (202 -129) Tom, I did receive your message. Thank you for your input. I will pass this along to the engineer overseeing this activity. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC 9/30/2011 Page 3 of 3 • • Office (907) 283 -1371 Cell (907) 394 -1880 Fax (907) 283 -1350 Safe, Clean, and Responsible From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, September 29, 2011 9:28 AM To: Skiba, Kevin J. (MRO) Cc: Saltmarsh, Arthur C (DOA) Subject: Abalone #1 (202 -129) Kevin, Please pass this on as appropriate. Please confirm you got this message. I just began reviewing the proposed re -entry and test procedure for this well. This proposal is not approvable as presently presented. 20 AAC 25.200 (d) requires a well capable of unassisted flow to be equipped with tubing and a packer. Well safety valve systems should also be considered. Producing wells without tubing has been approved in other situations; however I believe the surface pressures have been significantly Tess than are likely here. Call or message with any questions. Tom Maunder, PE AOGCC 793 -1250 9/30/2011 • • " WAY/ Marathon Alaska Production LLC ��1 //. Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 September 27, 2011 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7 Ave RECEIVED Anchorage, Alaska 99501 SEP 2 8 2011 SEP for Sundry Approvals Alaska Oil & Gas Cans. Commissi Reference: 10 -403 Application ry pp Althorn° Field: Ninilchik Unit Well: Abalone #1 Dear Mr. Aubert, Submitted for your approval is the10 -403 Application for Sundry Approvals to recomplete and flow -test ABA- lwell. Approximately 40MMcf of gas will be flared /vented during the testing process. Marathon proposes to perforate the 9 -5/8" casing into the Sterling -C formation and use it as the production casing in a monobore configuration. The 9 -5/8" casing packoff, on the ABA -1, was tested to 5,000 psi and the 9 -5/8" 40 ppf L- 80 BTC casing was tested to 3,350 psi surface pressure for 30 minutes on 2/16/2003. The casing was again tested to 1,500 psi surface pressure for 30 minutes on 3/06/2003 after a cement plug was installed for temporary abandonment of the targeted initial Tyonek intervals. A CBL and USIT were run to verify TOC and cement bond quality for the 9 -5/8" casing. TOC was found to be ±2,300 ft, approx. 100 ft below the 13 -3/8" K -55 68ppf BTC surface casing string. Good cement bond was observed from TOC at 2,300 ft to approx. 4,200 ft MD. The CBL also shows several hundred feet of good cement above the uppermost planned perforation interval at 3,164' MD. Marathon plans to monitor the 9 -5/8" x 13 -3/8" casing annulus during all completion activities. Based on the mechanical pressure tests and supporting cement evaluation Togs, we feel that the 9 -5/8" casing can be used as a safe, long -term monobore production conduit. Maximum anticipated SICP will be 1,500 psi, well below the published 9 -5/8" 40ppg L -80 BTC casing burst rating of 5,750 psi. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative • 1 Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Work Procedure Kenai Well File (2) KJS • STATE OF ALASKA RECEIVED • ALASKA. AND GAS CONSERVATION COMMISSIOW SEP 2 8 ?O .. - APPLICATION FOR SUNDRY APPROVALS 9a9-// 20 AAC 25.280 Alaska Oil & Gas Coal. Cvmmus 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool El - Repair well ❑ CFjan. - - ..roved program Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing El /1%. , 1 1. = t e Extension ❑ Operational shutdown ❑ Re -enter Susp. Well El - Stimulate ❑ Alter casing ❑ Other: Flow test El - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development ❑ Exploratory 0 202 -129 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6 ' PI Number: Kenai Alaska, 99611 -1949 50- 133 - 20517 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number:/ property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No Abalone #1 - 9. Property Designation (Lease Number): 10. Field / Pool(s): FEE - OSMAR - ilchik Field / NA 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (fty Plugs (measured): Junk (measured): 10,356' • 10,203' - 4,233'- 4,091'. 4,233" NA Casing Length Size MD TVD Burst Collapse Structural Conductor 149' 20" 170' 170' 3,060 psi 1,500 psi Surface 2,187' 13 -3/8" 2,208' 2,098' 3,450 psi 1,950 psi Intermediate 4,315' 9 -518" ' 33 4,194' 5,750 psi 3,090 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA 4 -1/2" L -80 -81' Packers and SSSV Type: SSSV: NA kers and SSSV MD (ft) and TVD (ft): - - Packers: NA - 12. Attachments: �- . Well Class after proposed work: Description Summary of Proposal �� Detailed Operations Program ❑ BOP Sketch r ` Exploratory 0 " Development ❑ Service ❑ 14. Estimated Date for 5. Well Status after proposed work: Commencing Operations: October 11, 201 Oil ❑ Gas El _ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct • the best of my knowledge. Contact Kevin Skiba (907) 283 - 1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature ' f T/ v w y hone Date `�'= j — ` >� <" ' (907) 283 -1371 September 27, 2011 COMMISSION USE ONLY Conditions of approval: Notify Commission s•; that a representative may witness Sundry Number: 3 1 . '�� Plug Integrity ❑ BOP Test . • Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: R BDMS OCT 04 201 \G\‘\11\1- .., Form 10 -403 Revised 12/2009 Submit in Duplicate Abalone #1 40 Ninilchik Field M ARATHO 250' FSL, 3,' , Permit #: 202 -129 Sec 29 T2N R1 SM API #: 50- 133 - 20517 -00 -00 Property Des: Tubing (2 joints) KB Elevation: 92.35' 4 -1/2" 12.6 L -80 Mod IBT Spud Date: 01/30/03 • Top Bottom Rig Released: 03/09/03 @ 12:00 hrs MD 0' "81' Lat: 60° 13' 42.50" North ..111 A l Long: 151° 24' 2.12" West TVD 0' "81' Well Suspended Conductor 20" K -55 133 ppf PE Top Bottom MD 0' 170' TVD 0' 170' Surface Casing Inhibited 6% KCL ► 13 -3/8" K -55 68 ppf BTC Top Bottom MD 0' 2,208' TVD 0' 2,098' 17 -1/2" holecmt /w ± 992 sks 12 ppg cmt. ' Cmt fell. WOC. Pumped top job @ 350' MD with 335 sks 15.8 ppg recovering 20 bbls cement to surface. Class "G" cement: 75 sks 15.8 ppg T. Top estimated @ 4,233' MD. - t ' Bottom estimated @ 4,436' MD. X ,•+, .. Intermediate Casing 9 -5/8" 40 ppf L -80 BTC Top Bottom MD 0' 4,336' i TVD 0' 4,194' 12 -1/4" hole cmt /w ±135 sks of 12 ppg & 550 sks of 13.5 ppg Baker Cement Retainer set @ 4,283' MD 9.5 ppg Flo Pro Fresh Water Mud I TD PBTD 10,356' MD -4,233' MD 10,203' TVD -4,091' TVD Well Name & Number: Abalone #1 Lease: County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:) USA Perforations: (MD) TVD: Angle @ KOP and Depth: - 3° / 185 ft @ 555' MD _Angle Perfs: NA Date Suspended: 3/9/2003 Completion Fluid: 6% KCL Revised By: Kevin Skiba Last Revision Date: 10/27/2010 • • r t4JJ Marathon COI Alaska Production LLC.. MARATHON ALASKA PRODUCTION LLC ALASKA ASSET TEAM Abalone 1 Ninilchik Unit Abalone Pad Well completion and flow test Procedure APPROVALS: Nick Miller Program Writer Latest Version Date: 3/19/11 Well Status: The well is plugged back into the Intermediate casing and is in suspended Status. Objectives: Recomplete well into the Sterling formation and flow test to determine production capabilities. Resources: Coil Unit & Crane E -Line Unit Test Flow equipment Flow -back Tanks SPIDR Gauge Procedure: 1. NU and test 4 -1/2" production tree with 2 -3/8" coil head pre - installed in the vertical run. 2 . MIRU Expro well testing equipment. Set up equipment per Expro layout using liner and dunnage to contain any potential spills or leaks. Deliver clean 500 bbl. Rain - for -Rent tank, MOC flow back tank and MOC gas buster to location — build liner around same. 3 . MIRU BJ Services 1 -3/4" coil tubing unit, nitrogen unit and fluid pump truck. Test coil BOP's and lubricator. RU MOC 2" flowback line, MOC flowback tank and a 5K manifold to BJ pump truck. Pressure test Expro flow -back iron and BJ equipment with water to 250 low /4500 high psi. 4. RIH with 2" OD bullnose jetting nozzle on CT to 3,500 MD, reverse jet well dry with nitrogen. POOH trapping 1500 psi surface nitrogen pressure. Sterling interval will be perforated at 30% underbalance. RD BJ Services coil tubing and nitrogen units ABA -1 Perforate & Test Flow Procedure Page 1 9/19/11 A 5. MIRU Expro electric -line a d underbalance perforate the proposed Sterling interval. 3,164' — 3,172' MD (8') 3,182' — 3,189' MD (7') 3,202' — 3,207' MD (5') Pressure test lubricator and BOPE to 4500 psi. PU and RIH w/ CCL, 3.375" HSD guns loaded 6 SPF 60 degree - phased with SDP charges and conventional firing head. Maintain nitrogen pressure on tubing while RIH and perforate Sterling interval 30% underbalance. Monitor tubing for signs guns have fired. POOH. 6. RIH and obtain a static BHP immediately following perforating the Sterling interval. 7. Turn well over to Expro well testers and flow for 5 -7 days. Perform a 4 point test and submit to State of Alaska. No more than a 50% drawdown with nitrogen or methane gas in the wellbore is permitted for the lowest open interval. Obtain stabilized flow within the 50% drawdown limit. 8. Shut -in well. Install SPIDR or Data Trap gauge on tree cap flange and monitor pressure build -up. When build -up test is complete, RIH and record static BHP. 9. MIRU BJ Services 2 -3/8" coil tubing unit. Test coil BOP's. RIH w/ 2 -3/8" velocity string and position end of coil bha immediately above producing Sterling perforations. Hang coil at surface and test hanger. 10. Open up well through 2 -3/8" velocity string and test well for 4 -6 hours to ensure formation is clear of sand and water. Lubricate in a BPV and shut -in the well. Secure master valves with chain and a lock. 11. Release all rental and test equipment. Remove liner and berm. Inspect location and lock gate. II ABA -1 Perforate & Test Flow Procedure Page 2 9/19/11 • • • STINE CI l SEAN PARNELL, GOVERNOR �t ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tiffany Stebbins Regulatory Compliance Representative Marathon Alaska Production, LLC P.O. Box 1949 \ Kenai, AK 99611 -1949 aPf5 Re: Ninilchik Field, Undefined Gas Pool, Abalone #1 Sundry Number: 310 -381 Dear Ms. Stebbins: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of June, 2011. Encl. 5A,AMEDAM 2, j 2D • Mar, Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 n Alaska Production LLC Kenai,AK99611 Telephone 907/283 -1371 Fax 907/283 -1350 November 9, 2010 Mr. Winton Aubert NOV 1 2 2010 Alaska Oil & Gas Conservation Commission 333 W 7 Ave 1 4,13 . 3 Oil & Gds Cons. C ll~ :33inn Anchorage, Alaska 99501 Arhat!e Reference: 10 -403 Application for Sundry Approvals Request: Suspended Well Extension Request Field: Ninilchik Unit Well: Abalone # 1 Dear Mr. Aubert: Attached for your approval is Form 10 -403 Application for Sundry Approvals for well ABA -1. This is a request for a 10 year suspension approval for well ABA -1 which had a suspended well inspection performed on September 29, 2010. Please contact Kevin Skiba at (907) 283 -1371 if you have any questions or need additional information. Sincerely, y Tiffany Stebbins Regulatory Compliance Representative Enclosure: 10 -403 cc: Houston Well File Kenai Well File KJS 1,!014 '�- c li o6(zo/tot1 STATE OF ALASKA b ` t ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS NOV 1 2 2010 20 AAC 25.280 ❑ Re p air We � ge ro ( ' ' ��ne 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool g aga U t a n L d Pro ram u e Pr g gram , Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Suspended Well Extension Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development ❑ Exploratory p 202 - 129 3. Address: PO Box 1949 ❑ 6. API Number: Stratigraphic ❑ Service Kenai, Alaska 99611 - 1949 50 133 - 20517 - 00 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Abalone # 1 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE - OSMAR Ninilchik Field / NA 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,356' 10,203' 4,233' 4,091' 4,233' NA Casing Length Size MD TVD Burst Collapse Structural Conductor 149' 20" 170' 170' 3,060 psi 1,500 psi Surface 2,187' 13 -3/8" 2,208' 2,098' 3,450 psi 1,950 psi Intermediate 4,315' 9 -5/8" 4,336' 4,194' 5,750 psi 3,090 psi Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA 4 -1/2" L -80 -81' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): Packers: NA NA 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil p Gas ❑ WDSPL ❑ Suspended ig 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tiffany Stebbins 907- 565 -3043 Printed Name Tiffany Stebbins 907- 565 -3043 Title Regulatory Compliance Representative Signature Phone Date b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: j5) 381 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: it 1 "E'f./v tc-bt tA0.11 1p L1 p/a.CC.N t4.A-t CL f p o /eel tM,! 1.- S14ttid .rde 30 - (St, Subsequent Form Required: /10 kte , APPROVED BY / /� I / Approved by: g COMMISSIONER n T ' HE COMMISSION Date: ( / fJ _ 0 RBDMS JUN 21101) R I Gi IiVAL Form 10 -403 Revised 1/2010 4 -� Submit in Duplicate • SITATE A[LASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production, LLC P.O. Box 1949 <,�' Kenai, AK 99611 -1949 '' Re: Ninilchik Field, Exploratory Pool, Abalone #1 1 9.,5( P ry Sundry Number: 311 -158 Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 / '. �I Daniel T. Seamount, Jr. Chair DATED this /3 day of May, 2011. Encl. • Marain Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai, AK 99611 ® Telephone 907/283 -1371 Fax 907/283 -1350 May 6, 2011 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 RECEIVED MAY 0 2011 Reference: 10 -403 Application for Sundry Approvals Mika Oii & Gag Cm. Commission Field: Ninilchik Unit - nmcrage Well: Abalone #1 Dear Mr. Aubert: Submitted for your approval is the ABA -1 10 -403 Application for Sundry Approvals requesting a variance of the surface plug installation. open -hole section of this well is isolated with a cement plug approximately 203' in length with a cement retainer located at 4,283' MD. The combination of cement plug and retainer should be sufficient to ensure that there is no hydrocarbon or fresh water migration. ABA -1 has future production capabilities upon development of the Abalone location. It would be beneficial to maintain the ABA -1 wellbore in its current state while awaiting this development. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ..2?1 -vim V a t Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Well Schematic Houston Well File Kenai Well File KJS - '� { - 1 l STATE OF ALASKA ` —..\--42 c, ( ALASKA AND GAS CONSERVATION COMMISSIC� i t IaGit- APPLICATION FOR SUNDRY APPROVALS 4-vo ost t s jzott 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Change approved program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Sus p. Well Stimulate Alter casing ❑ Other: V ariance for Surface Plug p p ❑ ❑ 9 9 - El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development ❑ Exploratory !0 _ 202 -129 3. Address: po Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20517- 00 -00 nearest 7. If perforating, closest approach in pool(s) opened by this operation to ea 8 . Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No E Abalone #1 9. Property Designation (Lease Number): 10. Field /Pool(s): FEE - OSMAR Ninilchik Field / NA- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,356' - 10,203' - 4,233' - 4,091', 4,233" NA Casing Length Size MD r' TVD Burst Collapse Structural Conductor 149' 20" 170' 170' 3,060 psi 1,500 psi Surface 2,187' 13 -3/8" 2,208' 2,098' 3,450 psi 1,950 psi Intermediate 4,315' 9 -5/8" 4,336' 4,194' 5,750 psi 3,090 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA 4 -1/2" L -80 —81' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): - - Packers: NA - - 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory t4 - Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Plugged - 111 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature TAil (907) 283 -1371 Date May 6, 2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 611-13 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED' Other: MAY 1 0 MI P K r s+.(4,' 6 2 Ask --t, 25. t t Z (i } , a. ( -v 14J( u cet 1 1 4 41 p /ate 4" k qfaro Vet 1. Alaska Oil & l;ss Cons. & omission Subsequent Form Required: AJp kt - Ann u APPROVED BY Approved b i ; COMMISSIONER THE COMMISSION Date: l i 3// / Form 10 -403 Revised 12/2009 Submit in Duplicate • Abalone #1 M Ninilchik Field MARATHON 250' FSL, 3,000' FEL, Permit #: 202-129 Sec. 29, T2N, R12W, SM API #: 50- 133 - 20517 -00 -00 Property Des: Tubing (2 joints) KB Elevation: 92.35' 4 -1/2" 12.6 L -80 Mod IBT Spud Date: 01/30/03 Top Bottom Rig Released: 03/09/03 @ 12:00 hrs MD 0' "'81' Lat: 60° 13' 42.50" North ■I A l Long: 151° 24' 2.12" West TVD 0' ^'81' Well Suspended Conductor 20" K -55 133 ppf PE A. Top Bottom MD 0' 170' TVD 0' 170' Surface Casing Inhibited 6% KCL . 13 -3/8" K -55 68 ppf BTC Top Bottom MD 0' 2,208' TVD 0' 2,098 ' 17 -1/2" holecmt /w ± 992 sks 12 ppg cmt. . Cmt fell. WOC. Pumped top job @ 350' MD with 335 sks 15.8 ppg recovering 20 bbls cement to surface. Class "G" cement: 75 sks 15.8 ppg ':` Top estimated @ 4,233' MD. Bottom estimated @ 4,436' MD. Intermediate Casing 9 -5/8" 40 ppf L -80 BTC Top Bottom MD 0' 4,336' • TVD 0' 4,194' 12-1/4" hole cmt /w ±135 sks of 12 ppg & 550 sks of 13.5 ppg Baker Cement Retainer set @ 4,283' MD 9.5 ppg Flo Pro Fresh Water Mud TD PBTD 10,356' MD - 4,233' MD 10,203' TVD -4,091' TVD Well Name & Number: Abalone #1 Lease: County or Parish: Kenai Peninsula Borough _ State: Alaska I Country:I USA Perforations: (MD) TVD: Angle @ KOP and Depth: - 3° / 185 ft @ 555' MD Angle Perfs: NA Date Suspended: 3/9/2003 Completion Fluid: 6% KCL Revised By: Kevin Skiba Last Revision Date: 10/27/2010 Mara on Alaska Production LLC Alaska Asset Team M Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 October 27, 2010 NOV 7°1° Mr. Winton Aubert Alaska Oil & Gas Conservation Commission ATITO ag 333 W 7 Ave Anchorage, Alaska 99501 D• pas- °- Reference: 10 -404 Report of Sundry Well Operations Field: Ninilchik Unit Well: Abalone #1 Dear Mr. Aubert: Attached for your records is the10 -404 Report of Sundry Well Operations for ABA -1 well. This sundry documents the suspended well inspection performed on September 29, 2010. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, V.1 '.M JU 2, 0 201) , 6 4 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Well Pictures KJS '/ Mile Radius Well Plate l/JG A STATE OF ALASKA 06/2 2011 ` ALASKAWAND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon H Repair Well H Plug Perforations H Stimulate H Other U Suspended well Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ inspection Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Alaska Production LLC Development ❑ Exploratory 0 ` 202 -129 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 * 50- 133 - 20517 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: r FEE -OSMAR Abalone #1 9. Field /Pool(s): Ninilchik Field 10. Present Well Condition Summary: Total Depth measured 10,356' feet Plugs measured 4,233 feet true vertical 10,203' feet Junk measured NA feet Effective Depth measured 4,233' feet Packer measured NA feet true vertical 4,091' feet true vertical NA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 149' 20" 170' 170' 3,060 psi 1,500 psi Surface 2,187' 13 -3/8" 2,208' 2,098' 3,450 psi 1,950 psi Intermediate 4,315' 9 -5/8" 4,336' 4,194' 5,750 psi 3,090 psi Production : Liner • � C N rl " ) " Perforation depth: Measured depth: NA feet '.) V 0 w '2 ! _ , ) t�a True Vertical depth: NA feet g Uti (St Gat Cans. Loorm,3sio 0 Anchorage Tubing (size, grade, MD & TVD): 4 - 1/2" L - — 81' MD — 81' TVD 1 SSSV: NA - MD - TVD Packers and SSSV (type, MD & TVD): Packers: NA - MD - TVD 11. Stimulation or cement squeeze summary: Suspended well inspection information: Intervals treated (measured): * Well head in good condition with no signs of leakage * Surface location cleared with no hydrocarbons Treatment descriptions including volumes used and final pressure: * Well Pressures: - Tubing = none - Inner annulus = 0 psi - Outer annulus = 0 psi 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 NA Subsequent to operation: 0 0 0 0 NA 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory 0 • Development ❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil J Gas H WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 • SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature i.. 2 ,4M� , 6 Phone (907) 283 -1371 Date October 27, 2010 NOV 0 �� Form 10 -404 Revised 10/2010 �� 'rY Submit Original Only Abalone #1 Ninilchik Field MARATHON Permit* 202-129 250' FSL, 3,000' FEL, API #: 50-133-20517-00-00 Sec. 29, T2N, R12W, SM Property Des: Tubing (2 joints) KB Elevation: 92.35' 4 -1/2" 12.6 L -80 Mod IBT Spud Date: 01/30/03 Top Bottom Rig Released: 03/09/03 @ 12:00 hrs MD 0' "'81' Lat: 60° 13' 42.50" North Long: 151° 24' 2.12" West TVD 0' — 81' Well Suspended Conductor 20" K -55 133 ppf PE Top Bottom MD 0' 170' TVD 0' 170' Surface Casing Inhibited 6% KCL ► 13 -3/8" K -55 68 ppf BTC Top Bottom MD 0' 2,208' TVD 0' 2,098 ' 17 -1/2" holecmt /w ± 992 sks 12 ppg cmt. Cmt fell. WOC. Pumped top job @ 350' MD with 335 sks 15.8 ppg recovering 20 bbls cement to surface. Class "G" cement: 75 sks 15.8 ppg "'' , Top estimated @ 4,233' MD. Intermediate Casing Bottom estimated @ 4,436' MD. 9 -5/8" 40 ppf L -80 BTC Top Bottom MD 0' 4,336' TVD 0' 4,194' 12-1/4" hole cmt /w ±135 sks of 12 ppg & 550 sks of 13.5 ppg Baker Cement Retainer set @ 4,283' MD 9.5 ppg Flo Pro Fresh Water Mud TD PBTD 10,356' MD —4,233' MD 10,203' TVD —4,091' TVD Well Name & Number: Abalone #1 Lease: County or Parish: Kenai Peninsula Borough State: Alaska Country:I USA Perforations: (MD) TVD: Angle @ KOP and Depth: — 3° / 185 ft @ 555' MD Angle Perfs: NA Date Suspended: 3/9/2003 Completion Fluid: 6% KCL Revised By: Kevin Skiba Last Revision Date: 10/27/2010 • • Ninilchik Unit, Abalone -1 13 ) 17 16 15 NI iILCHIKUNIT 24 19 20 21 22 T2N 2W 25 30 29 28 27 \ ABALONE -1 SURFACE LOCATION 1/4 MILE R4DIUS 0 36 31 32 33 34 COOK KENAI INLET PENINSU • M o r 1 6 o Q i. ..40" MARATHON ALASKA PRODUCTION LLC 1:12000 0 1 KILOMETRES ABALONE - 0 0.50 NINILCHIK UNIT MILES `J KENAI PENINSULA N� Lea. vme 4(ENG26734) ALASKA Na g� [1 500000 W 6.0000"1 I Alaska CS" zone 4 1 ■ v + - i ti ' �4.. a. s .' R •`` x.. ;. .'yam." .qi 4 ... .. ♦ • ' ` ' R 1., :� t � • ..* " f.�yy 1► "will 1� 7. '• ••• 1 = "1 . fY ; ^' ma +3 a 1 ' 'i '" , ., = J YT+ :*. � • w diligiLs . , ; , z -. ... . ; 7,..- ,..- .. ...:: ... ' -' . " ', :" '''''''' . a h 01.. . 4 'Y 0 ! rJ f': Z, �'�' . -,;•-... s , t • i o _ ,sn„z „. '•:2 4 1': $:,...A *t0-•" i 1 s t 1f , r '` s A,= n�+ • - *lost MARATHON OIL = . 3 1T - ABALONE #1 1 -.: * � ;,, • ; : J;,: PERMIT NO. 202 -129 ' '` X ' t`r' � • API NO. 50- 133- 20517 -00 , � � • • � 1. .� .�� .. ._ r n. : ." .4; 4 SURFACE LOCATION: s • . r A, SE1 /4; SW1 /4; SEC 29, T2N; R12W, S.M. .: .-- w -: • : r 1 /► ( 1 • .,l S •./ / f fi - »w�' ti "" # I t a fly " t•�! A ;•- ; r . lows 4404, 0140 • • • . . • • • v 4 i *I s 3 44,F;f, t rt g ti ! 41' ■ - • ` r �' rs� `�A3a. �` S� r ` ,a g f tfEk 4• • • +. .wr , $ F .� n " . FF`Y `riakf., ,. al J, t , '.,�', f e • A -' ...4' .4 •'-'' r • NSF // fy • ' I II. �L A / 1rt♦ , Ifr - ' ' , , ' ' . ' - ....040,4,0r4104,r0.*'.00".7°. '4* ' .rte �� + s �rf 11'',"•:,. 11'7 • L� `� . 4. i ,/ 1 . 1.„ 4. # ` 7/7/ ./ , Joe « .~ . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill, Commissioner "",tAJ DATE: February 8, 2003 THRU: Tom Maunder, P. I. Supervisor II ¢~~I ~<r <J-r ci:0 SUBJECT: at) ~- I À..C( Top Cement Job Marathon Oil Co. #1 FROM: John Crisp, Petroleum Inspector Februarv 8, 2003: I traveled to Marathon Oil Glacier #1 Drilling Rig to witness the Top Cement job on Surface Casing for Abalone #1. Marathon Rep. Roland Lawson contacted AOGCC to inform the Commission that cement was not circulated to surface on Abalone #1. Marathon was granted permission to top off the 13 3/8" surface casing. I witnèssed 1 %" Hydril tbg. run tö a depthof350' outside surface casing. I witnessed 68 BBL's of 15.8 PPG. Class G cementpumped@ a rate of 3.2 BPM 2000 PSI. Cement job was complete wI returns to Surface. SCANNEO JUN 1 ·1 Summary: I witnessed a successful Top Job performed on the Surface casing for Abalone #1. Attachment: None CONFIDENTIAL Top CmtJob Marathon Abalone #l.doc e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc q ~ ~(j ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2021290 Well Name/No, ABALONE 1 Operator MARATHON OIL CO API No. 50-133-20517-00-00 MD 10356 ,,/ TVD 10203 / Completion Date 3/9/2003"- Completion Status SUSP Current Status SUSP UIC N -~------ -------.,--- Mud Log Yes Samples No Directional Survey Q __ _cc'-, REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) -.- Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments I ! I Rpt Daily Operations ~ Report: Final Well R ~ Mud Log ¥g Mud Log ! 1ED C Pds 12071 Mud Log r :-'ED C Pds "'12071 Mud Log lED C Las '12071 See Notes V ~ Notes lED C Pds m068 Cement Evaluation ¡ED C Asc 12068 Directional Survey I ED C Pds 12068 Sonic i ¡ED C Asc 12068 LIS Verification ! lED C Asc 12068 LIS Verification i i I lED C Pds 12068 I nd uction/Resistivity ! ¡ED C Pds 12068 Sonic ! ¡ 0 0 5/13/2003 1/23/03 - 3/10/03 0 0 5/13/2003 2 Col 170 10356 cW 5/13/2003 In Well History File w/Final .~ 5/13/2003 Well Report 2 Co I 170 10356 In Well History File w/Final Well Report 2 170 10356 ~*' 5/13/2003 2 170 1 0356 çk 5/13/2003 2 10400 ÇJ1f' 5/13/2003 Drilling Dynamics Log 10400 'c~ 5/13/2003 Drilling Dynamics Log ---, 5 1210 4180 Case 5/13/2003 1960 10356 5/13/2003 2 123 4357 5/13/2003 Dipole Sonic, Best DT Processing 123 4357 5/13/2003 Dipole Sonic, Best DT Processing 2180 4357 5/13/2003 ProcessedAIT-H, Corkscrew Filter 2 2180 4357 5/13/2003 ProcessedAIT-H, Corkscrew Filter 2 4300 10356 5/13/2003 Quad Como BAT Socin SEMB VDL --~---- -~----- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2021290 Well Name/No, ABALONE 1 Operator MARATHON OIL CO MD 10356 TVD 10203 Completion Date 3/9/2003 Completion Status SUSP Current Status SUSP ED C Las 12068 LIS Verification 4200 5/13/2003 ED C Pds 12068 I nd uction/Resistivity 12 150 4338 5/13/2003 ED C Pds 12068 I nd uction/Resistivity 12 150 4338 ED C Pds 12068 Cement Evaluation 2 ED C Pds 12068 Cement Evaluation 2 ED C Pds 12068 Neutron 25 2208 4328 Case 5/13/2003 2208 4328 Case 5/13/2003 150 4238 ~ 5/13/2003 u~- 4238 ~e 5/13/2003 ED C Pds 12068 Density 25 150 Well Cores/Samples Information: Na~ le'lrttings Interval Start Stop 2210 10356 Sample Set Number Comments Sent Received 3/18/2003 ¿m3 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 10/7/2002. ADDITIONAL INFORMATION Well Cored? y~ Chips Received? ~ Daily History Received? ÐN ~N Formation Tops Analysis Received? ~ Comments: API No. 50-133-20517-00-00 UIC N Compensated Neutron, Three Detector Density, Platform Express Array Induction Tool, Reprocessed Curves - Platform Express Array Induction Tool, Reprocessed Curves - Platform Express. Additional ROP/DGRlEWR - MD + TVD on this Disc. UltraSonic Imager Cememt Bond Log Integrated Hole & Cement Volume Log Compensated Neutron, Three Detector Density, Platform Express. Additional DGRlCTN/SLD - I MD + TVD on this Disc. I Compensated Neutron, Three Detector Density, Platform Express. Additional DGRlCTN/SLD - MD + TVD on this Disc. .r-~~ ----. -~---~---- ----- Permit to Drill 2021290 MD 10356 TVD 10203 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Well Name/No, ABALONE 1 Operator MARATHON OIL CO Completion Date 3/912003 Completion Status SUSP Current Status SUSP Date: API No. 50-133-20517-00-00 UIC N ------ ---------- "-~-=... ~--- , , M MARATHON ~ ( Marathon Oil Company .{ Alaska Asset Team Northern Business Unit P.O, Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-6175 December 28, 2004 RECEIVED JAN 0 6 2005 0·, & Gas Cons. Commisstoß A\asKa I Anchorage Steve McMains AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. McMains: Attached is the Form 10-407 Application for Sundry Approval for suspension of the Abalone #1 well. Also attached for your records is the current well schematic and directional survey data, If you would like any other information, please contact me at 907-283-1311 or kdwalsh@marathonoil.com. Sincerely, \ ÚAA- D. w JLJl- Ken D. Walsh Advanced Production Engineer Enclosures STATE OF ALASKA ... F)ECEIVED ALASKÍ. .L AND GAS CONSERVATION COMMIS( \I L~\N 0 6 Z005 1a. Well s~ELL o~O~a~6E!:~~ O~a~o:fuOM ~~;nT.~~N W~Gif1?~~I~~r~I,~~~", Cons. Commissi 20AAC 25.105 20AAC 25.110 Development 0 ExptQrg~åQb GINJ D WINJ D WDSPLD No. of Completions Other Service D Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: MARATHON OIL COMPANY Aband.: 03/09/03 202-129 3. Address: 6. Date Spudded: 13. API Number: ö ~ t\G P. O. Box 1949, Kenai, AK 99611-1949 January 30, 2003 50-133-20517-,Qo1'" 4a. Location of Well (Governmental Section): 7. Date TO Reached: 14. Well Name and Number: Surface: 250' FSL & 3000' FEL Sec. 29 T2N-R12W, S.M. October 17, 2004 Ninilchik Unit, Abalone #1 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 496' FNL & 3109' FEL Sec. 32 T2N-R12W, S.M. 266' Ninilchik/Beluga-Sterling. 9. Plug Back Depth(MD+ TVD): (abandoned) 4233' 4091' 10. Total Depth (MD + TVD): 16. Property Designation: Zone- 4 10356' MD 10203' TVD Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Zone- 4 Total Depth: 287' FNL & 3181' FEL Sec 32 T2N-R12W, S.M. 4b. Location of Well (State Base Plane Coordinates): Surface: x- 245392 y- 2278133 TPI: x- 245283 y- 2277385 Total Depth: x- 245211 y- 2277597 18. Directional Survey: Yes ~ No D Tyonek 19. Water Depth, if Offshore: 20. Thickness of Permafrost: feet MSL SCHLUMBERGER PEXlAITH RUN #1; SCHLUMBERGER DSI/GR RUN #2; SPERRY SUN LWD GR-RES/DEN-NEUT/SONIC RUN #3 21. Logs Run: 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD 20" 133# K-55 0' 170' 0' 170' 17-1/2" Driven 13-3/8" 68# K-55 0' 2208' 0' 2098' 17 -1/2" in place, 1327 sx 9-5/8" 40# L-80 0' 4336' 0' 4194' 12-1/4" in place, 685 sx AMOUNT PULLED N/A N/A N/A N/A N/A N/A 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None SIZE 4-112" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 63' MD 24. 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4233'-4436' 75 sks15.8 ppg Class G cement w/adds 4283' Baker 9-5/8" Cement Retainer 26. Date First Production: PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ..... 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". , ~j:/;;'þ , ~rji;' ~~::~:;:~,'"~".;: RBDMS BFL ~JAN jo 2005 ()R\G\NAL Form 10-407 Revised 12/2003 CONTINUED ON REVERSE C); NAME GEOLOGIC MARKERS ~( TVD 29. Include and briefly SUr detailed supporting da.~ 2930 "None". 3098 6448 FORMATION TESTS 'ize test results. List intervals tested, and attach .~3 necessary. If no tests were conducted, state 28. Sterling Gas Beluga Tyonek 3071 3240 6590 None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ken D. Walsh Printed Name: Ken D. Walsh n n Signature: l ~ 'D, u.J~ Title: Advanced Production Engineer Phone: 907-283-1311 Date: 12/28/2004 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 Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional in Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 on 01/30/2003 212812003 Date: 03/09/2003 2 jQints 4-1/2" [Baker Cement Retainer MD L-SO TQP ppf 12·1/4" +1- 12 TD: 12.6 O'TVD 13.5 12 Mod IBT Abalone #1 ') ) Final Directional Survey Data MD (ft) Inc (deq) Azi (deq) TVD (ft) N/S (ft) EIW (ft) V.Sec. (ft) DLeq (deq/100ft) TFace (deq) Build (deq/100ft) Turn (deq/100ft) 0 0 0 0 0 0 0 0 0 0 0 196 0.35 311.7 196 0.4 -0.4 -0.2 0.18 0 0.18 0 255 0.26 314.1 255 0.6 -0.7 -0.4 0.15 173.12 -0.15 4.07 287 0.44 48.7 287 0.7 -0.6 -0.5 1.65 123.95 0.56 295.63 345 0.35 78.9 345 0.9 -0.3 -0.8 0.39 127.99 -0.16 52.07 406 0.5 303.9 406 1.1 -0.3 -0.9 1.29 -153.32 0.25 -221.31 467 0.35 320.1 467 1.4 -0.7 -1.1 0.31 149.21 -0.25 26.56 526 2.5 187.3 526 0.3 -1 0.1 4.66 -138.16 3.64 -225.08 555 3 184.6 554.9 -1.1 -1.1 1.4 1.78 -15.88 1.72 -9.31 585 4.1 186.9 584.9 -3 -1.3 3.2 3.7 8.53 3.67 7.67 647 5.4 187.3 646.7 -8.1 -1.9 8.3 2.1 1.66 2.1 0.65 706 6.7 188.8 705.3 -14.2 -2.8 14.4 2.22 7.68 2.2 2.54 767 7.7 189.1 765.9 -21.8 -4 21.9 1.64 2.3 1.64 0.49 826 9.5 188 824.2 -30.5 -5.3 30.6 3.06 -5.77 3.05 -1.86 890 10.6 189.9 887.2 -41.5 -7 41.6 1.79 17.71 1.72 2.97 954 12.6 190.5 949.9 -54.2 -9.3 54.3 3.13 3.75 3.12 0.94 1016 14 187.8 1010.2 -68.3 -11.6 68.4 2.47 -25.24 2.26 -4.35 1078 16.3 187.2 1070.1 -84.3 -13.7 84.3 3.72 -4.19 3.71 -0.97 1140 18.4 184.9 1129.3 -102.7 -15.6 102.3 3.56 -19.19 3.39 -3.71 1202 20.6 182.3 1187.7 -123.4 -16.9 122.3 3.81 -22.76 3.55 -4.19 1264 22.3 183.1 1245.4 -146 -18 144.1 2.78 10.14 2.74 1.29 1326 24.8 181.7 1302.2 -170.8 -19 167.9 4.13 -13.26 4.03 -2.26 1386 26 185.5 1356.4 -196.4 -20.6 192.7 3.37 55.37 2 6.33 1449 26.8 185.6 1412.9 -224.3 -23.3 220 1.27 3.23 1.27 0.16 1511 26.9 187.5 1468.2 -252.1 -26.5 247.4 1.39 84.2 0.16 3.06 1576 27.6 193 1526 -281.4 -31.8 276.8 4.02 76.92 1.08 8.46 1640 27.3 195.2 1582.8 -310 -39 306.2 1.65 107.45 -0.4 7 3.44 1700 26.6 197.1 1636.3 -336.1 -46.6 333.3 1.85 129.95 -1.17 3.17 1733 26.1 197.8 1665.8 -350.1 -51 348 1.78 148.46 -1.52 2.12 1761 25.8 196.9 1691 -361.8 -54.6 360.2 1.77 -127.7 -1.07 -3.21 1797 25.1 195.1 1723.5 -376.6 -58.9 375.7 2.9 -132.95 -1.94 -5 1822 24.7 192.5 1746.2 -386.9 -61 .4 386.2 4.66 -111.25 -1.6 -10.4 1860 24.1 190.9 1780.8 -402.2 -64.6 401.8 2.35 -132.96 -1.58 -4.21 1888 24.6 187.2 1806.3 -413.6 -66.4 413.1 5.73 -73.54 1.79 -13.21 1952 25 188.2 1864.4 -440.2 -70 439.5 0.91 46.81 0.62 1.56 1982 24.8 186.7 1891.6 -452.8 -71.6 451.9 2.21 -108.25 -0.67 -5 2014 24.6 188.2 1920.7 -466 -73.4 465 2.06 108.38 -0.62 4.69 2045 24.2 188.5 1948.9 -478.7 -75.2 477.6 1.35 162.92 -1.29 0.97 2076 24.3 187.3 1977.2 -491.3 -77 490.1 1.62 -79.08 0.32 -3.87 2158 24 188 2052 -524.5 -81 .4 523 0.51 136.65 -0.37 0.85 2231 23.9 185.8 2118.7 -554 -85 552 1.23 -97.39 -0.14 -3.01 2295 23.5 185.5 2177.3 -579.6 -87.5 577.1 0.65 -163.36 -0.62 -0.47 2357 22.3 185.5 2234.4 -603.6 -89.8 600.6 1.94 180 -1.94 0 2419 21.2 185.1 2292 -626.5 -92 623 1.79 -172.51 -1.77 -0.65 2482 19.21 186.9 2351.1 -648.1 -94.2 644.2 3.31 163.49 -3.16 2.86 2545 16.4 190.4 2411.1 -667.1 -97.1 663.1 4.77 160.81 -4.46 5.56 2607 14 191.1 2470.9 -683.1 -100.1 679.2 3.88 175.96 -3.87 1.13 2669 12.6 187.1 2531.3 -697.2 -102.4 693.3 2.7 -148.62 -2.26 -6.45 2731 10.6 187.9 2592 -709.5 -104 705.5 3.24 175.79 -3.23 1.29 2793 8.4 189.3 2653.2 -719.6 -105.5 715.6 3.57 174.69 -3.55 2.26 2855 6.8 188.3 2714.6 -727.8 -106.8 723.7 2.59 -175.77 -2.58 -1.61 2918 6 189.7 2777.2 -734.7 -107.9 730.6 1.29 169.66 -1.27 2.22 2980 5.6 184.8 2838.9 -740.9 -108.7 736.7 1.03 -131.35 -0.65 -7.9 3042 4.2 182.6 2900.7 -746.2 -109 741.8 2.28 -173.45 -2.26 -3.55 3105 3.3 191.8 2963.5 -750.3 -109.5 745.9 1.71 150.77 -1.43 14.6 3169 2.4 204.5 3027.5 -753.3 -110.4 749 1.71 151.18 -1.41 19.84 3231 2.4 198.5 3089.4 -755.7 -111.4 751.6 0.41 -93 0 -9.68 3294 1.3 199.5 3152.4 -757.6 -112 753.7 1.75 178.82 -1.75 1.59 3356 1 154.9 3214.4 -758.8 -112 754.7 1.48 -129.94 -0.48 -71.94 3417 1.1 143.3 3275.4 -759.7 -111.5 755.5 0.38 -70.68 0.16 -19.02 3481 0.8 132.4 3339.3 -760.5 -110.8 756 0.55 -154.31 -0.47 -17.03 3543 0.9 154.4 3401.3 -761.2 -110.2 756.5 0.55 84.16 0.16 35.48 3611 0.6 161.2 3469.3 -762.1 -109.9 757.2 0.46 166.86 -0.44 10 3668 1.1 156.3 3526.3 -762.8 -109.6 757.8 0.89 -10.73 0.88 -8.6 3730 0.9 160.2 3588.3 -763.9 -109.2 758.6 0.34 163.15 -0.32 6.29 3793 1 177.4 3651.3 -764.9 -109 759.5 0.48 79.41 0.16 27.3 3855 1.1 174.9 3713.3 -766 -108.9 760.6 0.18 -25.87 0.16 -4.03 Abalone #1 ) ) Final Directional Survey Data MD (ft) Inc (deq) Azi (deq) TVD (fO N/S (ft) EIW (ft) V.Sec. (ft) DLeQ (deq/100ft) TFace (deQ) Build (deq/100ft) Turn (deq/100ft) 3917 1.2 171.1 3775.3 -767.2 -108.8 761.7 0.2 -39.24 0.16 -6.13 3980 1.4 160.2 3838.3 -768.6 -108.4 762.9 0.5 -56.57 0.32 -17.3 4041 1.1 160.9 3899.3 -769.9 -107.9 763.9 0.49 177 .44 -0.49 1.15 4103 1.4 141.9 3961.2 -771 -107.3 764.8 0.82 -63.85 0.48 -30.65 4166 1.5 150.7 4024.2 -772.3 -106.4 765.8 0.39 70.26 0.16 13.97 4229 1.6 139.4 4087.2 -773.7 -105.4 766.8 0.51 -77.59 0.16 -17.94 4290 1.3 135.5 4148.2 -774.9 -104.4 767.6 0.52 -163.73 -0.49 -6.39 4371 1.2 152.4 4229.2 -776.3 -103.4 768.6 0.47 113.52 -0.12 20.86 4434 0.9 153.1 4292.1 -777.3 -102.8 769.4 0.48 177.9 -0.48 1.11 4625 0.9 181.6 4483.1 -780.1 -102.2 771.8 0.23 104.25 0 14.92 4810 0.8 266 4668.1 -781.7 -103.5 773.7 0.62 135.91 -0.05 45.62 4997 0.6 249.8 4855.1 -782.1 -105.7 774.8 0.15 -143.21 -0.11 -8.66 5182 0.5 219.2 5040.1 -783.1 -107.2 776.2 0.17 -123.68 -0.05 -16.54 5370 0.6 150 5228.1 -784.6 -107.2 777.6 0.34 -117.09 0.05 -36.81 5558 0.5 59.6 5416.1 -785 -106 777.7 0.42 -140.36 -0.05 -48.09 5747 0.9 104.3 5605.1 -785 -103.8 776.9 0.34 77.55 0.21 23.65 5874 0.2 70.9 5732.1 -785.1 -102.7 776.7 0.58 -171.46 -0.55 -26.3 6059 0.6 75.8 5917.1 -784.8 -101.4 776 0.22 7.34 0.22 2.65 6245 0.4 88.8 6103 -784.5 -99.8 775.2 0.12 156.83 -0.11 6.99 6431 0.7 335.9 6289 -783.5 -99.6 774.2 0.5 -136.2 0.16 -60.7 6617 0.8 359.1 6475 -781.1 -100.1 772.1 0.17 83.61 0.05 12.47 6804 1 321.9 6662 -778.6 -101.1 770 0.32 -90.33 0.11 -19.89 6990 1.1 0.2 6848 -775.5 -102.1 767.4 0.37 101.34 0.05 20.59 7178 1.2 325 7035.9 -772.1 -103.3 764.5 0.37 -99.79 0.05 -18.72 7366 1.6 339.5 7223.9 -768 -105.3 761.3 0.28 48.93 0.21 7.71 7448 1.9 327.9 7305.8 -765.8 -106.4 759.6 0.56 -55.63 0.37 -14.15 7678 2.1 340.5 7535.7 -758.6 -109.9 753.9 0.21 71.93 0.09 5.48 7866 2.8 343.7 7723.5 -750.9 -112.3 747.4 0.38 12.66 0.37 1.7 8051 3.4 339.8 7908.3 -741.4 -115.5 739.4 0.34 -21.32 0.32 -2.11 8115 3.3 337 7972.1 -738 -116.8 736.6 0.3 -122.82 -0.16 -4.37 8175 3.3 341.6 8032.1 -734.7 -118.1 733.9 0.44 92.3 0 7.67 8241 3.7 348.2 8097.9 -730.8 -119.1 730.5 0.86 48.53 0.61 10 8304 3.6 344 8160.8 -727 -120.1 727.2 0.45 -112.59 -0.16 -6.67 8367 4.1 347.5 8223.7 -722.9 -121.1 723.6 0.88 26.93 0.79 5.56 8429 4.1 348.9 8285.5 -718.5 -122 719.8 0.16 90.7 0 2.26 8489 4.3 349.6 8345.3 -714.2 -122.8 716 0.34 14.73 0.33 1.17 8553 4.3 344.7 8409.2 -709.5 -123.9 711.9 0.57 -92.44 0 -7.66 8612 4.2 348.6 8468 -705.3 -124.9 708.2 0.52 111.02 -0.17 6.61 8678 4.3 350 8533.8 -700.5 -125.8 703.9 0.22 46.75 0.15 2.12 8717 4.5 347.2 8572.7 -697.5 -126.4 701.3 0.75 -48.45 0.51 -7.18 8738 4.1 346.5 8593.6 -696 -126.8 700 1.92 -172.87 -1.9 -3.33 8800 4.5 350 8655.5 -691.5 -127.7 696 0.77 35.02 0.65 5.65 8863 4.7 344.7 8718.3 -686.5 -128.8 691.7 0.75 -67.46 0.32 -8.41 8927 5.1 348.2 8782 -681.2 -130.1 687 0.78 38.53 0.62 5.47 8988 5.2 345.4 8842.8 -675.9 -131.3 682.4 0.44 -69.7 0.16 -4.59 9050 4.1 341.9 8904.6 -671.1 -132.7 678.3 1.83 -167.28 -1.77 -5.65 9113 4.4 342.6 8967.4 -666.6 -134.1 674.5 0.48 10.16 0.48 1.11 9175 4.7 340.2 9029.2 -662 -135.7 670.6 0.57 -33.6 0.48 -3.87 9237 4.5 334.5 9091 -657.4 -137.6 666.9 0.8 -116.45 -0.32 -9.19 9300 5 337 9153.8 -652.6 -139.8 663 0.86 23.74 0.79 3.97 9363 5.3 333.1 9216.5 -647.5 -142.2 658.9 0.73 -51.36 0.48 -6.19 9424 5.4 333.8 9277.3 -642.4 -144.7 654.9 0.2 33.48 0.16 1.15 9486 5.5 338 9339 -637 -147.1 650.6 0.66 78.02 0.16 6.77 9548 6.2 341.2 9400.7 -631 .1 -149.3 645.7 1.25 26.58 1.13 5.16 9610 6.5 341.6 9462.3 -624.6 -151.5 640.2 0.49 8.59 0.48 0.65 9672 6.4 341.2 9523.9 -618 -153.7 634.7 0.18 -156 -0.16 -0.65 9735 6.3 342.6 9586.5 -611 .4 -155.9 629.1 0.29 123.55 -0.16 2.22 9799 6.5 343 9650.1 -604.6 -158 623.3 0.32 12.77 0.31 0.62 9862 6.7 343.3 9712.7 -597.6 -160.1 617.4 0.32 9.93 0.32 0.48 9920 6.8 340.5 9770.3 -591.2 -162.2 612 0.59 -74.49 0.17 -4.83 9982 7.4 343.3 9831.8 -583.9 -164.6 605.8 1.12 31.37 0.97 4.52 10045 7.3 340.2 9894.3 -576.2 -167.1 599.4 0.65 -105.69 -0.16 -4.92 10106 7.5 341.6 9954.8 -568.8 -169.7 593.2 0.44 42.73 0.33 2.3 10169 7.8 340.2 10017.2 -560.9 -172.4 586.6 0.56 -32.54 0.48 -2.22 10231 7.9 340.2 10078.6 -552.9 -175.3 579.9 0.16 0 0.16 0 10294 7.9 339.5 10141.1 -544.8 -178.2 573.2 0.15 -90.35 0 -1.11 10356 7.9 339.5 10202.5 -536.8 -181.2 566.6 0 0 0 0 MEMORANDUM TO: Jim Regg V.. ÐiZkQ4--- P.I. Supervisor 'ì't b FROM: John Crisp Petroleum Inspector Well Name: ABALONE 1 Insp Num: mitJCr040810185805 Rei Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 1 ABALONE 1 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-133-20517-00-00 Permit Number: 202-129-0 ") d.-O d-- ~ t 'J-f Reviewed By: P.I. Suprv Sf¥-- Comm Inspector Name: John Crisp Inspection Date: 8/9/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Type Inj. s TVD IA 0 2820 2750 2740 P.T. 2021290 TypeTest SPT Test psi 1596.5 OA 140 480 470 460 Interval INITAL P/F p Tubing 1800 1800 1800 1800 Notes: Hi Bob, this well is actually PBU 8-116 #2031810. V· Wednesday, August 11,2004 Page 1 of 1 ) ) Alaska Region Domestic Production , ~ M MARATHON 4 Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 December 24, 2003 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr, Aubert: Attached is the ~rm 10-403 Application for Sundry Approval for operation shutdown of the Abalone #1 well. Also attached for your records is the well schematic after shutdown, After this well reached TD on 02/28/2003 and open hole logs were run, the open hole was plugged back into the 9-5/8" intermediate casing, Although commercial quantities of gas were not realized from the Tyonek, a decision was made to evaluate the uphole Beluga and Sterling gas intervals for future completion. Marathon is currently evaluating completion strategies to access these pay intervals with emphasis on minimizing formation sand production. The evaluation and planning for this completion is on-going, It is anticipated that wellwork should begin early August 2004. / I appreciate your patience in the late submission of the Form 10-403 request. If you would like any other information, please contact me at 907-283-1311 or kdwalsh(ã2 marathonoil,com. Sincerely, .~~~,w~ Enclosure RECE\VED JAN \) 6 1.ÜÜ4 Comffi\SS\On 0'\ & Gas Cons, A\as\t.a \ ~nchofa~e Ken D, Walsh Advanced Production Engineer OR\G\NAL STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSIOI'J APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 9. Well name and number: Abalone #1 10. Field/Pools(s): Beluga. Tyonek (abandoned). PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): .,. '" 1. Type of Request: Abandon D Suspend Well D Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: MARATHON OIL COMPANY 3. Address: P. O. Box 196168, Anchorage, AK 99519-6168 7. KB Elevation (ft): 266 fee~ 8. Property Designation: 11. Total Depth MD (ft.) Casing Structural Conductor Surface I ntermed iate Production Liner Perforation Depth MD (ft): Size Length 20" 13-3/8" 9-518" NIA NIA Perforation Depth TVD (ft): Packers and SSSV Type: ) ';-.J0)A- I I (p / '7--(.)0 'I. DIS'¡ / b/ f-- qf (/~ Operation Shutdown[] perforateD varianceD Annular DisposalD Plug perforationsD StimulateD Time ExtensionD OtherD Perforate New Pool D 4. Current Well Class: Re-enter Suspended Well D 5. Permit to Drill Number: " 202-129 6. API Number/ 50- 133-20517-00 Development Exploratory ~ Stratigraphic Service Plug (measured): Junk (measured): MD Collapse TVD Burst 170 22QO-··'-" .", ) /"'?2~p"/ \",.<::.-"" 3060 5020 5750 1500 2260 3090 170 2098 3425 Tubing Size: Tubing Grade: 4-1/2" L-80 Packers and SSSV MD (ft): Tubing MD (ft.): 62 12. Attachments: Description Summary of Proposal rx- Detailed Operations Program D BOP Sketch ~ 14. Estimated Date for Commencing Operations: ~!Jj2cró4 2. I ~, ~·I () 'S 13. Well Class after proposed work: Exploratory EJ Development D Service D 15. Well Status after proposed work: Oil D GasD PluggedD Abandoned D 16. Verbal Approval Date: WAG D GINJD Commission Representative 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Ken D. Walsh Signature WINJD WDSPL D Title Advanced Production Engineer Phone 907-283-1311 Date 12/24/2003 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -=:t~ Lf -- C ¿i/ Plug Integrity D BOP Test D Mechanical Integrity Test D RCCCIVCD' Location Clearance D JAN 0 6 2004 Alaska ai' & Gas Cons, Commission 10 - !.fD 4- ~-- BY ORDER OF DatAe..nChora, g ~" ~()' ~. . O h' . ~ $, cd Bu COMMISSIONER THE COMMISSION J I-.~II\,JI 190 , Form 10-403 Revised 2/2003 Sarah Palin 0 RIG I N /4. L __ BfL it :;¡'p~ Other: Subsequent Form Requested: Approved by: API # 50-133-20517-00 Permit # 202-129 WBS # OX.02.07227.CAP Abalone #1 Wildcat Field 250' FSL, 3000' FEL, Sec, 29, T2N,R12W, SM ....IIIIIi \ ... ~ Inhibited 6% KCl ~ Class "G" cement with addltiv~ Top estima.ted at 4233' MD. Bottom est. at 4436' MD. I Baker Cement Retainer set at Intermediate Casing 9·5/S" L·SO Top 40 ppf BTC Bottom 12·1/4" hole with +/·135 sks 12 ppg + 550 sks 13.5 ppg 9.5 ppg Flo Pro Fresh Water Mud 2 joints ITempOrary Abandonment Diagram Conductor 20" 133 ppf K·55 PE Top Bottom O'MO 170' MO Surface Casing 13·3/S" L-80 Top 0' MO 68 ppf BTC Bottom 2208' MO 17-1/2" hole with +/- 975 sks 12 ppg cement Tubing 4-1/2" 12.6 l-SO Mod IBT O'MO 4250' MO TO: 10,356' MD/10,203' TVD drilled with 6·1/S" PDC Alas~ '3iness Unit ¿)C&-/:;)(i Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 May 2, 2003 Alaska Oil & Gas Conservation Commission Attn: Lisa Weepie 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 HAND DELIVERED RE: Marathon Abalone #1 CONFIDENTIAL Dear Lisa: The Abalone #1 well data listed below are included with this transmittal. Daily Drilling Reports,......,......,.,........,.................,.........,........,......,.... .Paper~'"~"'" BJ Cement Job Report,.""""."".".".""..,..,.,.""",.""",.""".",.",.""", ,PapeF'~""""·'::. MI Report Summary..".,.,."""."",."".""".,.",.",.."""""""."""...""", ,Papev~ MI Water Based Mud Reports ..............................................................PapeV . ' ~i:;!o~~x~~:~¿~~~~~·~t~d· N ~~b:~~~~ Th~~·~· D~t~;t~;' D~~~¡t;;: :g:::~:: " ~~ Integrated Hole & Cement Volume Log.. ,............ ,........ ....,........, ........,Digital i Ð- Ol9.ct3'> Platform Express--Array Induction Tool--Reprocessed Curves,.,..,.,.,.Digital J'()O~~ Dipole Sonic Best DT Processing,...,.,...,.......,.........,........,.,.,...,..,...,.,..DigitalIÐOlJ;~ Processed AIT - H--Corkscrew Filter .,.,..,..,....,..,.,..,..,.,.,.,..,.....,.......... ..Digital./:}. 0l.995, UltraSonic Imager--Cement Bond Log,......,......,......,..........,.,......,...... ,Digital I j()l"'¡ ~ Cement Bond Log - 3/6/03 ....................,.,.................,.........................,Digitall &..OtÇJi~t DGR Dual Gamma Ray--CTN Thermal Neutron Porosity- SLD Stablized Litho-Density (MD & TVD) ,...........,............,......,.........Digitall tJOLa'¡f DGR Dual Gamma Ray-BAT Bimodal Acoustic Tool (MD & TVD)..Digitall ~019ß Rap Rate ofPenetration-DGR Dual Gamma Ray-EWR Electromagnetic Wave Resistivity (MD & TVD) ..............................,...Di~tal il))(,,)L9<6" Epoch Final Well Report",.".,."...".".""",..."",.,.,."",.""""....,.,..,.", .J>íp~r/Digit~ I ~ Ot-I F ormation Log (MD & TVD)...,.,..,.".,..,.,."."",."".,.."."".,.".,.",.,.,....,. ~r/Digitm _ J 9-.0"1- \ Drilling Dynamics Log 2"=100' MD ...........,......,.,.................,.........~.".·Yáper/Digitt;lL 1~C>f' EPOCH LAS data on CD......,..,.........................................,........,........ ,Digita~ e O~ l List of all Digital data on enclosed CD's .........,..........,........................Paper )~'tð{ ~\ ~,...... D :~ JfJO~r tl~O-~O.~ ~-¿L~ LV\¡1 F 1:~L_\~~- ~~~~ () "~~\:") ~\(\ ~~ Page 2 ~.. ( Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address, Thank you, Kaynell Zeman Technical Assistant Received bY~~E)\_~~Â ./V~b __9 ~~.~~\.. Date: Enclosures Hand Delivered Run 1 DIPOLE Final: -¡~ ~;~.;:'~:'-^~-,-, ., ~~,.:,~ ..~[~~~~ .~=_.~~ _~~ ._~.i~.~,- f'-r-;~~~ ~~_--._~.~-_~~~::.:~_ -~_=rM~~f¡;d., ~ ,-~-~=~~.~:. ~·.;l~~ I ~ !r.!~~!:Þ.~~;~!¡~:::i 1, 95B KB DLlS File 212012003 11: 2'1 AM ¡ f!] flnal_bdt ,Ias 1 J 062 KB LAS File 2/20/2003 11: 30 AM i ~ final_bdt, pds 7 J 907 KB PDSView Document 2/20/2003 9: 00 AM rl 2/18/2003 8: 55 AM 2/1 B/2003 B: 55 AM 609 KB PD5View Document 725 KB LAS File r~^ l!d abalone 1__ait_reparcessed_a, pds ~ mab 1__ait_reprocessed}inal, las Run 1 AIT Final: '~'7:~~'[M:qd~F;~~¡--.·~..~-.~~:_~~~-~".J 3/4/2003 9:21 AM .5.ize ! .~ype, . 3 KB PRN File . Name / .r.~.:,,^. ...................'~.........:~..;:.;'...'...... ~¡~~Þ.~l!~~!~~!r..'.p.r.~..l Directional Survey: . . r·· . ... .. ..- ..... . ...... -.. ... ........). .... .. Modified .. -'........ ~. .......~. ., ----'...--- .... -~~, -.. .~- 3/7/20039:31 AM 3/7/2003 11: 15 AM Bond Logs: ~r"~~~e i_~·___~"~-.. '_.~.. ...., .-~. _]___.__....... ?i~~JjyJ~~........ -:"-'_~.... ~..__.~.._.:. ~:~:þ·~·(~·~·~...ï:"ç~T·:9:;·6:~·~·:;~~F:~:~~:·j 2) 772 KB PDSView Document @J Abalone 1 USIT 9.625 inch,PDS 89S9 KB PDSView Document ~~';'-Name-~~---~....__M_'-'----_..,---_·-~-~·l---- S!~; Ty;---wo-'-"--'-'--rM6~f!~º,-----~I D Bond Logs File Folder 4/25/2003 1: 50 PM I:JDírectional Survey File Folder 4/25/20032:25 PM C2J Run 1 AlT Final File Folder 4/25/2003 1 :57 PM CJ Run 1 DIPOLE Final File Folder 4/25/2003 2: 15 PM DRun 1 Final Data File Folder 4/25/20032:12 PM D Run 1 Final Prints File Folder 4/25/2003 2: 14 Pfv1 USperry Data File Folder 4/25/20032:23 PM Cd Sperry Log Images File Folder 4125/2003 2:23 PM MIll ¡¡ ABALONE1~GRP.dlis 18,810 KB DLIS File 3/17/20037:33AM Wi BAT4COMB.JPG 21,621 RB JPG File 4/1/20033:02 PM !!IBATVDL.CGr~1 84,929 KB Paint Shop Pro 6 Image 3/26/2003 7:06 Arv1 Marathon Oil Company Abalone 1 CD Created 4/2003 Disk 1 of3 Contents ( ( Page 3 ..",.2¡,~.~.1.Tye,~,: ... . ·..L,~,Ç.ªìfÎ~~.,:,;r ., 7)639 KB Paint Shop Pro 6 Image 3/21/20032~34 PM 1)021 KB Paint Shop Pro 6 Image 3/21/20032:34 PM 21,530 K6 Paint Shop Pro 6 Image 3/21/20032:35 PI\'1 13)905 KB Pai.nt Shop Pro 6 Image 3/21/20032:35 PM 22)200 KB PaÌflt Shop Pro 6 Image 3/21/20032:36 PM lL813 KB Paint Shop Pro 6 Image 3/21/20032:36 PM CGM Logs: "Nåm~..{.····.·:· , ·s:J:~~~~§~~X~~i~~í¡;t~:~:~:~·:; ~ ABALONEIBATTVO.cgm ~. ABALONE 1 EWRMD ,cgm ~ ABAlONEIEWRTVD,cgm !j ABALONE1NUKMD,cgm ~ ABALONE.lNUKTVO,cgm ··:···'~::':·:..·.I.:.~ödi~.ª:·I.··: 3/15/20039:46 AM '=·'~"·"T-JêJ;~-Vt~Í;;;-'^·""~·~~~~'~~·'·:·' 2312 KB LAS File ,.,,:,1' Sperry Log Images: ~P~~.~y ~.~!~: ~~:·J>i1 ~ ","':':-': ..,,,,,,, " , .Nam~ ;,:::. .' .. ....,;, "j,. f ~ Abalane# 1 proc, LAS ;1Y8~,;;~. T ,,~~':~:~,: ·,,,,,;,,,,,,,,,,,LM.þ',ª.!f.!~~t :;;""",¡,,' 11160 KB PDSView Document 2/18/20032:58 PM 497 KB PD5View Document 2/18/20033:33 PM 21667 KB PDSView Document 2/18/20033:34 PM ,N~~~t",,,~~~,,......... """",..,,,,~*., .,,,,,,,,,,,,.,,,,..,~,:,,,,,,,,,,. ,.. .....··:.::,,:,:1:: fî':, ,......... ........ .......... ................. .................. ............................... ....... ...... t!JAbalone 1 AIT 12, 25inch Reprocessed, PDS ¡ ~ 'At~'~ï~'~';'ï'iHV"ï'2':'2'5'i'~~h':PD'Š""""'"''''''''................, G9 Abalone 1 PORO 12.25inch.PDS Run 1 Final Prints: T"~"~dified ''1(", . .. . .......... 2/17/20039:53 AM 2/14/2003 1 :53 AM 2/14/2003 12:55 AM 2/18/20033: 14 PM ,."".$i~~,l:.r.yp~"'" ... 6)303 KB DLIS File 2261758 KB DLIS File 251311 KB DLIS File 1) 824 KB LAS File Name . ,!..... ....... ..*.... . ,....... ..... ... ...... ., "...."...,...... .." ..... ..,. ... ~~:.............................................................................................................: 1§1Abalone 1 AIT ONLY MainPass 12.25inch,dlis ¡ I~ ·Ã·b·~ï~·~·;1·'65Ï~PEx~Ãi;:··M~¡~p~~·~··ï·2:·2·Š·i·~·~h·:Õ'uS @] Abalone 1 DSI-PEX-AIT Repeat 12,25 INCH.DLIS ~ Abalone 1 DSI -PEX-ONL V MainPass 12. 25inch .Ias Marathon Oil Company Abalone 1 CD Created 4/2003 Disk 1 of 3 Contents \ Run 1 Final Data: ~" Page 4 iI'-' .f\:- ,~~ l~ Modifie..d . H .. 3/19/2003 1 :51 PM '-cr¡~~~~ '~.~'..~.--,~_-c--~--,,~..~'.. .~...._,-'- ~~.~~~--' -~. --~_.. ].-,' ~-.-~·-~li~l}yp~~", BATVDL.EMF 237¡642 KB Paint Shop Pro 6 Image Marathon Oil Company Abalone 1 CD Created 4/2003 Disk 3 of 3 Contents ~perryFinaI2: , .., .. . .. ... . .,.. ... . ':.~N1.::1P!~;.A;:;:,:::;;:;::..'::.::.;::.::.;::;::::::;:. . ";"..,,,,.,...;.H. ..~J""'.'...H."...n.'.;;. .~,i?~ .1.. . TVPE:!.'_"...'H'.. .....~_,~,~..~.._ '0;".1 .,,,~gºifi~.º.. .... ... .......... ··..H _.H.,J,,,.:. '.if . ABAL ONE I-SON ellls ¡ 496} 434 KB DLIS File 3/17/2003 B: 23 AM - . . ±;\J-\)fo'\ Modified 3/21/2003 12:08 PM 3/21/2003 12: 13 PfY1 3/20/2003 7: 09 AM 3/20/20038:13 AM 3/20/20037:59 Afvl 3/20/20038:10 AM ( Marathon Oil Company Abalone 1 CD Created 4/2003 Disk 2 of3 Contents Size Type 9,019 KB Pðint Shop Pro 6 Image 8,047 KB Paint Shop Pro 6 Image 20/398 KB Paint Shop Pro 6 Image 111946 KB Paint Shop Pro 6 Image 19}831 KB Pðint Shop Pro 6 Image 11) 705 KB Paint Shop Pro 6 Image Name ! ~¡ÄiÃCÕÑEiãÃ'TMÕ:~~f"1 EiJ'ABAlÕÑEïï3Ã=r:rvi)~;~¡ §) ABALONE 1 EWRMD. emf ~ ABALONE1EWRTVD.emf ì§] ABALONE lNUKMD.emf èìJ ABALONE 1 NUKTVD.emf EMF Logs: ( Page 5 .. Page 6 Mudlogs: Final Well Report: h' .~..~..." .'_"_"_ .~. ~__ ._._.__". { \ Marathon Oil Company Abalone 1 CD Created 4/2003 Mudlog Disk 1 of 1 Contents . _........._...M .....~.._.. .~._. . ..._____.._...._..... ........ . ....._...~__.........h ._.__...__... .......~...._.____... ...... Name ! I f@jð:~:~~:9:~~::#.T~~~:~~::~:~:~:9.:~±:·:ª~~:::i LAS Data: Name i , ~ abalone 1 ,Ias Log PDF Files: Name : ~ Abalone 1 Mudlog. pdf Morning Reports: ..., ....... n, '.' . I'ktme' II) 2003013t.hl:m 1~2003020 1.htm iiÏlzo030Z02.htm t) 20030200. hl:m il) 20030204 .htm 11120030205. htm f]20030206. htm ,I 20030207. htm '11 Z0030Z08.htm I} 20030209. htm ':lJZ0030210,htm ~20030Z1 Lhtm G20030212.htm ~20030213.htm 1:1) 20030214 .htm II) Z003021S.htm 1)20030216.htm ¡~20030217 'htm II) 20030Z16,htm f)20030219.htm ,~ro030220.htm I'fjZ0030Z21.htm :lJ20030222.htm 'I)ro0302.23.htm I) 20030224. htm t).Z0030225. htm 'IJ 20030226. httn ,1}20030227.htm I)Z0030Z28.htm <112003030 1. htm ,1)20030302. htm 1l20030303.htm ~)Z0030304. htm Size I Type 551 KB Microsoft Word Doc... Modified. 3/12/2003 5: 36 AM ~------~--- L-, Si~e Type 4 j 487 KB LAS File I. Modified 3/8/2003 9: 09 AM r ,...:.,. 5!~'~··~· T·~;Ê~·. n; "",. ..:L.M~djf~i~d.· .. ...... .. . .... :.::"....1 1 OJ 070 KB AdDbe Acrobat DDc, . . 3/8/2003 9: 1 B AM ., ... .. ~I~~ lT~~~· . ---., 27K8 HIM\. Docutl~ent 26 KB HTML Document 26 KB HTNL Document 26 K6 HT",1I. Document 26 K6 HTMl Document 26 KS HTMl Document 26 K6 HTMl Document 26 K8 H1M\. Document 26 K6 HTfY\l D«:ument 26 K6 HT(>;1I. Document 26 KS H1M\. Document 261<B HTML Document 26 KB HTMt. Document 26 KB HTNl Document 26 K6 HTML Document 26 KS HTNl D«ument 26 KB HTM\. Document 26 K8 HTML Document 26 KB HTNl Document 26 K6 HTMt. Document 26 K6 H1Ml Document 26 K6 HTML D«:utnent 26 KB HTMt. D«ument 26 K8 H1M\. Document 26 KB HTtY\l Document 26 KB HTMt. Document 26 KB HTMl Document 26 K6 HTMl Document 26 KS HTf..u. DocuN1ent 26 KB HT(>;1I. Document 26 K8 HTM\. Document 26 KB HTf..u. Document 26 KB HTMt. Document ·l¡"'Odified -r-" 2/1/20035: 10 AM 2/2./2003 ..: 44 AM 213/20033:41 AM 2/4/20035:28 AM 2/5/20033:47 AM 2/6/20036:06 AM 2/8/20037:49 AM 2/8/20035:37 AM 2/9/2003 4:54 AM 2/10/2003 4:"8 AM 2/11/2003 4:46 AM 2/1Z/2003 5;55 AM 2/13/2003 4:16 AM 2/14/2003 2:42 AM 2115/20034:17 AM 2116/2:003 5:52 AM 2/17/Z000 3: 14 AM 2/18/2003 6:34 AM 2/19/2003 4:12 AM 2/20/200'33:40 AM 2/Z1/2003 3:24 AM Z/22/2003 5:23 AM 2/23/2003 3:23 AM 2/24/Z000 3:55 AM 212.5/2003 3:42 PM 212:6/2003 3:14 AM 2/27/2003 5:11 AM 2/28/2003 3:47 AM 3/1/20032:51 AM 3/Z12003 5:22 AM 3/3/2003 5:28 AM 3/4/2003 5:44 AM 315/20036:14 AM ....... ...........". .. ,,,. '_"'m"""'M,~J?'~,,,(~yI~E,,~,,,,,",«,"_.,,.._..,,..;...,.,._,_...,"~,_.w".~ -..~98!f,!~EJ,~~-".,;;_.._,~_". .cr.,;,,·.~ 13J972 KB DBF File 3/1/20033:25 AM 1 KB HDR File 3/8/2003 8: 26 AM 173 KB MDX File 3/8/2003 10: 35 AM 1 KB DBF File 2/22/2003 '2: 35 PM 6 KB MDX File 2/22/2003 '2: 35 PM 571 KB DBF File 2/28/2003 10:21 AM 170 KB MDX File 2/28/2003 10:21 AM 45 KB DBF File 3/2/2003 3: 57 PfY1 15 KB MDX File 3/2/2003 3: 57 PM ., ......,.~¡.~;.. ,I... Type .................................. ····················..ï····M:~~·;f¡·~~ .............................................::::. 63 KB Text Document 3/10/2003 10: 13 AM 74 KB Text Document 3/10/2003 10: 14 ArVl RW Explorer Files: Name J ... .. .~L((¡«H~'" .".. .,..""..... '",",',,,' ···...,...........w.....""w.,..'"W..·h,...., ,......"....,;,. ...... ..,~...~...,.......,;..........w..y..w.."",:v..w.........w.:..J ...,.....,~.. rn l'.T(li~ [!J Ab 1. dbf [!J Ab1.hdr ¡-< l!] AB1.mdx ~ AB1_5CL,DBF f"""', ~ AB1_5CL,MDX r"-" 1.!.1 AB 1_ TVD . DBF ~ AB1_TVD.MDX ~ AB1R,DBF ~AB1R.MDX t Name I ŒJ AB 1 Lithology, txt ¡~ AB 1 Remarks. txt .......", .. ........ Remarks & Lith Files: Marathon Oil Company Abalone 1 CD Created 4/2003 Mudlog Disk 1 of 1 Contents { ( Page 7 ",'-11 ( ( C1Ô8-1~1 l' ,. . ISO 9001 Certified Œ'\:·'1t:.".U,..".'....I,..'.".,,"'.'...'"'.. / l';.l:}~.}¡.:f>¡:r:::.?'L';'!:;;.:'~~~ / j i ~~"'; ·~if ,I ,I' -'!.'~.~; \',,-:: / 1,. L.t. }':~·I . (,": I . : .,-'1 Marathon Oil Company PO Box 196168 Anchorage, Alaska 99519-5311 3/11/2003 ATTN: Steve Lambe Steve, We at M-I would like to present you with the recap for the just completed Well Abalone #1. Enclosed are the following: Recap Summary by Interval Well Summary Page Product Summary Cost Analysis Graph Drilling Fluids Summary Fluid Properties Graph Hydraulics Summary Drilling Parameters Graph Daily Discussion Volume Usage Centrifuge Van Performance Chart M-I would like to thank you for the opportunity to work on this project and we look forward to participate in further Marathon drilling proj ects, Please contact me if you have any questions, Tony Tykalsky Tony Tykalsky Proj ect Engineer M-I Drilling Fluids, LLC RECEIVED Cc Bob Wi11iams Rodney Mabeus MAY 13 2003 Alaska on & Gas Com). C>\/mm~ Andl~ ( I· \ MARATHON OIL CaMP ANY ABALONE #1 On Monday, January 27, 2003, the M-I engineer arrived on the Abalone #1 location dur- ing rigging up operations. Twenty inch cònductor pipe had been hammered to 70' at that time. A Gel/Gel ex spud mud was mixed in the rig pits, and was used for drilling the pilot hole in preparation for hammering the 20" casing to the 170' refusal point. This mud was then reused for the spud. Surface Interval 17-1/2" hole 13-3/8" casing (0 - 2210'): A 17.5 " bit was run into the conductor pipe, and drilled from 123' to the shoe at 170', but would not go any further. A mill was run into the conductor pipe, working through the shoe and drilling 5' of new formation. The 17.5" -bit was then run into the hole, and a 70-sec/ qt funnel viscosity mud was used in drilling t9 610', where a trip was made to. change out the MWD tool.· There was somewhat more clay in the upper part of this in- terval than in other wells. As the depth reached 700', the viscosity was lowered gradu- ally to 55-sec/qt. Another trip was made at 1007' to change out the MWD probe. The desiIter was run as needed to keep the sand content of the mud low. Below 700', addi- tions of PolyPac Supreme UL were made to lower the API fluid loss. Two Vac trucks were needed to haul away the cuttings for injection at the gas field. Due to weight re- strictions in the gas field, the trucks were limited to 75% of their load. Turnaround time averaged 3.5 hours. Drilling ahead continued, building volume as necessary. Minor hole losses @1,752' were noticed. The losses increased, and at 1,765', a 40-barrel LCM pill (20 ppb Safe- Carb 40,22.5 ppb Gel) was spotted downhole. Downhole losses continued, so a second 40-barrel LCM pill (10 ppb SafeCarb 10, 30 ppb SafeCarb 40, 22.5 ppb Gel),was pumped and the hole was monitored for losses. To add bottomhole pressure by ECD, the hole was circulated for 3 bottoms-up, and a wiper trip was made to 885'. Running back to bottom, there were no more losses. Drilling ahead continued, building volume as needed. The mud weight was reduced by adding new mud and running the desilter while drilling ahead. At casing TD, 2,210', the hole was circulated bòttoms-up twice. For the trip out, an LCM pill (10 ppb SafeCarb 10, 30 ppb SafeCarb 40,22".5 ppb Gel) was spotted on bottom, 2,008', and again at 1,630'. The BHA was laid down, and the bit was run back to 2,130', washing to bottom. The mud was conditioned by circulating while adding water and running the desiIter to reduce the mud weight below 9.2 ppg. Losses started again during this circulating time. LCM pills were again mixed on the trip out-on bottom, 2,000', and 1,816' (15 ppb·SafeCarb 10,20 ppb SafeCarb 40,10 ppb SafeCarb 250, 22.5 ppb Gel). The bit was pulled to 1,680' and the hole was moni- tored, but losses continued. Another LCM pill (20 ppb SafeCarb 10, 30 ppb SafeCarb f ( 40, 10 ppb SafeCarb 250, 22,5 ppb Gel), was spotted, but losses continued. The Deci- sion was made to change to a fibrous LCM, so a 30 ppb M-I Seal Fine LCM pill was mixed in 40 barrels of whole mud. The pill was spotted and losses slowed to 2 bph. The bit was tripped out, And after a PJSM,.the I 3-3/8"casing string was run to bottom without problems. The casing was circulated briefly, and cemented, but due to down- hole losses, no cement got back to the surface. While waiting on cement, the pits were cleaned. 1 1/4" pipe was rigged up and run into the casing, down to 350', outside of the 13-3/8" casing string. Calcium chloride brine for the cement job was mixed in the pill pit, but the valve in the pill pit leaked causing the brine to go into the remaining active mud system. Additional water was run that also went into the active mud system. Repairs were made to the pill pit valve, and the calcium chloride brine was remixed in the pill pit. The cement top job was completed successfully with good cement returns to the surface. Due to the severe contamination of the surface system, all mud volume was discarded during the pit cleaning. Valves were tested and repaired as needed while the stack and diverter lines were nippled down. The BOPE were nippled up after cutting the casing. A new FloPro mud was mixed for the next interval. Problems encountered during this interval included some lost circulation. The clays, while slightly troublesome, were easily removed by the desilter, as long as it got them on the first circulation, while they were still clumped together. This interval took 11 days. Total cost for this interval came to $27,167.04, including engineering. Intermediate Interval 12-1/4" hole 9-5/8" casing (2210 - 4350'): A 12 Y4" directional drilling assembly was run into the hole, testing the casing to 1500 psi. The bit then cleaned out the 13 3/8" casing, drilling through the sho'e at 2206'. New formation was drilled to 2209', and a FIT test to 11.0 ppg EMW was made. New 9.0 ppg FloPro mud was displaced into the well, with the old gel/water mud being sent to injection. At 2230'. a leak-off test was run to 14.5 ppg EMW. After some rig repairs, directional drilling continued to 3346', and the hole was circulated clean. The centri- fuge van was run during this time to reduce the solids and clays. A wiper trip to the shoe was made. The well was shut in, and a brèaker for the new pump house was in- stalled. The bit was run back to bottom and drilling resumed. Solids from the wiper trip were accumulating in the mud, so dumping and diluting was required while running all ( { ( solids control equipment. At 3900' a trip out was made, with the hole very tight. Back- reaming was required from 3900' to 3410'. The bit was changed out, and a new bit was run into the hole, reaming tight hole from 3472' to 3390'. Adjustments to the centrifuge van were made to take out more clays. Directional drilling continued to 4350'. The hole was then circulated clean, and a wiper trip to the shoe was made, backreaming from 4221' to 2848'. The centrifuge van processed the surface pits 2 and 3 during the trip. After servicing the rig, the trip in was tight from 4040' to 4273'. 11' of fill was washed and reamed to bottom. Solids from the trip increased the mud weight to 9.45 ppg. The hole was circulated clean, and the higher mud weight allowed the bit to be pulled out of the hole without any problems. Schlumberger was rigged up, and e- logging operations began. After e-Iogging was finished, a wiper trip was made, washing and reaming from 4272' to 4310. There was 3' of fill. The mud was beginning to spoil, so a Greencide treat- ment was made while the hole was circulated. A dry job was pumped, and with a 9.5 ppg mud, the trip out was made without any hole problems. Nine and five-eights inch casing rams were installed and tested, and a PJSM was made. Nine and five-eights inch casing was run to bottom without any problems. The casing shoe was at 4336' MD, 4194' TVD. Another PJSM was made, and the casing was ce- mented. There were no losses while pumping cement, but when the rig pumps dis- placed the cement into the annulus, there were 72 bbl of losses. Variable bore pipe rams were installed. The stack was tested. Five inch H.W.D.P. was laid down. Problems encountered in this interval included solids buildup, tight hole conditions, and fill on bottom after trips. The tight hole conditions improved when the mud weight was increased to 9.5 ppg. This interval took 10 days. Total mud costs for this interval, including engineering, came to $74,712.78 Production Interval 6-1/8" ho~e (4350 - 10356): A 6 1/8" bit was run into the hole to drill out the cement, drilling the float collar, and washing to bottom at 4350'. 20' of new formation was drilled, to 4370', and a leak-off test was run to 16.3 ppg EMW. The bit was pulled out of the hole. Eight-hunderd barrels of new FloPro mud was mixed and displaced into the hole, at 4.7 bbl/min, with 800 psi. A 6 1/8" motor assembly was utilized to directionally drill from ( .( 4,370' to 4,916', where a short trip to the shoe was made for repairs to the wash pipe. The trip back in went smoothly, reaming from 4,367' to 4,916'. Drilling continued to 5,430', where another short trip was made to the shoe. Additional volume was made by batch mixing as needed, blending the new mud into the active system. Treatment for bacteria and oxygen content were made as required. Drilled continued to 5,934'. Three bottoms up volumes were circulated, and the bit was pulled to the shoe for rig repairs. Following repairs, the trip back to bottom went smoothly. Drilled continued with the mud weight increasing to 9.6+ ppg due to increased solids by 6,345'. The M-I solids van with dual centrifuges was saddled up, and. lowered the mud weight to 9.4 ppg in only 4 hours. At 6,677' the mud was circulated and conditioned, and a short trip was made to 5,934'. No problems were noted, so the bit was ran back to bottom and drilled ahead to 7,230'. The hole was circulated and conditioned, and a short trip to 6,677' was made without incident. Drilling ahead continued to 7,508'. The hole was circulated and conditioned, and a bit trip was made· to test the BOPE, and change the bit and BRA. Prior to the trip, treatments of Conqor 404 for corrosion, and BioBan for bacteria were made. The pH was adjusted to 9.5+ with caustic. The BOPE were tested, and a new bit was run, a 4-3/4" STC M50VYPX with a 6.125" hole opener and BHA. An attempt was made to install a corrosion ring in the drill string, but it was found to be the wrong size. Running into the hole, at 4,245' the drill line was cut and slipped. Circulation began at 7,430' washing on to bottom. No prob- lems noted with the hole conditions during the trip. Once on bottom, drilling continued from 7,508'. Mud weight had gradually increased up to 9.7 ppg, so the M-I solids van was rigged up and run for one circulation to reduce the weight back to 9.4 ppg. Safe- Scav NA additions were made for oxygen reduction when back on bottom. Drilling ahead continued, using the M-I solids van when necessary for weight reduction to maintain the mud density from 9.4 to 9.6 ppg. A bit trip at 8,774' was made after cir- culating bottoms up. There was a tight spot at 7,770' on trip out. Repairs to the top drive were made on trip out. Problems with EPOCH equipment were worked on during the time out of the hole. The bit and BHA were changed, and a new bit ran into the hole to 8,765', washing and reaming back to bottom. Directional drilling continued, from 9361' to 9922'. After circulating the hole clean, a wiper trip to 8522' was made with no problems. Running back to bottom, there was no fill. As drilling resumed, the Centrifuge Van removed the barite dry job from the mud, keeping the mud weight in specs. Gels remained very low, because the 2 centrifuges were able to remove the clumps of clays on the first circulation, before they were dis- solved into the mud. At 10,356', (10,202' TVD), TD was reached. The hole was circu- ( (' lated clean, a dry job was pumped, and the pipe was pulled out of the hole, SLM. Some troubles with the cotta box interrupted the trip out. The bit and motor assembly were laid down, and the cotta box was repaired. A logging tool was run into the hole on a rerun bit, and the L WD tool logged formation from the shoe to TD at 10350' without any problems. The mud required a lot of Greencide, Myacide, and caustic. There was some coals noted coming across the shakers while logging the upper parts of the open hole, but as the tool neared bottom, the amount of coals coming across the shakers decreased. The hole was circulated clean, and the L WD tool was pulled out and laid down. In 12 hours, the pits required further Green- cide, Myacide, and caustic treatments. The BOPE were tested and the rig was serviced while the logs were analyzed. A cement retainer was run into the hole, and set at 4283'. After a PJSM, 39 barrels of cement was displaced below the retainer. The pipe was unstung, and pulled up to 4190'. One hundred barrels of mud were reversed out. A dry job was pumped, and the pipe was pulled out of the hole. The mud in the pits was dumped, and the pits were cleaned. Problems encountered during this interval included minor hole swelling and dissolved oxygen removal from the mud. This interval took 16 days. Total mud costs for this interval, including engineering, came to $114,479.82 COMPLETION INTERVAL A bit and casing scraper were run into the hole. At the retainer, 320 barrels of drill wa- ter in the pits displaced the mud out of the hole. The mud was sent to injection. Five hundred barrels of 6% KCl were mixed in the pits while the casing scraper made 2 short trips. When back at the retainer, the 6°/Ó KCl with CRW corrosion inhibitor was dis- placed into the hole, dumping the drill water returns. The M-I engineer was released March 6, 2003. No mud problems were encountered during this interval. This interval took 2 days. Total mud costs, including engineering, came to $8,352.82 (" ¡' ( M-I L.L.C. ONE-TRAX DRilliNG FLUIDS DATA MANAGEMENT SYSTEM Type Size Depth TVD Hole MaxMW Mud I in ft ft in Ib/gal Mud 2 Drilling Problem Days Cost $ - -..... __........ --......... --.............................. --........................-............... ---.......... --.. ..-oO" ___ __ __................ __.. ____ ___ __ __.................... __.................................................. __ _..... __........................ __............ __......... __.............. __ __ __ - __ ___ ...__..... __.......... Open Hole 10356 10202 6.125 9.60 FLO-PRO NT 16 114479.00 Casing 9.625 4336 4194 12.25 9.60 FLO-PRO NT Excessive Torque/Drag 10 74712.00 CF 9.625 4336 4194 12.25 8.70 Potassium System 2 8352.00 Casing 13.375 2206 2100 17.5 9.40 Spud Mud Partial Loss Circulation 11 27167.00 Casing 20 170 170 22 r:J ( ( PRODUCT SUMMARY Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DRILLING Field/Area: WILDCAT Description: SEC.29/T2N/R12W,SM Location: CLAM GULCH, ALASKA SUMMARY OF PRODUCT USAGE FOR INTERVAL WATER-BASED MUD AMOUNT 1/27/2003 - 3/6/2003, 145 - 10356 ft SIZE 1 - ENGINEER 1.00 39 2 - M-I GEL 100 LB BG 370 3 - CAUSTIC SODA 50 LB BG 83 4 - SODA ASH 50 LB BG 53 5 - GELEX BENT EXTENDER 2 LB BG 31 6 - M-I BAR 100 LB BG 644 7 - SPERSENE CF 50 LB BG 5 8 - DE FOAM X 5 GA CN 14 9 - FLOVIS 25 LB BG 293 10 - SAFECARB 250 50 LB BG 46 11 - SAFECARB 40 50 LB BG 756 12-SAFECARB10 50 LB BG 794 13 - SODIUM BICARBONATE 50 LB BG 8 14 - POL YPAC UL 50 LB BG 50 15 - CONQOR 404 55 GA OM 6 16 - M-I SEAL FINE 40 LB BG 30 17-LUBETEX 55 GA OM 12 18 - DUALFLO 50 LB BG 294 19 - POTASSIUM CHLORIDE (KCL) 50 LB BG 1635 20 - GREENCIDE 55 GA OM 8 21 - BIOBAN 1 LB 340 22 - DO CWT 55 GA OM 2 23 - Safe-Scav NA 55 GA OM 17 24 - PECAN NUT PLUG MED 50 LB BG 7 SUB TOTAL: UNIT COST PROD COST ($) ($) 625.00 24375.00 12.96 4795.20 28.65 2377.95 16.50 874.50 11.90 368.90 11.91 7670.04 33.50 167.50 88.17 1234.38 197.00 57721.00 17.50 805.00 17.50 13230.00 17.50 13895.00 17.75 142.00 156.70 7835.00 1152.10 6912.60 23.50 705.00 734.00 8808.00 82.00 24108.00 12.58 20568.30 1641.20 13129.60 22.00 7480.00 478.74 957.48 377.33 6414.61 19.20 134.40 MM':¥.t~1!.~~~~:!~11:fi:~¡~?,~¡¡~~Ü~·:<~·,/;.~'·.' ::.~,¡:',.:,;"~:",,,,;,':;:., :':i":'i,:.:¡~: DR.I~~ÎNG1'~LIJ"IPS'; DÀTA:'r.~t~NÁ.G ~Nit~NT ;':SY~1èNf:;/:>:;~';::;/:i; ;~~<:'.. ,', <>:j.~~!;\~:,J.ti~loiiø1:f::G:~".~::;t,:';·lt· 224709.46 r=J ( ( PRODUCT SUMMARY Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DRILLING Field/Area: WILDCAT Description: SEC.29/T2N/R12W,SM Location: CLAM GULCH, ALASKA SUMMARY OF PRODUCT USAGE FOR INTERVAL TAX: 1/27/2003 - 3/6/2003, 145 - 10356 ft 0.00 WATER-BASED MUD TOTAL COST: 224709.46 TOT AL MUD COST FOR INTERVAL: 224709.46 ~~M,¥"'~~~~::FH'!~)(~~'~;~~:;1~rii:':Y~1,;? '::;·,:iij':.;,>::.' ',:i'> '.: ',:.::::y'....~ ,:/j)RILLlNG· ,·FbÙì6$·;'PÄtA·ÑlANA~·eiVì ENÏì;,$YSTEM:;'}:tJ;:~~<:':·;'/::.:;1L'!,.Xt,\!i·.~:::~:.:;";: ,~~!~¡Q'"~~'?:,::t:;:.::}i?:Ú . f: (' OperAtor: MARATHON OIL COMPANY r:=J ONE-TRAX ABALONE #1 WllDC... T Do,criptlon: SEC.29fT2NIR12W.SM CLAM GULCH. ALASKA BREAKDOWN OF COST BY PRODUCT GROUP 1/27/2003 - 3/6/2003. o - 10356 ft W.rer·Bea.ed Mud J'ro.dUCtl % 1.-8r~M Pteclucb 28561.Jo 1803 Z.cOll'Vl*ft CbelDk... 31'53.... 15.1 )"Dbpcnantl IIl~." 0.6 4~nukl Lø. '19UN 15.9 S-J.A,.IClrct.btttial 11769." 14.4 6-l.ubrk.al 15720.60 7.a 7-VlHlFaukl LoN '1115.10 'U I-Weltht M.lcr". 7"8.... U O.n Water·Based Mud 3.1' Cost Analysis 14..' W.ter-a..e4 Mud Tobl. COil: S 2114I334.46 100.0 DJtXLLINO P'L\r.I:DB ÐATA MAlrACIDCllH"1' lIYaTBH 31....' March 11. 2003 I ~ ( ( Operator: MARATHON OIL COMPANY Field/Area: WILDCAT Well Name: ABALONE #1 Description: SEC,291T2N/R12W,SM Contractor: INLET DRILLING Location: CLAM GULCH, ALASKA ør~~~_~~~m~J'il~~~Rmi}I~}~,~~8'ì~QU~~~~!tt~£*~1ä.Ö~~Ø)21~~_~~ \-º~t~!.~.. ~~~t:i'Rm~~WM~~~-<'Il~~~¡:J~A'íØ'W~~B~~~~~~"K\\~~~6/8. ~. 6 . ~"'l'........ì1l~.\'it~~~nr~~~~'I», ..~~ _ ,... . _''In·iW\if1~''~''1III,~''I..r. ~ Mud T e GEUWATER GEUWATER GEUWATER GEUWATER GEUWATER GEUGELEX l' ." 'cJJ~~~.~_ Cire Volume bbl 452 .' " _ 422 "...~.. '447 . .. 500 .., 507' - _I 692 . , . -"'~'~-~" Cire Pressure 130 130 130 800 400 1200 _1~~t:.!:.~&..~mir~lr~ - S,,-1!'ple From _ _ , P~ . . PIT _ PIT PIT PIT. PIT .~tL~_Ø!~~~U_~ _, ,~--...~ IfIIRf' Mud Wei ht lb/ al _. ~~ 7@ 54 of ., ~.7 60 of . 8.7 57 of 8.7@63 of 8.85c.æ60 of 1.J..@12 of -. ,~Iw-~, . ~Ï:~-- _7.1 I II -.J17IL--.'\f;mt\m PV cP 16 16 16 17 14 12 fmjMnr.:œf -lIlW&Im[]IJi'II'a~~"..!!O ..nil[ _ _.T iIIR_....-- ~rr R6QO/R300/R200 57/41/33 47/31/25 43/27/21 55/38/25 73/59/52 45/33/26 BDtt61S11J11l1-Æ 'LI]1I1r1!:.\rl1~mRH..~~~.:' lOs/10m/30m Gel lb/l Oft2 14/27/34 7/19/21 5/15/18 9/17/26 36/54/62 24/2 ~~ .....- .,..... ~.,.Tijf .fl...,_·._... F.l. ¡d, Loss cc/30 min _£¥:~.:t.~- _~ ~~ . ... _.____III'--r-.~ n~ ~ ~"""'" Solli1s %Vol 4 4 4 4 4 4 dmøll'MJ.'MltIII ....M!IMII...~_!.)fíu:œJ..all. -._!l.Ul!i-...._._~"'mrnT'___ 'I -. Salld %Vol 0.5 0.25 0.25 0,25 0.25 .0.5 "~'~Iï. ....J.~ifkLWlft~··U1L...~ _1.__ _ r-åDI.. -~ --. - .RtI 10.0 10 9.8 10.0 10.0 10.2 '!ftIImmtrØTffQJL_-.. U____~··i._IIUØJ.l __;1'1i,._. _..~~~~._ ßPL- _._.._-_,.___~Áf~~It~ ~ PflMf . 0..2/0.5 0.3/0.9 0.3/0.8 0.3/0.8 0,3/0,7 0~/O,8 ~~~__;;JI'r_II_I""",WtI..Ld.~~Jh'~n~~¡1I'IDRJ::ßßt1,~'&i~¡"11I'" Lw. ~ess .Ca . -----10 . 40 40 20 . Q 2Q --___...,~. "1',.... JI ~...._ _-l~.Jl1n~(: r _or ..-__1,.- _ _, """'... .. Dissol OXYmL. ~ 8 8· 8 6 ~1i'lft.l.-''--I[..............,JU~uilAr_.._mMn____ ~~____,._LlØfllRr~rnlll1llt;œl:L(~ _RI 1Inu.,,-. ,__. __ r----·-. , ., ~'5iJ,¡r:J~~~llN.tr~.rnm,~?~"1""''''y~i·.I_r:~1!U~...."" __º~HY_MV,d Co§: ' .. $ _ _ 2~0~.85. "1' _ 6~6:9P: ... 625.00 . 77,8.40861.25 .. 23l0.l!5. ' ~..~nRla)fill'J~.'m._D.lf_~~ ..9!tp~ ~n~ne~.r ____. Sal¢s En· ¡neer,. .__. .. B. O. b. Wilti,ams Bob ~i1lia B,ob Wi11ia~_ Bob Wi1)iams BO.b. . Vj.il~ams . Bo. b. W. i. nia~.. ~~l.Z,.IIII',tn;}. .. - ,., ' .. ___.:nr·b'U~J. Ji , ~ "J~~~J:l\m'Ul~::J.~l::nt~~ SODA / 2 GELX / 12 CADS I 1 ~_~. ~. ~J~~ DD /2 ~ \'.'L,;~-' . ;)-} š: ...~ 1.: :" \'.?,yo;' I \ \. " ,'.. '\ , 1~~.¡ j " .,'", , '.'~/JI"}1·'i:;, ,.':i' ;hI1d,.','··, RMm~I\J'.J1' ~ ~ ~~~ '.,.-. flr.ll,l.J_,·· .'. ... ~J1~'L.. ...1........ '." ,"':."~:&" '.:r"il __~¡~~II': REMARKS 1/27/2003: Mix 440 bbl GellWater spud mud. 1/28/2003: Pump sweep around. 1/29/2003: Hammer pipe. 1/30/2003: Build 40 bbl more volume for spud. 1/31/2003: 17.5" bit will not go thru conductor shoe. Wait on mill. Mill thru conductor shoe. 2/1/2003: Dir drlg 175'-852' at midnight. Adding Gel and Gelex to water for volume. Added 2 dr DO per Co Man request. "~,. .,:;¡,r· ,,¡¡¡r:r.',~~r{~~ "~~'-:;., ":'~1J'.~··:· i ',-,"." ,Î¡ ~. "'~'. :l:þIf;;, ',Y-'.._ J(~~~~r.I~ 1\'1'~;~..I~,,",\,. ~., 'I ~"~j,~:. ~'1:i:~~'t··t>~I'fl;.41~'.I/:},-~ !~mil9~ì~:~\&t.~ff:jjlf.: . . '_:.n~_ . - '-;;::; \(. ·oJ ¡.. ~ I( DRILLING FLUIDS SUMMAR~ ~~,. Operator: MARATHON OIL COMPANY Field/Area: WILDCAT Well Name: ABALONE #1 Description: SEC.291T2N/R12W,SM Contractor: INLET DRILLING Location: CLAM GULCH, ALASKA , ·'~~Wiii¡'¡'i>:\1I]§!B¡!:.f~)rii\an1lí.tM~'j~''''·.¡;",~ri1'i:· "- . " , · - , . _. '. . . .~~~.f!!~,~~~i.4~·· ... .~.... . . ~ _'.. . ... .' .~, . ft 1442/1408 1950/1863. 2210/2100 2210/2100 2210/2100 221012100 ,. . ...... ...... '~. _·.·~.·1J.~D~Ur~·fjI~~~ GEUGELEX GEUGELEX GEUGELEX GEUGELEX GEUGELEX· FLOPRO . ·\~"'~~~--~I~ Cire Volume bbl 836 935 1151 1117 979 924 "~·.I~t~mfiøif.'timIEm.'.t· ,-' .~. ~~~~_ Cire Pressure si 1420 . 1430 . . 1200 0 , 0 0 ,. ~~ -,- SamRkfrom FLO PIT PIT PIT PIT PIT þÞ,iI~ 1~~.!.t.JlJ...... J]lmfímU'.ll~~~~"~~"'1_. _ , ~- .._~ ~:'I~~ . Ib/~!__'\. 9,3@99 OF 9.J5@9~ 0I: _ 9~2@2_Q_~_I:.n___._n_~-=3@85 of 9.0@80 o~". 9.0@50 of ... . .... ,10':11._ _._--.x",'~J,."I.M~~~ _._ .. _II"'. It I PV eP 17 15 15 15 9 9 "' ØJA~._ vF.~_Jm1__.,m_ _",/,", -".( So: ß.600/R300~00 54/37/28. ?1I,36!27 . 52!37/~7 '. 49/34/26 38/29/24 '" 48/39/36 *~t\l!¡IlØ ~. -- _......"~~~~~Æ...~__lØ£fII\1J!f!~..~fI¡~~ ~v:.,. =~ I~I I' 10.S./(0'3~~. . Gel Ib/lOOft' 8/20/28 8/20/23 ..~/18/22 .1"11> 6/1 /I~ ~ f~, 18/2~3 ~.... J\IIIII....-Ø~UIiI.L~....,... ..~......__"'.~~~_II __ ____~........ .. ßTHP Fluid Loss ec/30 mjn . .~M1mMlw___,__ .._.__ ..~I!I\t".. ~l:f!!I'\-!n::k.;::Q¡.~_,_..~!I·.II ."___" ..... JII"IIf' ___ . 11 1\ . ~Q!ids %Vol 6 6 5.5 6 4..5 .. 3 . ~IL- .~MI!I!IM.t.I.f,ðiIItH(~..L.1(~~W(~&..L:lti:t.I\U..."1ðIr1'2ø--J:Vumfurl_ftM':.: ~~__ .j-__-I!~ _ Sand a 0.25 . 0.25 0.5 0.75 ;¡T 0 _"'..___.._._.___ IJ..UIU __ IT N.IIJ'KJ~!D~:. .,.:_.~l"':...~~::~_ , ; ~ ; ~_~...~H -J ..~5 11111 ~lL..; ~~ _~ 11- 8.8 . i 9.5 .. Pf/Mf 0.2/0.7 0,15/0,7 TRIO, 8 TRIO. 9 TRJO.6S ~ fb(.j..D"... ,.. _ J _ n~ _I.JIM ~J! ___ ~..'!m.'",¡J,~. JlhIllL___-.~~\m If ~KÐ! II~ ..~~.... ~ . ~:¡~J -U1õJ~~- --0 l ~~= i~ _ , ,.- ,___....uwI.IIIft~~_~~t,lIJ.ïQ~;~l'~1!T1'B..,.~~.wit...._~If.¡jl[l=:~ ~..ì.~M:\1d,Cost '. $ 2486.14, ~15873.23 ,...,7633.16 . ,3136..96 __67?,QO. 87.7.7...6.? .' ... .irt\f8j~..~7~I.T~nll.~..a¡\"t_~~_ _$.ªles Eºgineer . Bob Williams FAUL~ER F. .IF~ULKNER F..~ FA}JL~.. .'. F. ~, ~~!A-IG:!~~F, ".. ..,. ... F. '. ~~...!I1DMft"_'_".'M..~2.1.. .... . ,,,,~., Œ.1b.~ EGR / 1 SCF / 16 SCF / 60 SCF / 28 SCF / 12 ~,.._''"r-' . ~.._...,..r'l1'Jœ~!IUIJIiII/ r41..~I1~i!Ii'f.t:l'\'\tw~~ ~..\UU¡III'~.jl!lMr.Æ.~ .... í:..~-.IIr;;¡~Ll.lU"'~Wl~J.\IJIUll'''-~ - -. ----'~d1Jl1[~:. .'~ CAUS / 3 ENGR / I, ENGR / 1 ENgR / 1 ENGR / 1 -....... I. ~,_"''i!''~ .~~" ~·~..~~~"mm':"'t·.tV_ dJRIII¡rIliiK':Œ'bfiil' "1. .._._~~}... _~~~\tn..",~ ~:lfi!U.~~..ríZtm::l~\...ÆL.r.R&;JI.:~ IIJn]I"!~I'm'iI!I'1~ :.m:r"~..__!i.llllillìlln~rn-l111;pm1i., " ...."\.,¡.J'. .. ~ r::I~~ "......."Y'1'.""" 'I[ DFX / 3 C~US / 3 GELX / 7. S~C / 16. SODA / 1m:ua..~. ,;: .",_" ,".,., ,.. .(~Mt:'M'-íi:~ ._. "_""w~ , o,,;i¡ ". . " .w,:r. (I .'1Itï ~,.. .._...----~~- ~t\\lœ*i!¡i\tI~~~1J!J'M.~~~'i~¡m.~¡¡'¡_~~~M·· " ".' ., ~.~-__t¡,~~.!-~l-~-il, "'"" De thlTVD I.; !~;' , "'., ,~~,lIIì1.lJ.. ,t . , I: ~, \ .:; '" '" '... " ~111 _.il.¡.i.UJI]fc.;rmI~~ . \1;,11r. . ... , . ~ ~ ..\,;\ '" .. ,i._~~-"~I_~Wi~\iI'II!.~_~' REMARKS 212/2003: Drlg ahead. Build'g vis wlgel, gelex. Drilling more clays than usual. Dump/dilution with water. 2/3/2003: Drld. ahead @1765'-10sses; mix/pump LCM pills (2); monitor wen; CBU 3X-work pipe; monitor; wiper trip @885'-RIH; drlg. 2/4/2003: Drld. tITD @2210'; spot LCM pills on trip out; chg. BHA-RIH; wash/ream-losing fluid; mix/spot LCM pills on trip out 2/5/2003: Mixed/spotted LCM pills; observe well @1664'; losing@2 bph; POOH slow; UD BHA; rig up-run casing; land casing 2/612003: Rig down csg. run; RIH-cmt. job; lost rtns.-cmt. not to surface; POOH w/DP; WOC; prep. fltop job; valve leak in pill pit 2/7/2003: Cement top job; pull 1-114" pipe-UD; nipple down/nipple up; chg. brakes; empty/cln. pits; repair valves; mix FloPro . ,i~*,Mf,!~'~J;~~~~';"~~·~IJ~'¡.;'í..fj,"?~i<,'M~~f.7;'\~~.~rJ.'~~t;,J~l$:~; I ;~)~~.'.'rjÆ~"'~~-l.f(·¡'>.',,;,~ ~¡"1,,.·,:"~~~~¡ig",~,"t:·;~~1!t~W~f!!K~,.~fM.j 2 ~ ( DRILLING FLUIDS SUMMARY Operator: MARATHON OIL COMPANY Field/Area: WILDCAT Well Name: ABALONE #1 Description: SEC,291T2N/R12W,SM Contractor.: INLET DRILLING Location: CLAM GULCH, ALASKA ~·~-~·~~~_~~W~1.itv__ ': ~ ~h/~VD _I ~~ïf;;.~j~=...~!l~ 3900/37.59 4~50/420~. ~~e i1)"I.~~'Wk~~ F~OP~O '¡''t, , FLOPRO FLOPRO ~::Vr.r lP- Cire Volume bbl 872 865 873 964 1034 998 I~~.. ' .__~jtl~I.~iut\Jt~o.__·- ~-. Circ Pressure si 0 1200 1500 1450 1550 1550 ~c.~:..::.ill . ,-~I~~~II..~ _ ~. rom ... .... .... ~ PIT PIT PIT PIT. . . PITS PIT lfÄiIll1-\~:mr.: , ],_..;I1[.:,r .. ~~~_tl.1 M, ud W.'eig!1t . lb. I' ~l. al . 9.0.5@55°F,19.:.9.2,62 of 9.35~90 of 9.2, 5@8~ of 9.35~95 of ~A_5(â)~z.. ~~~~\_'ffðY.\Un!~· .. , ~ . ~JW"~ -.J- .....,.. .. ~IIIIIIMI PV eP 9 11 11 11 11 11 __ ,1Lr.~~r ~....~ __ß]l~j.. .~_- R600/R300/R200 55/46/41 54/43/37 49/38/34 ~11 . . _ U.~.r:r¡Iit'~:~6WKf~1J8Lr. 10s1l0m/30m Gel lb/l00ft2 22/29/31 18/24/27 18/23/26 ~JI~~_~. _ .' __ - HTHP Fluid Loss ee/30 min In¡, - nllÍu~ l~" .Á11~~ '~'--"I Solids %V 01 3 3.5 ~ ..11I_ r.:h.,J..!!\Il'1M!m.ííumL.~. %Vol 0 0,25 1- r'I,~.. 'r'~~.,· t ¡'I. i,_ I '\. ." "(.' _,' "......:,' " ',...1' r;'~;'-: ", ,.'. ,', .' ( '/,,:-: IW',", 1" ",.(' .' . :1'1II' 46/35/32 50/39/35 48/37/32 16/20/24 13/23/29 14/23/26 5 4 -....: .. . ,'m 0.5 .4 ~\V):/J I \ÌI¡ ~~ (....j . . ) ~ . \ I '~.!... ",,'1.., ,.~ ,\. 1 / ':>if \. \,' S d 0.5 .25 0,25 " ,.,,_In j ._...n pH 9.5 9.5 9.2 9.0 8,5 ~n.._._ _n_ .._ --.- 1IU_rtr.. ':b~ PflMf 0.35/1.15 004/1.3 0.3/1.1 0.25/0.9 0.1/0.8 ii~ -~~~~~~ .!1.::3?:..+-I~ .~ .. \Jìi..- , -~ -.-.---- -._~I rH.. œ_ -"_~IPf-----. Daily IV.. M. .ud Cost . . $ 11325.24 , 11,409.".46, 8290.21, , 1746.. O. .97 860.9. .65. .203. 9.25 ...._~ . 11m. .tiI.~ ~r:~~-~it~-L ~l~ ~.....4i~\~R:--I![.,,-. Sales E~~ineer I ,. " FA~~~":""'ì~r~ BOB WI~I.AMS BQ~~.:WILLlAMS VILLIAM. S.· ~!'_'~ºª~.'... ~~LlAMS ~~~_-...uj~...~R:~...1";.'T ., ,. ~ ~.. II ~¡tl..,./tlilll~~'I~'~ .....- h:l!IK.Æ,,,....jld1t:J:t';i\Øflr.m1, . '.., ~ÇF l~ 18 SCF.~ .:1 ~1r~~ DFLO I 8 ENGR / 1 KCL / 88 GCIDE I 1 KCL I 40 SODA I 8 ~lt,I,I·~JMlIl¡'. .,:'::~Ãl1m1I11!~.,~f~~.rø~~"ril"" .. ..,. I I ., .... 11I_ GCIDE / 1 SODA / 3 CADS / 1 ENGR I 1 CADS I 2 ."it·lJrfl.,MiNI'_~'t:~JrrM..~~WØJII!mt~~".&"~'~lm]",_ UIfil!~...i..I'IIPII_- ....!11Im SODA / 1 FLOV I 31 BAR / 22 FLOV / 11 SC-NA I 5 ~~~~_~.:t:;tm\I1."'rdkæ._!M;l&íI,...L~~œ.~~ -"J'~.I.:].~~ MIII,_,~~I__811~'~n'1tl1~~1I&R·~Bllu;L11..~..11uflme~I/~II~ --, ' , 1.::1.'", . ." '.' ['1;., ",I I J! " '..,:¡'i', ,__,I '" : I ", . 8.5 0,05/0,6 r ~ ; 'I, ''! "I 'J, .W 'f .. " _. -__'_"111I".' "' ~ v.' ,'" '(''''''',:-'~~'-I,' .~",' I '-, ", , " ~'l.lm ~ifIIA."III.I.ìljIII!OII\llil_¡____ _""tI~~~IJ~iï~IWJ~.~¡__1B~ REMARKS 2/8/2003: Mix FloPro; move old mud into pill pit for drilling cmt.; NIU, test BOPE; BHA; RIH; PIU DP; drilling line 2/9/2003: Clnd.ltested csg.; drld. out @2209'; FIT; displaced t/FloPro; built volume; LOT; drld. ahead @2230-2764' @midnight 2/10/2003: Runn'g Centr Van. Mud wt incr'g. Beginn'g to dump and dilute. 2111/2003: MBT, mud wt rising. Dump/dilute, run all solids equip. Put 230 PYR on shkr #2. Tweak centrifuge performance. 2/12/2003: Run centr van while tripp'g to lower mud wt. Run van while drlg-van down 5:00 PM repairs. Dump and dilute. 2/13/2003: Centr Van down. Mud wt rise to 9.6 ppg while backream'g out. RIH w/9.6 ppg mud-no problems. rnJ ( (' DRILLING FLUIDS SUMMARY Operator : MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DRILLING ~W~:...' De th/TVD Field/Area: WILDCAT Description: SEC,29fT2N/R12W,SM Location: CLAM GULCH, ALASKA .... ,.. ,·~.~~..I,¡j,~;';¡~1W~~~~.rr¿t'!tf,,1¡~Ri"~~_·"." . ',' . .,.. ~~~~~.wowm.W!Nj~~q~IT!W .,. ". ..~. ,.m~ ft 4350/4208 4350/4208. 4370/4228 4798/4656 5557/5414 6345/6202 Iim,~:nm""iJ~~'_·· . ':¡¡¡~ti"'_r'~~ ØJU'~.QIIUQRltl~ll':".NJr. JJlm·, ,. ,. . ,. . Jì'IIIfIJ.""....,.", ,ØfI"'M~ ...,..... FLOPRO FLOPRO FLOPRO FLOPRO FLOPRO FLOPRO '~åD!'Ò11ilil/l,"it~~~~fift1f,¡,~';i:~'ti~_.··, ,".. "'. .,~ ~ .IÎ ~.Ji~T~"~~~ . -, ,. ',. ,fj~\IJl iIIIII' 998 618 621 770 764 803 ~t: :', r~ \.~ . ,... ~~lÆl!_"'-"""" ---.. 1550 1550 1100 1250 1300 , Ii., , . .j . ¡f~~.,-:PI\\'-: m m ~..~. ,m, m , .,~111U.ltœ;'I~"_I.lt...íl'IWltJl-~_ =eight Ib/gal 9.5 82 of 9.5 84 OF 9.85 79 OF. 9.4 80 OF .~~~~:~;~I'ir~ PV cP 14 16 12 9 10· 8 --..-.--- __ ..._iJlJIIt4~~"".,. ';lIiII¡-.:rrRtKUl~II1!.~_..._ ~1EfI.\-.J&~'...IfiI- .88t . R600/R300/R200 54/40/35 54/38/32 49/37/31 43/34/30 48/38/33 45/37/32 :.iJ.dirct..... __ L ~m:Jl.l.JI.þ.v1'!jr}~~II;l~4f.JfIi\Ø1~ø~þ_ Jh 1 Os/1 Om/30m Gel Ib/l00ft2 13/14/27 11/22/29 11/23/27 15/19/23 16/20/26 18/24/26 ,....,II\~ ~..IUIIio"..>J,..,.r::~r.UU~'_'1t -.0" _r,-~ 1_- r 1 n. _, , -t .- liTHP J.... P Fluid bgss cc/30 miD 7 'j .....ÎÍi.ìøII...... - .~_. T .~ IíJ ~ r "~.II!II,_llIIillJmUJ·I\'i«l... _~_.:-rlllll"""'." -"~,.~_,. ~ _ ~..Qlid'. %Vol 5 5 7 7.5 7,5 ,.., IPI WlIt.l!IIII1III\\il:!'i1nN_. -~ ..........-,ft JII.,.I"'FI,~,:~_dlllu'!n Sand %Vol 0.5 0.5 0.5 0.25 0.25 ... .-pi -.raw_. 8.5 ª.5 11.7 9.7 9.0 ~ ~~._.:-t~J! ____ II "" m'lll Pf/Mf 0.05/0.4 0.05/0.5 1 0,311.6 ""r-8:Jai~ ~n.....""",..... ____~..._....~/J..":'11bflam1t.':~..an\\\g.-_, r' l!w;dness Ca 400 320 120 40 _..~_ _.~~ - "" _. _"' __ _.. .Ii!'-- . Dts~.ygn ...e"Q~ 4 4 3 ....~.. - _1f;;Æ.I.~~~ I~.~¡L,1I1't.'fI 11..,--·- __ 11II Mud T e bbl 1550 ~ 4 'I" : \ ,j ,I ~ I ~ t, "I , , , ,) \ ¡ ~ i .' ~ >~ r, ; . f. I .. , ! j I:: J 1 ~ 8 -.............'.'111". '__m_" :1"ltIIIIJ,' ,'·II'InlJ·'I\I,lil".)"_''IiI~'' ,,:_,1.'.:,,- . I i-tl, 11I~..,~_",_I'_:" .".' , ,.;~ '.. ..,.,·t·" : i "II,F!' I,·· _' li : ~'¡""'~.i~':~!'l~ , ,i" 'I ',V'!' , II.:: I; "I",!\,I;' '. ' ,~l,65 1Ii¡ 40 ~.~ 3 iUII _ ~......III.~ ~m ij~ Z'I!I ~"\~_gm '1." --§.\:J1( . T ". ....) iIT_ ., ~a.i1'(¥J!f! Cost ; "$., 5360.10 roo' 625.00 . 812.25. 31454.59. ~ 75~?ll )l.:ll1f:: .."J.2~li07 _. &;tI.JiN~JI'~J.Pr-__..u:J~CJ1ni~lt.,'BI.NtØll~~~ ø t!P.f~_]\U'IM. .~ ~:';&En~ ",_. . BOB WILLIAMS . BOB WILLIAMS .. BOB. WI~LI~S ,,~OBWILLIAMS FA~;':~"''''K.r.. ~ER F.... ..FA.~UL.ø. KN~~ .....: I~JI~~"..L:..~ l" , .,~t:.q¡;J'1I\~1~~. /~ PPUL 1 10 . ENQR / 1 C404 I 2 DFLO I 10 DFLO / 18 "'\I'I..__IIIMI.~DI:lr.I~·~mt~,,~_~WIa.1_'f~l~_~far~ BBN 1 40 KCL I 362 GCIDE I 1 BBN I .20 ..IIUUH....jI....,.il~~_\ltl',f.tIB)b:t·~~..:~!II$~~~~~rmfi\llfïll CAUS I 4 ENGR I 1 ENGR I 1 CADS I 8 111I __a¡;lLj\f,lti1t~~--_~~ SODA I 7 DFX I 1 DFX / 1 ~.r\],............1I11!1' li~E~~~MI~I~·JiII~l'fkvŒ~ DFX I 4 ~-~~~~ "..~I..,.... SC-NA 1 1 ....~~t , . . , '!1! J,' '__IWI~" .': ,.,. :BI~.U_~.mif4~1~_I$,,· ¡.: ,'.- ,,~ REMARKS 2/14/2003: Begin bacteria problem. Hit it hard w/Greencide, BioBan. 2/15/2003: Run 95/8" csg to btm, cement. 2/16/2003: RIH, wash thru cement. Drill 20', run 1eak-offtest to xxxxxxppg EMW. Build new FloPro mud in pits. 2/17/2003: Disp1 new FloPro mud into hole at 4.7 bpm, 800 psi. Dump returns. Drlg ahead. 2/18/2003: Dril1ed @4675-4916';POOH @shoe;repairs;reamed @4367-4916';drld. @5430'-sht. trip;dril1ed ahead 2/19/2003: Dril1ed @5934'; CBU 3X-POOH tlshoe; rig repairs; RIH-dril1ed ahead @6345' @midnight .~I;,~~ '.. ~·ßl,~~,'11!~~+,~i·~~!~~~ff.!:ðJ'\~~~9,~M,~~J'J~"~~~'~..,k}f~~'\:Vv~(~",:"',,,~·:;W¡f,:'Ì'.ft~~,,~.;·,,~,,~.!.,j,~t9J..:~V".. ,. ...: 4 ~ f'· ( DRILLING FLUIDS SUMMA~~ Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 c;ontractor: INLET DRILLING Field/Area: WILDCAT Description: SEC.29rr2N/R12W.SM Location: CLAM GULCH, ALASKA _..~. ;. ',_...~,,'., '. ',..' .'. .....~. I......" -. '. ,....;'C,.--_._...... ~;.; !:.' ft 7230/7087 7508/7364 7950/7808 8517/8373 FLOP~1;á1~ . FLOPRO . FLOP~O 1~~-Mt~8Jþ4;~..;::"-"'JI.-~'I&~Lt....W' , bbl 844 . 877 836 867 ~- . ,~:i_1 ·1l~i '. .... 1352 : 1:400 -1I1i1"WL1.~ .JIJt~ PIT PIT ¿~:~ lb~~ 9.4 95 OF . 1400 ~... . ,: " '_."' ·~,il-:iN,~·t~; ~' ~f; \ 'RI"'·· J: .' ;. : " 'if~'.i': ,',,' ~ .'__. JI" ~.j\~\_",~ '--If Ii'" . "\;_' .'·i~ cP ~.,....... B'I }J~. I ,.' i,' . , , raJJ" ~ \ ' ~ ) \ C. ¡~ p. ,~: m.s~' <?~~I .Q1~'. . ' Jill Dai . s~ l. , . "^ ~ ,,~_'" rf .. ii....,....>,. .. ...·.··aiFDCh~FLÖ,'1 12 SÖ·NIl ' . .. ~y"", ".J.""",,.,~ .'.s<;~/ L~- ........ . .. , .. . ....' .(..1,1, .aBI. "'. .,~.,,~.;,.{lrnl..T(~S\¡,~.f___~'I~-JitiW\T~'"_~ _.t"~ _h' ~t:~Th{·~~~~~::~~a...__ W~ ~·r--Jk.~~i1W 'IIt:J ~ ...._IL.__L__h-n."'~.~1~b!tJ!}UlildllJWlI!Œl;ø·~1....w'i!'lijl~""'¡¡,..r.:..._· .,. V._·· .... ... . .... I '.··,.D··. _rJI[T!''f.vr~~~.~~M~iJl¡J\,~~,~In,!!!II.\:I\IIJi.~'l..IJ.ttl~~jß ;...... ." . REMARKS 2/20/2003: Drilled @6677'-circ.lcond.; short trip @5934'; RIH-drilled ahead @7230'; CBU for short trip 2/21/2003: Short tripped t/6677'; RIH-{irilled ahead @7230-7508'; circulated/conditioned hole; POOH tlchg. BHA 2/22/2003: BOPE test; chgd. bit, BHA; RIH t/shoe; cut drlg. Hne; RIB @7430'; wash/ream tlbtm.; drld. ~head@7S08-7950' @midnight 2123/2003:Drilled@8273'-circ.lcond.; short tripped @7490'; RIH-dril1ed ahead until midnight; hole in good shape 2/24/2003: Drilled @8774'; C.B.D.-POOH t/shoe; wlo top drive; continue POOH; wlo top dhve;chgd. bit,BHA; RIH 2/2;5/2003: RIH-wash/ream @8765-8774'; dril1ed ahead to@9382'@midnight '~\W'i~*:;; ";::,;'rl~ ¡¡,";;¡ì~!'.¡'I;.r~lf:'~i!·' . :';\q/~~'I!I;;¡:r~¡"~~";;1~l!,1~ ~~~~:~~I~ìá~~(~:H~t!µ( ,1·¡¡"'.¡ii'f~~i1,\:::".' .~~~~~~~~.,:~.,,..~..;,,~:~ JI.~:~>1' . I" ,','~ 'f"~.I,~~~~~,r..t~~ ,I"'(~ 'I \~t., \ 5 I ~ · OR/LUNG FLUIDS SUMMA! I I I I .9968/9818 FLOPRO Field/Area: WILDCAT Description: SEC.291T2N/R12W,SM Location: CLAM GULCH, ALASKA ·-.~f~-\ ~.L,J(t.-:7 10356110202 1035~/I0202 10356/10202 914 FLOPRO 904 FLÙPRO Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DRILLING FLOPRO 918 1850 . 7~O : .:. n " '. '.',': 1.\,' I~, . 1·3 DFLO I' 4 ~F~Q LJ 0 ENÇJß. Ii· . C404 I 1 I . 1?rt;ØLIL : '-~:I~~~~Ã/l-~;~~ ~S~~~/IO *.. ,C~/1l ~~~~ ~j= .tiJ~"~~rk~I'''i~"-' . J.." VJr~~.~.¡~~~ìt:""__~""lr,~~'IIJ~~m~··""ffU:i_~ ~lJr.rr~~.·'..~·'"P~'''ð·.·.af~~1ar_\,·__ï\l'~'~~~~"~ REMAAKS 2/26/2003: Noted minor amounts of coal across shakers. Wiper trip smooth. R1,Inh'g.centr van as needed. 2/27/2003: Build'g volµme as t)eed~. Fluid loss getting hard~ to maintain. Add'g SafeScav for 02. 2/28J20Ö3:Drill to TD at 10356'. Circ hole clean, POH. 3/1/2003: RIHwllogwbile drh~ tool, circulate :lTöm shöe down to TD. Take 45 bbl water trom rig into pits, treat wI Dualf1o, Flov 3/2/2003: See'gmore coats over shaker screens. . Put 3 X 200 PYR mesh screens back on shaker#2. 3/3/2003: Mudft'om hole Went 3$lys\v/otrea,trnent:"'tetums very sour, dehydrated. . '~~ :i;~. ViifJ~J'W.¡'ë;}i ~,~~ír¡'O'~"·j'·'l~~~i'¥.'W~j,:·',·~·~~¡'n~· ; ,: P,." .. ~:~~;t~,'~': ~~'''~~~~~l'~..~¥ji~~ '..,..',\', ;~~~:,~ .~.,... ~\~~·~r.')R\f~t'~I~~i·· 6 " . I. .,.,,'~. .k,...: '¡: : .~ . .. , ~, ' ~ I ,,1141,1' ~'. "" :: .1".,.,:. "-,' ( I I I I r:lJ -(. ~ DRILLING FLUIDS SUMMA~ Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DRILLING r'~~ .De thltVD MudTe Cire Volume 10356/10202 FLOPItQ I., ~.~~~. 10356/1 0202 "IQ . PITS ARE EM 529 Cire Pressure ..~ a $ "'.,... '..' .',.,...,....::...~.:, ... .....'... .....'. "..'., ....' .,.. .. .... ..'.... .,..'., .', .~. '.'.".', .".. .:. ,".'.: '), :Qtt-L 1 G~ 1 .. ,,_. ~"-'!'"V,~,~,,,..:' ~l~~_. ___...-!f:''''RJI, _"IØJ l jJ.I~j ,li",J"IMJ,~~.µ~}¡~-J. j"",. '~~.sO..,J.~IM\uw.~t. í f¡'~fl;::'_i..lè,"-"'- .J,~.. ti,.-, ,L~fP-¡ " ,.~,.~. n-~ 1111''.; . .: ,',' ~ ,.' '" 'r~..", II " . . ~-~""-.-',rl t" I I I I Ii,JilUJ[IJHUJi<~.-.. . .. . .·...IIf'-I.~,~V . . ~1îL;¡~~~~],4JJ¡. ,,~!U. 1~" . ,11nt:~j~~lGItâ_Jliaw"~ tr.~.~_Jl'r,l.L4 ... r ·.·..·j~~j+~l ,r"l~ijTt~_ ~·J~JlJ.~t~~~}-'~~~~~ì.,I. ..,~""~f...i4IIo . ' . 'm, 11\ ' ~~~c-,-..c"", T,L'r~¡~"~':~*~ ReMARKS 3/4/MQ3:POH. Mud in þit$ Söur after 12 .hours. Treat w/Gcide, Myacide, caustiè. 3/5/2003: Mud sour'g. Add cau¡¡µc, Greencidejust after midnight. Add bicarb for cementing. . '.. . \1,1'. ¡,.:. , . . '~'.~ ,,~~'." ~..', :ell. ". .."'."I'Irlf" l"'·. .... ,·.ll· ]···¡'~rJ·..","'."..~"...·.....>.~,.,. '. ..... ¡'.['. .'. ". . ... " ~~~ .~: "'~-:='r':--; _~ .~¡;~~.~ ~ :'...... --f".-. ~f~~ ~ ~;:~~~~ I ~. ..'..... t_mm ¡:":;~óiMf Al\I~:J~~.n:.~...:..,.,-.;..,. . ¿.;: ~~ ."o.c:"'-:::- .'.;.:~ :.' -- ,,~ - '- "'.' - ~'..-, .Y::- '2~~ , 0: ---;-- t- I:: . I:: f~»'~ , œ-o-a r.-- "011'.·-·10"'- .-.0- GtlIOm 1 J I T ~ 9 ¡ _ ¡L . .. '" '9 Y It a a "0 -- --- . ~? 0 . I .: 'r : . " .j J u ¡, t- u· Depth ft na,np o~ ø y uy , 'J , t- ~ ~ ~ " r MBT pH Pm;Pf,Mf IbIbbI 20 010 0 1020. o 1 2 3 ~ ~ "1 0Ii'I :¡--- It ". 1 - 20000 Chlorides mgll Comments: WILDCAT Well Location: CLAM GULCH, ALASKA Well Name: ABALONE #1 Operator: MARATHON OIL COMPANY r 10 20 API FL, HTHP F\. ccJ30m .~ ~ 'r 1 100 0 - '11 Ge110s. GeI1Om.GeI3Om 1b/100ftZ ;' j 11 tt----q. L t , " a:!J IIID 1..;..0-.: PV I' -- YI' MlÌcfCost $ x 1000 \ t~ \ 1 200 50 25 ·PV,¥P;U;VP 1b'100ft' Drilling FfUid Pr()pérties 7 e1B1i6.2OOÓ1IoILLÇ.,AI~- -- --- - -...-,...... Depth ft -;~', -_. r:lJ . , HYDRAULICS SUMMAkY Field/Area: WILDCAT Description: SEC,291T2N/R12W,SM Location: CLAM GULCH, ALASKA 1/29/2003 1/30/2003 1/31/20.03 2/1/2003 2/2/20.0.3 2/3/2003 145 170 273 886 1442 1950 -1 1· 2 3 4 _œ1laL-~..~ __~. ._.. 8.7 8.7 8.7 8.85. 9.1 9.3 9.25 16 16 17 14 12 17 15 15 11 21 45 21 20 21 4 4 6 26 5 5 7 .6004 .6714 .5334.30.72 .4475 ,5454 .50.25 .7824 .4377 1.4561 9.2691 2.1616 1.3155 1.673 .4289 .3953 .297 . .15 . ,3653 .3953 .29.94 2.120.1 .. 2,2395. 3.9438.. 21.71?6 . 2,942,7994 . 45832 ,~...~.-.!~~.--~.....- 66 . .. 66 . 196·, '221 29~ ··295· 557 130. 130. 80.0. 40.0 ¡Zo.o. . 1420 1430. 5 5 91 52 20.7 244 465 Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DR1LLlNG 1/27/200.3 1/28/20.0.3 145 145 -3 -2 .I!> .. 8.7 16 25 9 .4753 2.257 ~2914 ,:'. .,5;?704' 3 2 14 95 4 4 39 92 2 6 53 189 ï$$ 523 93 298 3 ' 6 2$:~827 .,,' .'.:. .. i.' .'" ( ........' 'r ., , .. ,. . .... ... .. .... .. ...: .. ........ ..... . .... .. .. . 3x18 14 3 6 234 6 2:>50 2x18 2x16 13 6 .0.3 80 ...$1 22 501 9 30.49 5 220. '1 ./ 15 257 ,..,... .., . .., , ., ,.. . . ... . ·10·'· ... .:.III j ~ .. ~ -,. , I' 1; I. ' " ~ \ ¡ \ Ii" ¡. " ¡ , \ I 'r. ~ .. 'I'" . .' ..'... -'. .'.. '..' ..' .. '..'... '. 2739 , 22 501 9 ?049 26 244 63 4857 25 244 64 2723 41 273 130 2182 ~:,.\' ;, ··.··.····\··..fl.,. .\10:.._' ..':.:.-'... ..,... ..,' '. . .... ......' ...... ·1. ....".,. ,.. ,... .", .' ,:t ,.:.:. " . '..' " '. ,..,., ·.20 -5 -36 0.0 I I I 12 11 47 0..0. 9 9.Q6· 20 6 22 12.7 39 19'18 529 2~ 63 9.7 2.24 30. 37,6 .~ 9,3 ··f3 ..~... '" 8.6 '" 87 '" 0;92 o 39.6 .~(i~'~".~_,,_.,. '~A7 . ····!f59 '" ... .. 9~5$. . .. .9,(i$ .-.'. -- ~ . . . ..:.., , .... "..'... .:.... ...... ' ·.·'i.·.' ... .... * ·Q,~9~(H 9.6 9$' ~72 245 2930 .. ..... . \4 83 85 034 33 '" '" '" ... . o '" '" . '" '" . ... ... '" '" 2 I I I ... '" '" '" '" '" '" '" · '" · '" '" '" · 0 0 .....' 9.25 * .. *. . 9.46 '" '" -- . ,_ . ," . ,. . .,.~,,\. I,· .. ·1:' ..1. ' ,~,,:.. '" ... '" '" '" '" '" '" "" '" ... -- ,- '" · .. 81'() J025. , " ' , 'J ' I 3x'{8' . 14 ... ... · '" 2.5 2.2 ... ... '" ... 89 i;Q4 "'. . · '" .76 ;ª' '" '" '" ... 1Q1 'ZOQ $]7 534 15ØO 467 . 9.35 11 27 15 .3668 4,1167 d78 11.9118 . 510 1200 ~~7. 9,2 11 32 17 .3286 5;91 . .1713 ·'13.71~4 o o . 9.05 9. 37 21 .251.8 . 9.8333 .14?7 17,6678 9.0 9 30 17 .2996 6.4253 .162 13,9272 o Ö .. 9,2 9.3 9.0 15 15 9 22 19 20 7 4 3 .491 .5272 .3899 1.8474 1.3541 2.7191 .2994 .4729 .4393 45832 1,9734 1.5634 ''''- 0 0 0 0 . 9.25 11 24 13 .3943 3.1942 .2084 9;873 . ~34 ··14]50 452 - ' ., ,... I :'. ' ,... ,." >..,. ~ ! . - _ ... ~. ,. ". ~_. :. ...... . - "·oJ' Field/Area: WILDCAT Description: SEC.291T2N/R12W,SM Location: CLAM GULCH, ALAS~ 2/7/2003 2/8/2003 2/9/2003 2/10/2003 2210 2210 27~ 3$58 8 9· to: I! . Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DRILLING ---- 2/4/2003 2/5/2003 2210 2210 5 6 2/6/2003 22)0 7 r HYDRAULICS SUMMARY ( ~ ~ .( {" HYDRAULICS SUMMARY Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: . INLET DRILLING 2/12/2003 2/1312003 4350 4350 13 14 n 9.35 9.45 11 11 28 26 12 12 .3585 .3755 4.4503 3.796 .2313 .2205 ..8,7804 8¡9359 I I I I I Field/Area: WILDCAT Description: SEC;291T2N/R12W,SM Location : CLAM GULCH, ALASKA 2/14/2003 2/15/2003 2/16/2003 2/1712003 2/18/2003 2/19/2003 4350 4350 4370 4798 5557 6345 15 16 17 18 19 20 ._~~. -~~..- 9.5 9.85 9,4 9.45 9.6 16 12 9 10 8 22 25 25 28 29 9 8 12 14 16 .507 .4053 .3388 .337 ,2824 1.7175 3.1533 4.385,6 4.9558 6.7844 .2797 .3249 . .2093 ,1977 .1492 6,0849 5,0241 9.1005 10,8208 13.3836 9.5 14 26 11 .433 2.8681 .2453 7 :8663 2.95 1250 :215 295 1300 224 3 I 4 14 14 13 14 13 14 14 321 304 305 304 322 321 332 % % % % % % % 0.17 0.32 0.25 0.17 0,26 0.0 0.12 19.2 34. 25.8 17..7 . 2~,6 0 14 _' . ... ·"PI\ib-~1f~WI1rr'~a.'lJn~~ " ..,. _ .,~.£~fl.~...._......:~:~.,_.._., , ,!'I .. 9.87 9.86 9,88 9,96 9.87 10.069.91 9.92 9.91 9.88 9.92 9.99 9.89 10.09 9.91 9.93 ,.._~._~"'~~::!dØ____~'- 1 0.28 10.39 10.59 10.48 10.72 10.54 1 O.6~ 10.43 "- -- "~-. "^ n Field/Area: WILDCAT Description: SEC.291T2N/R12W,SM Location: CLAM GULCH, ALASKA ., 2/23/2003 2/24/2003 2/25/2003· '.. 2I26./~003 8517 8774 9~82 24 2S '·26 ' "J_W - 9.45 8 34 17 .2515 9.3356 .1713 13.7164 . , , ,',', ,', ,;, I ;, ,: I· ' 18 20 q 16 41 49 49 S3 1.4 1.67 1.65 1.81 174 183 183 188 236 267 264 280 9AS 1.0 29. 14 ,3293 5,?3.'73 ·.2.()77 :..,l~i§JS~ 9,4 8 30 15 .2756 7,268 ,188 11,12,~ 9045· 9 ' 29 14 .3067 ·5,9894 .1977 2J?;,ª~,2~ . 9,55 8 33 16 ,2572 8.7995 , .1886. 12.?~O(} ~...., 9.4 9.4 9 8 27 30 16 16 .3219 .2756 5.1588 7.268 .1596 .1.696 12.946 .,,:,"4I~ Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Contractor: INLET DRILLING 2/20/2003 2/21/2003 2/22/2003 7230 7508 7950 21 22 23 HYDRAULICS SUMMty f ~ -. .. . ~ C" ~ HYDRAULICS SUMMAkf Operator: MARATHON OIL COMPANY Field/Area: WILDCAT Wen Name: ABALONE #1 Description : SEC.291T2N/R12W,SM ÇOt1t~âc;tpr : IN~ET DRILLING Location: CLAM GULCH, ALASKA . . .c ... . 2/28/2003 3/1/2003 3/2/2003 3/3/2003 3/4/20Q3 3/5/2003 10356 10356 103.56 10356 10356 10356 29. . 30 " 31. 32 . 33 34,. .......... .. ~. _~.~1;!ti'''''~ft - 9,5 9.4 9.45 9.45 9.5 9.5 . .. 9 10 9 9 10 10 27 25 25 26 21 20 12 12 11 11 9 8 .3219 .3626 .3388 .3301 .4034 ..415 5.1588 3.8926 4.3856 4.7649 2.6734 2.4054 .2313 ,2093 .2341 .2341 .2797 ... ,28&5 "\:,. -8/1-804 . 9.1005 8~0112 8~0112 6.084'9 . S'~'3'319 ' '. ........,... ~......_--.-- ~ ...~ 196 2()9. 209 209 ···209 7~Ö 900 lÖ50 10'50 1950 ·~2J lO 128 128 128 .... ... .·..·.._.,.·:h...'-... ....'.'.......,..' ... '. t '-. ...................... r,.. .......,.,. .........,.....'......: ......... 444 142 533 1119 464 143 521 1128 474 .143 480 ,1097 3x15 3x15 . \." . .", ,. ,''"'' " t· .,'" , ' ''''''''. 3X15 9.81 9.83 9.8 9.81 9,83 9.8 , ""'..-' .~~_.. ". .." i., . .. . .. .. '. . . . J!8!Ij\!Wft.I,~~.I:~JJì 10.45 10.48 10.4 10.45 10.4~ 10.4 I I I 223 Z~7· 413 416 .888 986 2~73. ~OQ6 . 3018 .I.~~ 15 ·15'· 15· 208 223 223 . 93 94 94 0,0 0.0 0,0 000 15 222 94 0.0 o 9.77 9.77 9:81 9,:,,81 . ... ,~:! I I 5 16 221 93 0.0 o ~A t- ." -. . -.:~[~ ',,;;:c"~ -:-._.,~,--.::.-~-,::~. :... .:ia,".'...,'. ----,~ ti{~ ~1f~\~J /Í .~ . ~-.~ :,:;<~;.û~~ I ¡-- ¡ I I I ~ r}~--:'-:T/<~<·~:- . .. _.- _ E.. I~ :;fj.;;{({¿ ili~ ., \.~;-: Depth ft \ I ~ I \1 I ¡ . . ¡ . . --' ·1 ,/ .\ . ~ '-------: I I I . , I I . I ·r.z~z:+ ., \ \ I I· . J i i/ \ \ Bit HSI ROP Rot~IIY.WOB Bit prusure ftIh psi psi 4000 0 50 100 0 50 100 0 200 400 0 \ ~ I 0 . Comments: WILDCAT Well Location: CLAM GULCH, ALASKA Well Name: ABALONE #1 Operator: MARATHON OIL COMPANY \ ì -1 ~ 2000 1000 .0 Plmppr psi ..... ~·'-:FV· -0- F!I .-. yp 1: "It: Qt ~1· ~'l' ,. . ~ ~ GO. \ ,~ ¡ .. ~ ! l~ . d 500 Flow -Rate gaUmin ~ \ 7 '\ \r l 10 0 50 100 0 ·FV.PV. YP. R3 Mud Weight b'gal Drillingparameters i ì li DI)s .~ t""""" 010 8- 20 in -Days. Bit Size DIM. 2Oœ1l'l LL.-C. --All RJg/!1Io- Casino Program Formation Tops Depth ft [)f~i;I;Scan -: .- - - . , f rm ()p~tát()r:MARATHON OIL CO Field/Area: WILDCAT Daily WèUName: ABALONE #1 Description : SEC.29fT2N/R12W,~ Discussion COl1ttðctor: INLET DRILLING Location: CLAM GULCH, ALA~ M-I Well: abalone1 1/27/2003 I ID= 145 ft I Day-3 Rig up. Drlg pilot hole 34'·145'. Vac trucks transfer'g mud ITom cellar to shakers. Mix Ge1lWater spud mud for pilot hole. Visc up mud near ID, Mix 440 bbl Ge1lWater spud mud. 1/28/2003 I TD= 145ft I Day·2 TD pilot hole, pump sweep around. POH to drive 20". Prep floor. Rig up hammer. Make up and weld on 1 st joint. Finish pump'g sweep around. Pump sweep around. \. . 1/29/2003 IID= \. 145 ft I Day ~ 1 Check Koomey Unit. Drive 20" conductor. :No mud mixed today. Hammer pipe. 1/30/2003 ID= 170.ft I Day....O N/U Diverter system, P/U36 stds drillpipe. RIH w/BHA #1. PJSM. Build 40 bbl more mud volume för spud. Suild40 bbl more volume for spud. I. ....\.'. U3M2ÖÒ3 \............'.:'.....'.,....':..' \ I TD= \ Day »tiI117;·5Ì111plel~Ø'717()t--un~þle to pass 170', .Circ O\1t, POH. RIH,attempt to drill out of conductor--no go. POH. UDbit,BHA. PIU and MIU h\V4pvy?i)ew~it~~'?~;~1l.RJH, millf/169'to 175', work~g thru shoe. POR, LID mill'g assy. RIH w/drilling ass'y. A.:g¡¡l:.g~Jex.·.tP .,irtçr:)I\$~.:¥P. I... , , '. ,"', ' 17.p"Mt iwi~:1,n¿~,:'89'tþr\tÇqJ19µ~t9rshge.W¡:l~t.on mill.· ··MiU..tbruconductor shoe. . . ··'~:··.d·'<·; ','f;:·'· .., ··"t 2/iliòÓ3 'I' TD:= '. 852 ft I Day 2 I.··:,'; ,I:, ..1 I "'fl I I RI.·, .H~.. t~~'..'b....,tm,l. ,?S..\D. .i.rld...r1..g..,.~o. ·481'. Chg wear plate in mud pump. Dir drlg to 610'. paR. Chg out MWD, RIH. J?ir drlg to 708'. Repair #2 mud ,pump. :Ol~ dttg~01.8p2~at, mId. ~ûi1d'~vot~e, . ß.,pfin'~,~esi1ter as necessary for sand content, solids. Add 2 PAC (broken sx). Add Gel, Gelex for vis, YP when build'g volume. N<?tØ(l.s1~~~!,~.ct~~~}~:,0~~~en PPJU on 02;00 mud che~k. I' " ,.,' ., '_ _ ,I' _ I, ~, ", ',' bir drlg ~7~';;.&5~'::~~·m~~ø~ght. Adding Gel and Gelex to water for volume. Added 2 dr DD per Co Man request. , I"': ,\~':.. ,;:.:'.~:.:.~';"'..~"': .. ,',I I'· I '2/~iŽØð§::;' 1,:·';,;t+;;r·~~m:1~:~,·": "î379'ft I Day 3 :-::, I ; , r' , :. ,.,. I:, .I,' ,', "", .' "\~.'~. ~, .: ~ : ,\,'1.', - ':; "' , . I .. ",Pjr:Øfig;':~52i~88V>êifc;'chg saver-sub, DDrlg to 1007', Circ hole clean, POB. Chg MWD probe, RIH. Ream 885'-1007'. Dir drlg to 1379' at 'h~~4rii~ht, ., . I . Dr,g:~ßad,aui1d'g vis w/gel, gelex. Run dsilter as needed for sand content, solids. Add 3 defoam x after DD additions. Getting clays from Iormation"dump/øiluting with water. Drilling more clays than usuaL Dump/dilution with water. . .( rm Oþerator: MARATHON OIL CO Well Name: ABALONE #1 Contractor: .INLET DRILLING " Field/Area : WILDCAT Daily Description : SEC,29fT2N/R12W,~ Discussion Location: CLAM GULCH, ALA~ M- Well: abalone1 2/3/2003 ,. TD= 1950 ft I Day 4 Drld. @1752'-minor losses; rig repairs; chgd, screens on shakers; drld. @1765'-inc, losses; mixed/pumped 40 bbl LCM pill (20 ppb SafeCarb M)-monitor; mixedlpurnped40 bblLCM pill (10 ppb SafeCarb F/30 pp~ SafeC~b M); monitor-CBU 3X; work pipe; wiper trip @885'-RIH; drld. ahead; built volume in sObblbàtches; losing volume-ran desilter/water/chemicals as needed for volume; Building volume to replace losse$--water, Gel, polyPac, Caustic Soda; adding SafeCarb M while drilling for losses Built LCMpills with SafeCarb M/F Drld, ahead @1?65'-losses; tnixJpump LCM pills (2); monitor well; CBU 3X-work pipe; monitor; wiper trip @885'-RIH; drlg, 2/4/2003 I ID= 2210'ft· I Day 5 Drld,·@1941o:Z110';rigrepair$;drld.(@2210'-CBU 2 times; mixed/spotted LCM pills on trip out (on bottom, @2008', @1630'); POOH-UD BHA; RIH@2130-w~heqtlb~ttøm;Qirê~late/condition; monitor losse!); ran water/chemicalsldesilter to reduce mud weight tl9,2 ppg; mixed/pumped LCM pills (onbotfó~ @2()QO');.mixi~g third pill @1816'@midnight--some losses continue Mixed/spotted 3 LCM pills ontrlp out (22.5 ppb Gel; 1'0 ppb SafeOirb 10; 30 ppb SafeCarb 40) Losses on wiper trip-..;mìxedlspotted LCM pills em trip out (22.5 ppb Gel;. 15 ppb SafeCarb 10; 20ppb SafeCarb 40; 10 ppb SafeCarb 250) Drld. tlTD@2210'; spot LCM pills on trip out; chg. BHA·RIH; wasblream·4osingfluid; mixJspotLCM pills on trip C)ut .. " \ \'.... 2/5/2003 I TD = 2210ft I Day 6 Mixed LCM piH#3@1816';.spot;pullV1680'; mix LCM piU#4-$pot; observe wel1,,-lossescontìnue; mix LCMpill @5-spot; observe well; losses slowed to @2bph~ POOH slowrate;UD BHA; cleared floor of tools; remQveclelevator, bails; rigged up-ran casing string; broke circulation @11l0'; RlH-;.land casipg @midnight Mixed/spotted LCM píl1 {225 ppb Gel; 20 ppb SafeCarb 10; 30 ppbSafeCåtb 40; 10 ppb SafeCarb 250) @1660' Mixed/$potted LCM pm (30ppb ·M- J Seal F in 40 bbls whole mud) @1660' Mixed/spotted:tCM pills; observe well @1664'; losing @2bph; POOH slow; LID BRA; rig up-TQn casing;land.casiJ?g ... .\'..' : ,:.\.\, 2/6/2003 1m = \2:Ú Ò ft · . 1 '.I)~y 7 :Rigdown C$g,;tra11sferringm~d to tigertankfor storage; cleaning pits; RIH-tag.up w/seal; MID cmtg. head; pumped spacer--pumped cem¢nt; lO$t retu:tns-.,noneto$urface; disp. w/rig pump!); RID cmtg, head; POOH w/DP;WQC;wQrkedpnpit dug,; remove!)pider--run 1-1/4" pipet/350' outside 13-3/8"osg.; prep. fltopjob; valve failed--purhped calcium ,chloride brine into active; repair valve Valve leak in pill pit--Iòst calcium chloride brine ii1toactive system Transferred. excess volume totigertì:\nk--hauling to injection Rig dQwn esg. run; RIH-cmt. job; lost rtns,"cmt. not to surface; POOH w/DP; WOC; prep. fltop job; valve leak in piu pit . \ 2/7/2003 rTD~ .,". ..:. 2210 ft I bay 8 I Repaired pill pit valVe; mix¢d calciurnchloride brine f/cementers; topjob-flush stack; pull,UD 1-1/4'1 pipe; rig down tools; NID diverter line, stack;tougþêut csg.; setout stack; cut surface pipe flange; cut casing; N/U BOPE;cln. pits..repair valves; mix FloPro per specsfor drilling; chg. brakes on drawworks . Contaminated active system with calcium chloridebrine/water--sent for injection during pit cleaning; repaired leaking valves, etc. I Mixing new FloPro system, fornext interval per program@report time NOTE: Check is run on 2/8/03 I Cement top job; pull 1-1/4" pipe-LID; nipple down/nipple up; chg. brakes; empty/cln. pits; repair valves; mix FloPro I I 2 . .. ( ( . ~ Operator : MARATHON OIL CO Field/Area : WILDCAT Daily Well Name: ABALONE #1 Description: SEC~291T2N/R12W,~ Discussion Contractor: INLET DRILLING Location: CLAM GULCH, ALA~ M-I Well:abalone1 2/8/2003 I TD= 2210 ft I Day 9 Completed mixing new FloPro system for displacement; transferred mud from tiger tank for cement <;irilling; N/U BOPE--tested; made up, oriented BHA-RIH w/HWDP; P/U and rabbit drill pipe; RIH @2065'; sliplcut dtjlling line Built @500 bbls FloPro for drill out; transferred mud from tiger tank to pill pit to drill cement Solids van on location and rigged up Mix FloPro; move old mud into pill pit for drilling ~mt.; N/U, test BOPE; BHA; RIH; P/U DP; drilling line 2/9/2003 I TD= 2764 ft I Day 10 Slipped/cut drilling line; circulated/conditioned old system; R/U, tested casing to 1500 psi f/30 minutes; clnd. out 13-3/8" csg, wltop ofFC @2163', shoe @2206'; drld. @2209'-C.B.U,; FIT tfll.0 ppg; clnd. pill pit; displaced tf9.0 ppg FloPro wllO .bbl water spacer; old system to tiger tank for disposal; CÍrc.-build additional volume; drld. @2209-2230'; CÍrc.-LOT tf14.5 ppg EMW; repairs; drld. @2230-2764' @midnight Displaced old system following FIT; circulated while building additional volume Continued batch mixing in pill pit to build volume an day; mud weight to 9.2+ ppgat one time--M..;I solids van on location to help control mud weight and solids--rigged up @2300hrs, Clnd.ltestedcsg..; drld. out @2209'; FIT; displaced tlFloPro; built volume; LOT; drld. ahead @2230-2764' @111idnight , \ 2110/Z0()3' I To .= 3470 ft I Day 11 p~r4rl~275()'-33:16'. q~rc hole clèan, Wiper trip to shoe. Shut in well, install breaker for new pump house. Serv rig. RIH-:--no problems, Dir 'drl~t03470'atmidnight . Add S,pda a$h to Jqwer va; Add Dualfl()to}(eep fluid loss in specs. Running Centr Van to keep mudwt in specs. Add 1 sx Safecarb/20 min while 4:r1g fOÏ"seeþäge,tO$ses,Mµdwt incr~g. ,Bøginning to dump and dilute. Will add SafeScav as soon as possible, '~µ11I)'.SC¢ntr.VaJ1...Mud·wt incr'g. Beginn'gto dump and dilute. (.y' .. . ( 'i \ \ I ' '~){i)~bbK\"~:: I'w~ '3900ft I Day 12 X;>irdtlg347()!-3900'.Circholeclean,POH. B(j.ckream to 3410',Circhole dean.. POH. C/Qbit.RlHto $hoe, MßT,mud\Vtïising.Put 230 PYR screens on sh)q #2. Dump, dilute. Rµnning all solids control. . SafeScav trèatment intemtPt~d by bit trip, Got ~'<;it\lrnsin, WiUresuwetreattnentwhen back on bottom. Adjusled Centrifugeperformance, now making .2 ppg cut on return fluid, NOTE: adq 1 cJ,l'S~feSCàvintopits duringtrip--l ppm dissol oxygen after 2.5 hours. Dump 100bbltoday. M:I3T,trll1dwt rising. Dump/dilute, run all solids equip. Put 230 PYR on shkr #2. Tweak centrifuge performance. 2/12/2003 I Tù = 4350 ft I Day 13 Sèrv rig. RIB: to 3472'. Ream to 3S34'.Circ. Ream to 3900'. Dir drlgto 4343' at midnight. DUD1plOO bbls mud, replace with 100 bbls water for dilution. Add SafeScav for dissol oxygn. Centr Van down for repairs at 5:00 PM, Add Soda . Ash at mid for Calcium. Dissol oxygn in specs dur'g trip, got out of specs when dflg, back in specs. after more treatment. Run centr van while tripp'g to lower mud wt. Run van while drlg--van down 5:00 PM repairs. Dump and dilute. 2/13/2003 I TD = 4350 ft -I Day 14 I Dir drlg 4343'-4350'. Circulate hole clean, backream 4221 '-2848'. POH to shoe. Serv rig, RIR--tite 4040'-4273'. Tag fill 4339'. Wash/Reatn to 4350'. Circ. POH SLM. E-Log. Centr Van down. Mud weight rising to 9.6 ppg while backream'g, wash/ream to btm. POH- no problems. Repair Centr Van, process mud in pits During logging. Reduce wt to 9.45 ppg. Centr Van doWn. Mud wt rise to 9.6 ppg while backream'g out. RIH w/9.6 ppg mud-no problems, I I I 3 . ( f Field/Area: WILDCAT Daily D.escription : SEC,29fT2N/R12W,~ Discussion Location: CLAM GULCH, ALA~ M-I Well: abalone1 . ~ Operator: MARATHON OIL CO Well Name: ABALONE #1 Contractor: INLET DRILLING 2/14/2003 I TD = 4350 ft I Day 15 RID SWS, RIH. WashlReam 4272'-4310. RIH, 3' offill. Cire, eond mud, Pump dry job, POH. IJJ;> BHA. Install 9 5/8" esg rams, test. PJSM. Rig up and run 95/8" casing. .. Add'g Greencide, BioBan for beginn'g bacteria problem. Add PolyPac UL to maintain fluid loss within specs. Add Safeearb to replace the material scraped off from the wiper trip. Finish adq'g drum ofConqor 404 just after midnight yesterday, Begin bacteria problem. Hit it hard w/Greeneide, BioBan. 2/15/2003 I TD= 4350 ft I Day 16 Run 9 5/8" csg. PJSM. Cement csg. Install varibore pipe rams arid riser. Test BOPE. RIH w/5" hwdp and POH UD, Caliper pits during cement~g. Lose 0 bbl pump'g cmt, lose 72 bbl displ cmt w/mud. Dump mud in pits, cleaning pits. Run 9 5/8"esg to btm, cement. 2/16/2003 I TD = 4370 ft I Day 17 P/u 41' dp. RIH w/8.5" bit, test cSg~Prillfloat coUar at 4250',wash cement to 4306'. CBD.Wash emt to 4350', drill new fottnation to 4370', GBU. RU~ leak'Qfftestto 16$ppgEMW. POH. ... .. . .. .. .. ... .. NQtE: Mud in left column (20:40 hours) isold.mud for leak-off test. Mud in right column (15:00 hours) is from newFloPro mud being built. Cost for new FloPto mud win be posted on tomorrow's mud check sheet. RIll, wash thtu cement. Drill 20', run leak-off test toxxxxxxppg EMW. Build new FløPromud in pits. HI .\ 2/17/2003 I TD = 4675 ft I Day 18 RIB, clean trip tk,pillpit, displace newFloPro mlld into hole. Pump dryjob,J>Oß. Chgbit. RIH, Pir drlg to 4675' at mìdl1ight. Displace new FloPro It1ud into hole, retuq1s to injection. Build new volume. Reduc'g oxygen content w/Safescav, maintain'g Conqor pþm, NOTE: most driU solids in mud check solids analysis are from Safecarb.· Çlays ~ncreasing after mìdnight. , \ þisplnew floPro mud into hole at 4,7 bpm, 800 psi. Dump ret1Jrt1s. DrI8::m~ad. "~I 2hs/ÌÒ03 fu ~ 55.57 ft I Day 19 Drilled @4675-4916'; PQOH @s~oe; repairwasb pipe; reamed@4367-4916' while tripping in; drilled àhead@4916..54:30'; C.13.U..short tripped tJsbo.e; RIH..holein good cQndition;drilled ahead t/@5557' @midnight JtùJÏning desilterfor solids removal/weight control ~atch mixing fluid as needed for volume Treating for bacteria control Drilled @4675A916';POOH @shoe;repairs;reamed @4367-4916';drld. @5430'..,sbt. trip;dtilled åQead 2/19./2003 I TD = 6345ft l. Day 20 Drilled@5545-5934'; C.RU. 3)(; POOH tlshoe;rig repairs (replaced top drive compensator çylinder;replaced link ti1t~~(lelevat<)r switches; rebuilt @1 pump valve; rig service); RIH-trip in good; drilled ahead@5934-6345'@midnight;rigging up solidß vanfot additional solids control @rnidnight 'NOtE: 1'¢$ted wellwater--dissolved oxygen cOI1tent @6ppm(mix water) I Building volume as neçessary while drilling; attempting to hold weight below 9.6 PPG; rigging up centrifugev~@midnight for additional aid in weight reduction Drilled @5934'; CBU 3X-POOH tlshoe; rig repairs; RIH.drilled ahead @6345' @midnight I 4 I I I I . . ( r . ~ Field/Area: WILDCAT Daily Description: SEC,29tr2N/R12W,~ Discussion Location: CLAM GULCH, ALA~ M"IWell: abalone1 Operator: MARATHON OIL CO Well Name: ABALONE #1 Contractor: INLET DRILLING 2/2012003 I TD = 7230 ft I Day 21 Drilled ahead @6345-6677'; weight had increased to @9.6 ppg @midnight; ran solids van for 4 hrs. .to reduce weight to @9.35 ppg; circulated/conditioned @6677'; short tripped to 5934'-RIH; drilled aheafl to @7230'; circulating for short trip @midnight Ran solids van for @4 hrs. to reduce fluid weight ftom 9.6+ ppg to 9.35 ppg Mixing fluid as required for volume Added· SafeScav NA and Conqor 404 Drilled @6677'~circ,lcond.; short trip @59341; RIH-drilled ahead @7230'; CBU for short trip 2/21/2003 I TD = 7508 ft I Day 22 Circulated/conditioned @240 spm/1400 psi; short tripped up to 6677'; RIH (hole good); drilled ahead @7230-7508'; circulated; POOH to change BHA, test BOPE Treated with Congor 404 for corrosion; added BacBan for biocide; added Caustic to adjust pH to 9,5+ Added Nut Plug faf possible "balling" co~ditioi1s CÔITosion.ring on rig floor to·be added to drill string on trip in Short tripped t/6677'; RIH-drilleda,head @7230-75081; circula.ted/conditioned hole; POOH tlchg. BHA ,. .., ",r.,. 2/22/2.003 \... fu = 7950ft (Day ·23 TestBOP~; set wear ring; changedbit, BHA;surfacetest MWD; RIH @4245';.slip/cut 100' drilling line; inspect brakes; RIH @7430; broke circulatiQu;Wa$bJreø.m to bottom; drilled ahead @7508-7950' @midnight ÇQt:rosi(Jnri~g would not fit into saver sub--not run in string Ran solids van for 1 circulation t() reduce mud weight @9.65 to 9.4 ppg Added S;rl'eScav NA for oxygen reduction (@3 ppm) BOPEtest; ¢hgd¡ bit, BHA; RIH tlshoe; cut dtlg. line; RIM @7430'; wash/ream tlbtm.; drld. ahead @7508-7950' @midl1igbt '\ ': ,:,·,>I',.:'~'",: 2/23/200$ 8517 it [Day 24 tD= Drilled @7950-82731; circulateQ/cÇ)nditioned; short tripped tl749Ö'; RIR..driUedaheadto @8517' @tnidnight; running solids van ÎQr weight reductjQp.@reporttiroe . . Added Greencide for bacteria control Batchtnixed @50 bbls new fluid fotvolumereplacement Running$olids van for weight reduction (9.6 ppg to @9.4 ppg)ªHèporttime Dril1ed@8273'..circ./cond.; short tripped @74~O';E;.JH..,drillêdaheaduntiltnidnight;höle in good shape \ \ . \ .',,, . 2/24/2003 .1 '·Däyi5 \ ',¡.... I to= 8714 ft Drilled ahead f/8517';ran solids V::µ1 for weight reducti()n\1ntil~9.35PPG~chieved; drilled to 8774'-c.B.U.; POOH (tight @7770') tlshoe; removed the top drive valve acçuator; continued trip out; reþI&cetþe top drive valveaccuator; pulled motar..,changed bit; RIB @midnight Ran solids van until weightdQwntQ9.35 PPG . Batch mixed @50 bblsnew FloPro for volume replacement Drilled @8774'; C.B.U.-POOH tlshoe; w/o top drive; continue POOH; wlo top drive; chgd. bit, BHA; RIH 5 Date 1/27/2003 1/28/2003 1/29/2003 1/30/2003 1/31/2003 211/2003 2/2/2003 2/3/2003 2/4/2003 2/5/2003 2/6/2003 2/7/2003 218/2003 2/9/2003 2/10/2003 211112003 2/12/2003 2/13/2003 2/1412003 2/15/2003 2/16/2003 2117/2003 2/18/2003 2/19/2003 2/20/2003 2121/2003 2/22/2003 2/23/2003 2/24/2003 2/25/2003 2/26/2003 2/2712003 2/28/2003 31112003 372/2003 3/3/200-3 3/4/2003 3/5/2063 3/6/2003 Depth ft 145 145 145 170 175 852 1379 1950 2210 2210 2210 2210 2210 2764 3470 3900 4350 4350 4350 4350 4370 4675 5557 6345 7230 7508 7950 8517 8774 9~S2 ()'l2~ 1{J~f)5 IO.) :-f. 1(1_~ 5f. 1{J_~5h lO_~:-On lUJ5i) 1035h W3:-ñ Totals Hole Size in 17.500 17.500 17.500 17.500 17.500 17.500 17500 17 .500 17.500 0.000 0.000 0.000 12.250 12.250 12.250 12.250 12.250 12.250 12.250 12.250 12.250 6.125 6.125 6;125 6.125 6~125 6.125 6.125 6.125 6.125 6.125 6.125 6.125 6.125 {j.125 6.125 6~125 6;125 6.125 Wt lbl gal 8.7 8.7 8.7 8.7 8.9 9.1 9.3 9.3 9.2 9.3 9.0 9.0 9.1 9.2 9.4 9.3 9.4 9.5 9.5 9.5 9.9 9.4 9.5 9-.6 9.4 9A 9.4 9.5 9.4 9.6 9.5 9.5 9.5 9.4 95 9.5 9.5 9.5 452 422 447 500 507 692 836 935 1151 1117 979 924 872 865 873 964 1034 998 998 618 62-1 770 764 ~OY 844 877 836 867 884 876 835 918 914 904 919 919 899 529 60(}5 25 53 14 426 363 760 567 10 270 22 463 238 304 265 51 34 10 13 549 80 150 170 110 57 65 52 6 52 130 10 47 26 21 1 44 23 43 18 6 3 4 3 4 2 2 377 14 1 1 6 3 15 30 10 10 22 23 15 27 16 1 3 1 57 5 10 15 8 7 10 3 6 4 13 2 2 6 6 2 23 5585 260 440 222 277 249 50 29 10 12 474 75 140 155 100 50 55 45 45 117 4 45 20 9 1 39 510 25 52 13 420 360 745 537 4464 138 325 74 470 210 203 185 75 24 390 10 400 71 111 109 70 98 34 35 14 82 37 4 47 6 11 11 414 23 7 220 193 221 112 1012 20 10 10 12 10 21 26 440 239 44 11 10 10 10 5 10 10 15 20 7 452 422 447 500 507 692 836 935 1151 1117 979 924 872 865 873 964 1034 998 998 618 621 770 764 803 844 877 836 867 884 876 835 918 914 904 919 919 899 529 529 ~ ~ Previous Mud In Returned 524 Mud Wt. Mtl. Field/Area Location M-IWeUNo. :abalone1 MUD VOLUME (bbl) Mud Built Chern Oil Water 30 Spud Date : 1/31/2003 Losses Surface Subsurface Storage Active 42 30 - ©-199.7.99 M-I LLC. M·U[)··VOlUMES AIfRights Reserved MARATHONOtL COMPANY· ABALONE #1 WILDCAT 3/11/2003 CLAM GULCH, ALASKA From 0 ft To Date Interval 10356 ft . ~ .' ( , . MARATHON OIL COMPANY M-I SOLIDS VAN USAGE Well Abalone #1 Month of February, 2003 RATES SINGLE DAY RATE 12 HR TOUR $1,750 (Both centrifug~ operating) 24 HR TOUR $3,500 (Both centrifuges operating) 12 HR TOUR $1,250 (One centrifuge operating) 24 HR TOUR $2,500 (One centrifuge operating) STANDBY RATE $500 Rig Up Solids Van BBlS Average Average Average Pounds DATE Processed Weight In Weight Out Cut R~moved . CHARGE COMMENTS PPG PPG PPG Daily 2/112003 0 0 2/212003 0 0 2/3/2003 o· 0 2/4/2003 0 0 215/2003 0 0 2I6/~OO3 0 0 2/7/2003 0 0 218/2003 0 0 219/?OO3 0 0 211 Qla()03 1724 9.25 9.13 0.12 8689 $1,250 1/2 price for 24 hourS 2/11)2003 2400 9.36 9.27 0.09 9072 $1,250 1/2pricefor24 hours 2/12J2()O~ 1257 9.35 9.22 0.13 6863 $1,250 12 hrs (one centrifuge) 2113/2003 708 9.58 9.45 0.13 3866 $1,250 12hrs(Qne centrifuge) 2I14J~903 208 9.55 9.42 0.13 1136 $1,250 12 hrs (one centrifuge) 2115/2QQ3 0 0 211fi)1:~903 0 0 211712003 0 0 2/18/2003 0 0 ~t912Ô03 0 0 2I~O~OO3 420 9.49 9;07 0.42 7409 $1,750 12 hrs (two centrifuges) m112003 690 9.6 9.24 0..36 10433 $1,750 12 hrs (two œntrifuges) 2J2~2003 0 0 mð/2003 780 9.45 9.15 0.3 9828 $1,750 12 hrs (two centrifuges) 2/24/2Q03 0 0 ~5~()O3 0 0 212612003 1309 9.57 9.44 0.13 7147 $1,250 12 hrs(one'centrifuge) 2/2112003 520 ·9.5 9.32 0.18 3931 $1,750 12 hrs (two cen~rifuges) 2/28/2003 0 0 3/112003 408 9.48 9.33 0.15 2570 $1,750 12 hrs (twO centrifug~) . 23,411 520 Pounds Total Remov~ Cost 70,944 $16,250 23,411 = 520 bbls = $23,266 Solids removal cost per pound $().23 Pounds of Drill· Solids Removed I I I Total for Well Estimated % solids in discharge Estimate of dilution fluid required (to maintain 5% drill solids) Average cost per barrel (from standard formula) BBlS Processed 10,424 33% Ibs @ 5% 45 $44,72 Barrels of fluid required to dilute Savings in d.ilution & disposal cost r:::t;;J WFF Operator: MARATIION OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: GEORGE BREWSTER DRILLING ASSEMBLY Bit Size 6.13 in HTC HCM406 Nozzles 3x15 I 1/32" Drill Pipe Size 4in Drill Pipe Size 5.063 in Drill Collar Size 4.75 in 1: Sample From Flow Line Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV yp 1 Osll Om/30m Gel API Fluid Loss HI1fP FL Temp Cake API/HTHP Solids OiVW ater Sand :rvIBT pH Alkal Mud (Pm) Pf/Mf CWorides Hardness Ca LSRV Dissol Oxygn Conqor 404 Length 9780 ft Length 459 ft Length 117ft cP Ib/1 00ft2 lbll 00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol lblbbl ( i! ~C\9- -) ;90 WATER-BASEd. ".UD REPORl No. 39 Date 3/612003 DepthlTVD 10356 ft /10202 ft Spud Date 1/31/2003 Mud Type PITS ARE EMPTY Water Depth Activity DISPL WIKCI Field/Area: WILDCAT Description: SEC.29!T2N/R12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 CASING Surface 20in (á1170ft (170TVD) Intennediate 13.375in (á12206ft (2100TVD) Intennediate 9.625in (á14336ft (4194TVD) Production or Liner in @ß (TVD) MUD PROPERTIES MUD VOLUME (bbl) Hole 488.7 Active Pits 40.3 Total Circulating Vol 529 In Storage CIRCULATION DATA Pwnp Make OILWELL 1600PT On..WELL 1600 PT Pump Size 4 X 8.in 4 X 8.in Pump Cap 1.227 gallstk 1.227 gallstk Pump stk/min 85~94% 85~94% Flow Rate 209 gallmin Bottoms Up 76.9 min 13069 stk Total Circ Time 106.3 min 18072 stk Circulating Pressure 1050 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 DEFOAM X 5 GA CN 2 POTASSIUM CHLORID 50 LB BG 311 OF ft 10356/1 0202 Ib/gal s/qt of mg/1 mg/l Rr~cr 11:0 MAY 1 j 2003 AlðÐtta Oil & Gø.¡ CQn~. (~mm~ AmltM'. SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Hr 14 14 o o Size 230/230/230 200/2001200 cps ppm ppm MUD PROPERTY SPECS Weight 8.65 Viscosity N/C Filtrate N/C REMARKS AND TREATMENT REMARKS Displ hole w/drill water fÌ'om rig pits. Build 420 bbl6% KCI w/CRW corros'n RIH wlbit, scraper SLM to 4200'. Test csg. Displ mud out of hole w/drill water. 2 inhib. Disp1349 bbl KCI brine into well, dump'g drill water. Dump, clean pits. Short trips to 2181, RIH. Displ6% KCI w/corros'n inhib into well. Engr released 5/6/03. TIME DISTR Last 24 Hrs MUD VOL ACCTG (bbl) SOLIDS ANAL YSIS (%/lblbbl) MUD RHEOLOGY & HYDRAULICS Rig Up/Service Oil Added 0 NaCI .I np/na Values Drilling Water Added 0 KCI I kp/ka (lb-s^nl 1 OOftZ) Tripping 6 Mud Received 0 Low Gravity I Bit Loss (psi / %) Circulate 6.5 Desilter 0 Bentonite I Bit HHP fhh& / HSI) Test Csg 1 Shakers 0 Drill Solids I Bit Jet Ve ( Is) 130 Dumped 23 Weight Material I Ann. Vel DP (ftlmin) 237.41 Shakers 0 Chemical Conc - I Ann. Vel DC (ftlmin) 341.17 Evaporation 0 Inert/React Crit Vel DP (ftlmin) Centrifuge 0 Average SG Crit Vel DC (ftlmin) Formation 0 Carb/BiCarb (m mole/L) I M~I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAilY COST CUMUlAT~VE COST BOB WILLIAMS (907) 240-4116 (907) 776-8680 $ 4,713.72 $ 224,709.46 c r:¡j WFF Operator: MARATHON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: INLET DRILLING Report For: GEORGE BREWSTER DRILLING ASSEMBLY Bit Size 6.13 in HTC HCM406 Nozzles 3x15 I 1/32" Drill Pipe Size 4in Drill Pipe Size 5.063 in Drill Collar Size 4.75 in Sample From Flow Line Temp DepthffVD Mud Weight FUlmel Viscosity Rheologv Temp R6001R300 R2001R 100 R6/R3 PV yp 1 Osll Om/30m Gel API Fluid Loss HIHP FL Temp Cake API/I-ffiIP Solids OH/W ater Sand 1v1BT pH Alkal Mud (Pm) pflMf Chlorides Hardness Ca LSRV DissolOxygn Conqor 404 Length 9780 ft Length 459 ft Length 117ft cP Ibl100fP Ib/100ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol lblbbl ( WA TER-BASE¿ .ti.UD REPORT No. 38 Date 3/5/2003 DepthfTVD 10356 ft /10202 ft Spud Date 1/31/2003 Mud Type PITS ARE EMPTY Water Depth Activity LAY DN DRILLPIPE Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No,: abalone 1 OF ft lblgal s/qt of CASING Surface 20in ~17Oft (170TVD) Intennediate 13.375in ~2206ft (2100TVD) Intennediate 9.625in ~4336ft (4194TVD) Production or Liner in @)t (TVD) MUD PROPERTIES pIT(â}20:20 pIT~12:30 N/A N/A 10356/10202 10356/10202 9.5~80°F 9.5~84°F 41 42 120 120 40/30 41/31 26/22 26/23 10/8 10/8 10 10 20 21 10/13/17 10/14/19 12.8 10.6 CIRCULATION DATA Pump Make OIL WELL 1600PT OIL WELL 1600 PT Pump Size 4 X 8.in 4 X 8.in Pump Cap 1.227 gallstk 1.227 gallstk Pump stk/min 85~94% 85~94% Flow Rate 209 gallmin Bottoms Up 76.9 min 13069 stk Total Circ Time 106.3 min 18072 stk Circulating Pressure 1050 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGrnEER 1 1 CAUSTIC SODA 50 LB BG 1 M-I BAR 100 LB BG 50 SODIUM BICARBONA': 50 LB BG 5 GREENCIDE 55 GA DM 1 BIOBAN 1 LB 30 MUD VOLUME (bbl) Hole 488.7 Active Pits 40.3 Total Circulating Vol 529 In Storage mg/l mg/l 2/ 21 8 8 0/92 0/92 1R 1R SOLIDS EQUIP Size Hr 6 6 Derrick Shaker 230/230/230 8 9.0 9.3 Derrick Shaker 200/200/200 8 0.1 0.2 Cleaner 1 0 0.112.5 0.15/2.4 Centrifuge 0 22000 22000 100 80 9800 14800 4 2156 cps ppm ppm MUD PROPERTY SPECS Weight 9.35-9.6 Viscosity 40-50 Filtrate 6-8 REMARKS AND TREATMENT Add caustic, Greencide just after midnight. Add bicarb for cementing. Dump/clean pits. TIME DISTR Rig Up/Service Drilling Tripping Plug back REMARKS liD hwdp. Clean rig floor. RIH w/cement retainer. Chg top drive bails. Set retainer at 4283'. PJSM. Sting in, establ inj rate 4.2 bbm at 1800 psi. Pump 39 bbl cmt. Pull up to 4190'. Rvs circ 100 bbl. RID lines, pump dry job, POH. liD pipe, dump, clean pits. Last 24 Hrs MUD VOL ACCTG 3 Oil Added Water Added Mud Received Desilter Shakers Dumped Shakers Evaporation Centrifuge Fonnation M-I ENGR I PHONE BOB WILLIAMS 5 4 (907) 240-4116 (bbl) o 39 o o 414 o o o o o RIG PHONE SOLIDS ANALYSIS (%/lblbbl) NaCI .I .1 KCI 1.61 15. Low Gravity 5.6/51.4 Bentonite .111. Drill Solids 5.1 45.5 Weight Material .7/10.6 Chemical Cone - I 5. Inert/React 6.734 Average SG 2.78 Carb/BiCarb em mole/L) 2./ 10. WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.637/0.176 kplka (lbos^n!100ft2) 0.361/6.405 Bit Loss (psi I %) 143 I 13.6 Bit HHP (hhp I HSI) 17 / .6 Bit Jet vel (fils) 130 Ann. VelDP (ftlmin) 237.41 Ann. Vel DC (ft/min) 341.17 Crit Vel DP (ftlmin) 304 Crit Vel DC (ft/min) 317 ECD (ã) 10356 (lb/gal) 9.96 DAilY COST CUMULATIVE COST (907) 776-8680 $ 3,639.10 $ 219,995.74 c ( ~WFF Operator : MARATHON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: MIKE LESLIE DRILLING ASSEMBLY Bit Size 6.13 in mc HCM406 Nozzles 3x15 I 1/32" Drill Pipe Size 4in Drill Pipe Size 5.063 in Drill Collar Size 4.75 in Sample From Flow Line Temp DepthffVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R 100 R6/R3 PV yp I 0s/1 Om/3Om Gel API Fluid Loss HTHP FL Temp Cake APII.HTHP Solids Oil/Water Sand :MBT pH Alkal Mud (Pm) Pf/Mf Chlorides Hardness Ca LSRV Dissol Oxygn ConQor404 Length 9780 ft Length 459 ft Length 117ft OF ft lb/gal s/qt of cP Ib/lOOft2 Ib/l00ft2 cc/30 min cc/30 min 1/32" %Vol %Vol %Vol lblbbl mwl mg/I 21 8 0/92 TR 6 9.5 0.25 0.25/2.8 23000 80 26400 3 2352 WATER-BASED( JD REPORT No. 36 Date 3/3/2003 DepthlTVD Spud Date 1/31/2003 Mud Type Water Depth Activity Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 TR 6 9.3 MUD VOLUME (bbl) Hole 488.7 Active Pits 430.3 Total Circulating Vol 919 In Storage PIT(á}07:45 94 10356/10202 9.45(á}88°F 42 120 42/33 29/24 13110 9 24 12/16/20 8.8 21 8 0/92 TR 6 9.0 0.1 0.1512.4 24000 100 28400 10356 It /10202;ft FLOPRO TRIP OUT CIRCULATION DATA Pwnp Make On.WELL 1600PT OILWELL 1600 PT PwnP Size 4 X 8.in 4 X 8.in Pwnp Cap 1.227 gallstk 1.227 gaUstk Pump stklmin 85(á}94% 85~94% Flow Rate 209 galfrnin Bottoms Up 76.9 min 13069 stk Total Circ Time 184.7 min 31396 stk Circulating Pressure 1050 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 CAUSTIC SODA 50 LB BG· 11 M-I BAR 100 LB BQ 89 SAFECARB 10 50 LB BG: 18 DUALFLO 50 LB BG· 18 GREENCIDE 55 GA DM 1 BIOBAN 1 LB 30 Safe-Scav NA 55 GA DM 1 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner I Centrifuge Size 230/230/230 200/200/200 Hr 24 24 6 o CASING Surface 20in ~ 170ft (170TVD) Intennediate 13.375in (ãJ2206ft (2100TVD) Intennediate 9.625in (à}4336ft (4194TVD) Production or Liner in @,ft (TVD) MUD PROPERTIES FLO(á}19:40 FLO(á}14:30 103 92 10356/10202 10356/10202 9.45(á}103°F 9.4(á}92°F 43 42 120 120 44/35 44/34 31/25 30/25 13/11 14/12 9 10 26 24 13/16/23 14/17/22 7.6 7.8 cps ppm ppm MUD PROPERTY SPECS Weight 9.35";9.6 Viscosity 40-50 Filtrate 6-$ REMARKS AND TREATMENT REMARKS Mud &om hole went 3 days without treatment. Returns very sour, dehydrated. LWD £18250-10356'. Circ hole clean, POH. Adding caustic, Greencide and BioBan. Coals quiet. Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received 18 Evaporation 1.5 Centrifuge Fonnation Left in Hole Desiher Shakers Dumped M..J ENGRJ PHONE TIME DISTR Rig Up/Service Drilling Tripping LWD Circulate BOB WILLIAMS (907) 240-4116 (bbl) o 9 o o o 10 o 1 10 o RIG PHONE SOliDS ANALYSIS ('.Mlblbbl) NaCI ./,2 KCI 1.7/15.6 Low Gravity 5.91 54.1 Bentonite .11 .6 Drin Solids 5.3/48.5 Weight Material .3/5.1 Chemical Cone - I 5. InertlReact 7. 1899 Average SO 2.69 CarblBiCarb (m molelL) 5./7.9 WAREHOUSE PHONE (907) 776-8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0536/0.130 kplka (lb-s^n/100ft:z) 01754/9.497 Bit Loss (psi! %) 142/13.5 Bit HHP (hhp I HSI) , 17 I .6 Bit Jet Vef (ftfs) 130 Ann. Vel DP (ftlmin) 237.41 Ann. Vel OC (ftlmin) 341.17 Crit Vel DP (ftlmin) 327 Crit Vel DC (ftlmin) 337 ECD (âJ 10356 (lb/gal) 9.97 DAILY COST CUMULATIVE COST $ 6,469.67 $ 215',Û42.99 ~ Length 9780 ft Length 459 ft Length 117ft Sample From Flow Line Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/R100 R6/R3 PV yp lOs/1Om/30m Gel API Fluid Loss IDllP FL Temp Cake APIIHTHP Solids OillW ater Sand :MBT pH Alkal Mud (Pm) Pf/Mf Chlorides Hardness Ca cp lbll 00ft2 Ibll OOft2 cc/30 min cc/30 min 1132" %Vol %Vol %Vol Iblbbl LSRV DissolOxygn _ Conqor 404 ( WATER-BASEd .~~UD REPORT No. 35 Date 3/212003 DepthITVD 10356 ft /10202 ft Spud Date 1/31/2003 Mud Type FLOPRO Water Depth Activity LOGGING Field/Area: WlLOCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 OF ft lblgal s/qt OF CASING Surface 20in ~17Oft (170TVD) Intennediate 13.375in ~2206ft (2100TVD) Intennediate 9.625in ~4336ft (4194TVD) Production or Liner in (â>ft (TVD) MUD PROPERTIES FL0(ã111: 15 94 10356/10202 9 A(ã194 of 42 120 42/33 29/24 12/10 9 24 12/16/21 7.8 ~WFF r~,~ Operator: MARA mON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: :MIKE LESLIE DRILLING ASSEMBLY Bit Size 6.13 in HTC HCM406 Nozzles 3x15 1 1/32" Drill Pipe Size 4in Drill Pipe Size 5.063 in Drill Collar Size 4.75 in mg/l mg/l 2/ 8 0/92 1R 6 9.0 0.05 0.05/2.5 24000 80 26800 cps ppm ppm REMARKS AND TREATMENT Add SafeScav for oxygen control, Dualflo for fluid loss control. Chlorides slowly dropping 1Ì"om minor amounts of water additions. Put 3 X 200 mesh PYR screens back on #2 shaker. TIME DISTR Rig Up/Service Drilling Tripping Repair LWD Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Evaporation Centrifuge Fonnation Left in Hole Desilter Shakers Dumped M-I ENGR I PHONE 1 11 BOB WILLIAMS (907) 240-4116 (bbl) o o o o o o Q o o o RIG PHONE MUD VOLUME (bbl) Hole 488.7 Active Pits 415.3 Total Circulating Vol 904 In Storage FL0(ã11l: 15 94 10356/10202 9 A(ã194 of 42 120 42/38 29/24 12/10 4 34 12/16/21 7.8 2/ 8 0/92 1R 6 9.0 0.05 0.05/2.5 24000 80 26800 CIRCULATION DATA Pump Make OIL WELL 1600PT OILWELL 1600 PT Pump Size 4 X 8.in 4 X 8.in Ftunp Cap 1.227 gaVstk 1.227 gal/stk Pump stk/min 85(ã194% 85~94% Flow Rate 209 gal/min Bottoms Up 76.9 min 13069 stk Total Circ Time 181.7 min 30883 stk Circulating Pressure 800 psi PRODUCTS USED LAST 24 HRS Products Size Amt SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 230/230/230 200/200/200 Hr o o o o MUD PROPERTY SPECS Weight 9.4-9.6 Viscosity 40-50 Filtrate 6-8 REMARKS LWD f/5900'-6937'. Circ, servtop drive. LWD to SOLIDS ANALYSIS (%/lb/bbl) NaCI J. KCI 1.81 16.6 Low Gravity 6.21 56.6 Bentonite J .3 Drill Solids 5.61 51.3 Weight Material J -.2 Chemical Conc - 1 5. Inert/React 7.6046 Average SG 2.6 Carb/BiCarb (mmole/L) 1./ 5. WAREHOUSE PHONE (907) 776-8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0.559/0.139 kp/ka (lb·s^n/lOOft2) 0.619/8.500 Bit Loss (psi I %) 141/17.6 Bit HHP (hhp 1 HSI) 17 1 .6 Bit Jet Vel (ft/s) 130 Ann. Vel DP (ftlmin) 237.41 Ann. Vel DC (ftlmin) 341.17 Crit Vel DP (ftlmin) 319 Crit Vel DC (ft/min) 329 ECD ~ 10356 (lb/gal) 9.89 GAilY COST CUMULATIVE COST $ 0.00 $ 202,411.79 WATER-BASEl .tIIUD REPORT No. 31 Date 2/26/2003 Depth/TVD 9922 ft I 9772 ft Spud Date 1/31/2003 Mud Type FlOPRO Water Depth Activity DRilLING AHEAD Field/Area: WJLDCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 { P::iJ WFF Operator: MARATHON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: MIKE LESLIE DRilLING ASSEMBLY Bit Size 6.13 in HTC HCM406 Nozzles 3x151 1/32" Drill Pipe Size 4in Drill Pipe Size 5.063 in Drill Collar Size 4.75 in Sample From Flow Line Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R6001R300 R2001R100 R6/R3 PV yp 1 Osll Om/30m Gel API Fluid Loss HI11P FL Temp Cake APIIHTIIP Solids OillW ater Sand MBT pH Alkal Mud (Pm) Pf/Mf Chlorides Hardness Ca LSRV Disso1 Oxygn Conqor 404 Length 9356 ft Length 493 ft Length 73 ft OF ft I bl gal s/qt of cP lb/1 00ft2 Ib/lOOft2 cc/30 min cc/30 min 1/32" %Vol %Vo1 %Vo1 lblbbl CASING Surface 20in (á)17Oft (170TVD) Intennediate 13.375in (á)2206ft (2100TVD) Intennediate 9.625in (á)4336ft (4194TVD) Production or Liner in (á))l (TVD) MUD PROPERTIES PIT~02:15 PIT@,21:10 106 114 9968/9818 9922/9772 9.45~98°F 9.45~108°F 45 44 120 120 47/38 46/38 34/28 34/29 16/14 16/14 9 8 29 30 16/20/24 16/21/24 7.6 7.6 mg/l mg/l 2/ 2/ 8 0/92 TR TR 6 6 9.3 9.5 .25 .3 .25/1.6 .3/1.6 27000 27000 60 80 38600 38200 3 2940 cps ppm ppm REMARKS AND TREATMENT Chg shkr # 1 to 3 X 230 mesh. Noted minor amounts of coal across shakers. Adding Dualflo to keep fluid loss in specs. Using spare thennocup. MUD VOLUME (bbl) Hole 475.1 Active Pits 359.9 Total Circulating Vol 835 In Storage FLO~12:45 H4 9786/9638 9.5~104°F -45 120 47/39 35/29 17/14 8 31 17/22/24 7.8 2/ 8 0/92 TR 6 9.5 .3 .3/1.6 28000 80 38400 CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT PumP Size 4 X 8.in 4 X 8.m Pump Cap 1.227 gallstk 1.227 gallstk Pwnp stklmin 120@94% 120~94% Flow Rate 295 gallmin Bottoms Up 53.2 min 12759 stk Total Circ Time 118.9 min 28532 stk Circulating Pressure 2100 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 CAUSTIC SODA 50 LB BG 4 SODA ASH 50 LB BG 1 M-I BAR 100 LB BG 42 FLOVIS 25 LB BG 4 SAFECARB 10 50 LB BG 10 DUALFLO 50 LB BG 13 POTASSIUM CHLORID 50 LB BG 35 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 230/230/230 230/200/200 Hr 24 24 o 10 MUD PROPERTY SPECS Weight 9.4-9.6 Viscosity 45-55 Filtrate 6-8 REMARKS Dir drlg 9361 '-9922'. Circ hole clean. Pump dry job, wiper trip to 8522', no problems. RIH, no :fill. (907) 776-8680 Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Evaporation Centrifuge Fonnation Left in Hole Desilter Shakers Dumped M~I ENGR I PHONE (bbl) o 45 o o 40 11 o o o o RIG PHONE SOLIDS ANALYSIS (%/Ib/bbl) NaCI ./.1 KCI 2./ 18.5 Low Gravity 5.6151.1 Bentonite .1/ 1. Drill Solids 5./ 45.2 Weight Material .4/5.3 Chemical Conc - 1 5. InertlReact 6.6907 Average SG 2.7 Carb/BiCarb (m mol elL) 5./ 12.5 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.476/0.108 kplka (lb-s"nll00fP) 1.257/12.529 Bit Loss (psi! %) 283/13.5 Bit HHP (hhp I HSI) 49 1 1.7 Bit Jet veí (ft/s) 183 Ann. Vel DP (ft/min) 335.09 Ann. Vel DC (ft/min) 481.56 Crit Vel DP (ft/min) 354 Crit Vel DC (ft/min) 362 ECD (tij 9922 (lb/gal) 10.07 DAILY COST CUMULATIVE COST 19 3 2 (907) 240-4116 $ 3,725.62 $ 188,431.79 TIME DISTR Rig Up/Service Drilling Tripping Circulate BOB WILLIAMS WFF Operator: MARA1HON Oil- COMPANY Report For: STEVE LAMBE Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: MIKE LESLEY DRilLING ASSEMBLY Bit Size 6.13 in HTC HCM406 Nozzles 3x15 / 1/32" Drill Pipe Size 4in Drill Pipe Size 5.063 in Drill Collar Size 4.75 in Sample From Flow Line Temp DepthlTVD Mud Weight Funnel Viscosity Rheology Temp R600/R300 R200/RIOO R6/R3 PV yp 1 Os/1 Om/30m Gel API Fluid Loss HTHP FL Temp Cake APIIHTIIP Solids OiVW ater Sand :MBT pH Alkal Mud (Pm) PflMf Chlorides Hardness Ca LSRV Dissol Oxygn Conqor 404 cP Ib/1 OOfP Ib/l00fP cc/30 min cc/30 min 1/32" %Vol %Vol %Vol lblbbl mg/l mg/l WA TER-BAJ_J MUD REPORT No. 30 Date 2/25/2003 DepthlTVD 9382 ft / 9238 ft Spud Date 1/31/2003 Mud Type FlOPRO Water Depth Activity DRilLING Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM location: CLAM GULCH, ALASKA M-I Well No,: abalone 1 MUD VOLUME (bbl) Hole 458.1 Active Pits 417.9 Total Circulating Vol 876 In Storage PIT~1230 106 9018/8874 9.5~102°F 46 120 48/40 35/30 18/16 8 32 18/24/26 7.8 CIRCULATION DATA Pump Make OILWELL 1600PT OIL WELL 1600 PT Pump Size 4 X 8.m 4 X 8.m Pump Cap 1.227 gallstk 1.227 gallstk Pump stk/min 120~94% 120~94% Flow Rate 295 gal/min Bottoms Up 51.6 min 12373 stk Total Circ Time 124.7 min 29932 stk Circulating Pressure 1400 psi PRODUCTS USED LAST 24 HRS Products Size ENGrNEER 1 CAUSTIC SODA 50 LB BG FLOVIS 25 LB BG DUALFLO 50 LB BG POTASSIUM CHLORIDE (KCl 50 LB BG BIOBAN 1 LB Safe-ScavNA 55 GADM Amt 1 4 8 8 24 20 2 1/ 1/ 8 7.5 0/92 0/92.5 TR TR SOLIDS EQUIP Size Hr 6 6 Derrick Shaker 230/200/200 24 9.5 9.5 Derrick Shaker 230/200/200 24 0.33 0.3 Cleaner I 20 0.23/1.7 0.15/1.65 Centrifuge 0 28800 29600 80 80 39600 39200 3 3 2250 2250 cps ppm ppm REMARKS AND TREATMENT Completed Greencide treatment CASING Surface 20in ~ 170ft (l70TVD) Length Intennediate 8819 ft 13.375in~2206ft(2100TVD~ Length Intennediate 489 ft 9.625in ~4336ft (4194TVD) Length Production or Liner 74 ft in (â),ft (TVD) MUD PROPERTIES PIT(â)2350 OF 108 ft 9382/9238 lb/gal 9.55~103°F s/qt 46 OF 120 49/41 36/31 18/16 8 33 18/22/23 7.7 Ran in 2 drms. of SafeScav N A for oxygen reduction MUD PROPERTY SPECIFICATIONS Weight 9.4-9.6 Viscosity 45-55 Filtrate 6-8 REMARKS RIH-fill pipe @shoe; RIH @8765'; wash/ream to 8774'; fanned bottom; drilled ahead to @9382' @midnight; weight increasing slowly-will run solids van when over 9.6 ppg Added Flo Vis/DualFlo for rheology/fluid loss; added KCI for salinity; added Caustic for pH last 24 Hrs MUD VOL ACCTG Oil Added 20.5 Water Added 3 Mud Received 0.5 Evaporation Centrifuge Fonnation Left in Hole Desilter Dumped Dumped M~I ENGR I PHONE ebbl) SOLIDS ANALYSIS '%nb/bbl) o NaCI ./.1 o KCI 2.2/ 19.8 o Low Gravity 5.11 46.4 o Bentonite .2/ 1.6 o Drill Solids 4.4/39.8 o Weight Material .7/10.9 o Chemical Conc - / 5. 4 Inert/React 5.8957 o Average SG 2.8 o Carb/BiCarb (m 111ole/L) 4.6/7.2 RIG PHONE WAREHOUSE PHONE TIME DISTR Rig Up/Service Drilling Tripping Reaming FAULKNER, F. (907) 242-6994 (907) 776-8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0.415/0.088 kplka (lbos^nl100ft2) 1.924/14.788 Bit Loss (psi / %) 286/20.4 Bit HHP (hhp / HSI) 49/1.7 Bit Jet Vel (fils) 183 Ann. Vel DP (ftlmin) 335.09 Ann. Vet DC (fi/min) 481.56 Crit Vel DP (ftlmin) 360 Crit Vel DC (ftlnùn) 367 ECD(âJ9382 (Ib/gal) 10.17 CAlLY COST CUMULATIVE COST $ 4,468.18 $ 184,706.17 c. WATER-BASED(h.uD REPORT No. 21 Date 2/16/2003 DepthfTVD 4370 ft / 4228 ft Spud Date 1/31/2003 Mud Type FLOPRO Water Depth Activity TRIP Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 ~WFF Operator: MARATIION OIL COMPANY Report For: GENE ANDERSON Well Name: ABALONE #1 Contractor: INLET DRILLING Report For: MllŒ LESLIE DRILLING ASSEMBLY Bit Size 12.25 in STC FGXIVC Nozzles 3x18/121 1132" Drill Pipe Size Length 4 in 3539 ft Drill Pipe Size Length 5 in 725 ft Drill Collar Size Length 8 in 106 ft CASING Surface 20in ~170ft (l70TVD) Intermediate 13.375in @2206ft (2100TVD) Intermediate in (â>,ft (TVD) Production or Liner MUD PROPERTIES Sample From PIT(ã»).0:40 PIT~15:00 Flow Line Temp OF N/A N/A DepthfTVD ft 4370/4228 4350/4208 Mud Weight lb/gal 9.85~79°F 9.05 Funnel Viscosity s/qt ,3 51 Rheology Temp of 120 R600/R300 49/37 R200/R 1 00 31/25 R6/R3 11/8 PV cP 12 yp Ibll 00ft2 25 1 Osll Om/30m Gel lb/lOOft? 11/23/27 API Fluid Loss cc/30 min 12.6 HTHP FL Temp cc130 min Cake API/HTHP 1/32" 31 Solids %Vol 7 onlW ater %Vol 1/92 Sand %Vol 0.5 MET lblbbl 10 pH 11.7 Alkal Mud (pm) PfIMf Chlorides mg/l 28500 Hardness Ca mg/l LSRV cps DissolOxygn ppm Conqor 404 ppm REMARKS AND TREATMENT NOTE: Mud in left colunm (20:40 hours) is old mud for leak-offtest. Mud in right column (15:00 hours) is from new FloPro mud being built. Cost for new FloPro mud will be posted on tomorrow's mud check sheet. TIME DISTR . Rig Up/Service Drilling Tripping Circulate (bbl) o 12 o 10 o o o o o o RIG PHONE Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Shakers Evaporation Centrifuge Fonnation Left in Hole Desilter Other M-I ENGR I PHONE BOB WILLIAMS (907) 240-4116 MUD VOLUME (bbl) Hole 610.9 Acti ve Pits 10.1 Total Circulating Vol 621 In Storage CIRCULATION DATA Pump Make OIL WELL 1600PT OIL WELL 1600 PT Pump Size 4 X 8.in 4 X 8.m Pump Cap 1.227 gaUstk 1.227 gallstk Pump stk/min. 115~94% 11 S~94% Flow Rate 282 gaUmin Bottoms Up 84.4 min 19408 stk Total Circ Time 92.5 min 21273 stk Circulating Pressure 1550 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 SPERSENE CF 50 LB BG 4 SODIUM BICARBONA." 50 LB BG 3 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner I Centrifuge Size 180/180/180 180/180/180 Hr 24 24 o o MUD PROPERTY SPECS Weight 9.4-9.6 Viscosity 45-60 Filtrate 8-10 REMARKS P/u 4" dp. RJH w/8.s" bit, test csg. Drill float collar at 4250', wash cement to 4306'. CBU. Wash cnrt to 4350', drill new fonnation to 4370'. CBD. Run leak-offtest to 16.3 ppg EMW. POH. SOLIDS ANALYSIS (%nblbbl) NaCl .11.7 KCl 2.118.6 Low Gravity 5.81 52,9 Bentonite .61 5.1 Drill Solids 4.8/43.8 Weight Material NN NA Chemical Conc . / 4. InertJReact. 3.894 A vera~e SG 2.6 CarblBiCarb (m molelL) -5.1-.1 WAREHOUSE PHONE (907) 776·8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0.405/0.325 kplka (lb·s^n/l00ftZ) 3.153/5.024 Bit Loss (psi I %) 98/6.4 Bit HHP (hhp 1 HSI) 16/.1 Bit Jet vet (ftls) 106 Ann. Vel DP (ftlmin) 51.56 Ann. Vet DC (ftlmin) 80.31 Crit Vel DP (ftlmin) 321 Crit Vel DC (ftlmin) 365 ECD ~ 4370 (lb/gal) 10 CAlLY COST CUMULATIVE COST $ 812.25 $ 101,g76.82 (, ( WELLSITE INVENTORY WFF DAIL Y REPORT Operator: MARATHON OIL COMPANY M-I Well No. : abalone1 Well Name: ABALONE #1 Report No, : 21 Location: CLAM GULCH, ALASKA Date: 2/16/2003 COST SUMMARY Net Daily Cost : 812.25 Sales Tax : 0.00 Total Daily Cost : 812.25 Cumulative Cost : 101876.82 INVENTORY Product Unit Begin Recvd Recvd Used Used Return Return Final Daily Name Unit Price Invent Today Total Today Total Today Total Invent Cost Total Cost ENGINEER 1 625.00 0 1 21 1 21 0 C C 625.OC 13125.00 M-I GEL 100 LB BG 12.96 0 C 595 C 370 0 225 0 4795.20 CAUSTIC SODA 50 LB BG 28.65 31 C 53 C 22 C C 31 630.30 SODA ASH 50 LB BG 16.50 37 C 58 ( 21 ( C 37 346.50 GELEX BENT EXTENDER 2 LB BG 11.90 44 C 100 C 31 c' 25 44 368.90 M-I BAR 100 LB BG 11.91 620 C 672 C 52 0 C 620 619.32 CITRIC ACID 50 LB BG 98.70 5( ( 5< c c 0 C 50 SPERSENE CF 50 LB BG 33.50 19 C 20 ~ 5 0 C 15 134.0(, 167.50 DEFOAM X 5 GA CN 88.17 74 C 77 ( 3 0 C 74 264.51 FLOVIS 25 LB BG 197.00 69 C 186 C 117 0 C 69 23049.00 HEC-I0 SO LB BG 195.00 0 ( 0 ( c.. 0 c 0 SAFECARB 250 SO LB BG 17.50 104 ( 183 C 46 C 33 104 805.00 SAFECARB 40 SO LB BG 17.50 290 C 1011 C 721 0 C 290 12617.50 SAFECARBI0 50 LB BG 17.50 165 (, 41~ ( 245 C C 165 4287.50 BORAX 50 LB BG 43.25 10 C lC C 0 ( ( 10 SODIUM BICARBONATE 50 LB BG 17.75 19 C 19 3 3 0 C 16 53.25 53.25 50 LB BG 156.70 61 C 107 C 46 0 C - 61 7208.20 POLYPAC UL CONQOR 404 55 GA OM 1152.10 12 C 13 ~ 1 0 C 12 1152.10 M-I SEAL FINE 40 LB BG 23.50 30 ( 97 ( 30 0 37 30 705.00 LUBETEX 55 GA OM 734.00 IS C 28 ( 12 0 1 15 8808.00 DUALFLO 50 LB BG 82.00 8 C 85 C 77 c' C 8 6314.00 POTASSIUM CHLORIDE (KCI 50 LB BG 12.58 392 C 896 C 504 0 C. 392 6340.32 GREENCIDE 55 GA OM 1641.20 1 C 4 C 3 0 C 1 4923.60 BIOBAN 1 LB 22.00 40 C 100 ( 60 0 ( 40 1320.00 VENfROL401 40 LB BG 44.60 40 ( 40 ( 0 C ( 40 DDCWT 55 GA OM 478.74 0 ( 8 C 2 C' 6 0 957.48 Safe-Scav NA 55 GA DM 377.33 0 ( 8 C 8 0 C 0 3018.64 ( WATER-BASEd ....UD REPORT No. 20 Date 2/15/2003 DepthlTVD 4350 ft I 4208 ft Spud Date 1/31/2003 Mud Type FLOPRO Water Depth Activity UD PIPE Field/Area: WILDCAT Description: SEC.29ff2NIR12W,SM Location: CLAM GULCH, ALASKA Well No,: abalone 1 r:z;, WFF Operator : MARATHON OIL COMPANY Report For: GENE ANDERSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: MIKE LESLIE DRILLING ASSEMBLY Bit Size 12.25 in STC FGXIVC Nozzles 3x18/12/ 1132" Drill Pipe Size Length 4in 3519ft Drill Pipe Size Length 5 in 725 ft Drill Collar Size Length 8 in 106 ft CASING Surface 20in ~17Oft (170TVD) Intennediate 13.375in ~2206ft (21 OOTVD) Intenneœate in (â),ft (TVD) Production or Liner MUD PROPERTIES Sample From PIT~18:00 PIT(á107:00 Flow Line Temp OF N/A N/A DepthfTVD ft 4350/4208 4350/4208 Mud Weight Ib/gal 9. 5 (â}84 of 9.5@}84°F FU1U1el Viscosity sIqt 54 55 Rheology Temp OF 120 120 R6001R300 54/38 56/39 R200/R 1 00 32/24 32/23 R6/R3 12/9 12/8 PV cP 16 17 yp Ib/100fP 22 22 lOs/10m/30m Gel Ib/100ft2 11/22/29 11/23136 API Fluid Loss cc/30 min 10 10 lITHP FL Temp cc/30 min Cake APIlHfHP 1/32" 31 31 Solids %Vol 5 Oil/W ater %Vol 1/94 Sand %Vol 0.5 0.5 tvIDT Iblbbl 12.5 pH 8.5 8.5 Alkal Mud (Pm) 0.1 PfIMf 0.05/0.5 Chlorides mg/l 28500 Hardness Ca mg/1 320 LSRV CPS 38600 Dissol Oxygn ppm 4 Conqor 404 ppm 1764 REMARKS AND TREATMENT Caliper pits during cement'g. Lose 0 bbl pump'g cmt, lose 72 bbl displ cmt w/mud. Dump mud in pits, cleaning pits. MUD VOLUME (bbl) Hole 608.1 Active Pits -.1 Total Circulating Vol 608 In Storage CIRCULATION DATA Pump Make OILWEli.1600PT OIL WELL 1600 PT Pump Size 5.5 X 8.in 5.5 X 8.in Pump Cap 2.32 gallstk 2.32 gallstk Pump stk/min 115(â}94% 115(â}94% Flow Rate 534 gaVmin Bottoms Up 44.4 min 10202 stk Total Circ Time 47.8 min 10999 stk. Circulating Pressure 1550 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 SOLIDS EQUIP Derrick Shaker Denick Shaker Cleaner 1 Centrifuge Size 200/200/200 230/230/230 Hr 12 12 o o MUD PROPERTY SPECS Weight 9.4-9.6 Viscosity 45-60 Filtrate 8-10 REMARKS Run 9 5/8" csg. PJSM. Cement csg. Install varibore pipe rams and riser. Test BOPE. RIH w/5H hwdp and POH liD. (907) 776-8680 TIME DlSTR Ri,g UplService Drillin,g Trippin~ Circulate Run CS2, cmt BOPNU BOP Testing (bbl) o o o 390 o o o o o o RIG PHONE SOLIDS ANALYSIS (%/lblbbl) NaCI .11.7 KCI 2.1119.2 Low Gravity 3.1128.5 Bentonite 1.2/ 11. Drill Solids 1.5/13.5 Weight Material NAI NA Chemical Cone - I 4. InuUReaá .9S83 Average SG 2.6 CarblBiCarb (m mole/L) 1.115.8 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.507/0.280 kplk.a (l~^nIl00ft2) 1.71716.085 Bit Loss (psi / %) 341 122 Bit HHP (hhpl HSI) 106/ .9 Bit Jet Vef (ftJs) 200 Ann. Vel DP (ftJrnin) 97.63 Ann. Vel DC (ftJrnin) 152.08 Crit Vel DP (ft/min) 330 Crit Vel DC (ftlmin) 367 ECD (a) 4350 (lb/gal) 9.69 DAilY COST CUMULATIVE COST last 24 Hrs MUD VOL ACCTG 5 Oil Added Water Added Mud Received 2 Shakers 5 Evaporation 2 Centrifuge 3.5 Formation Left in Hole Desilter Other M-I ENGR I PHONE BOB WILLIAMS (907) 240-4116 $ 625.00 $ 101,064.57 ( ( WELLSITE INVENTORY WFF DAIL Y REPORT Operator: MARATHON OIL COMPANY M-I Well No. : abalone1 Well Name: ABALONE #1 Report No. : 20 Location: CLAM GULCH, ALASKA Date : 2/15/2003 COST SUMMARY Net Daily Cost : 625.00 Sales Tax: 0.00 Total Daily Cost : 625.00 Cumulative Cost : 101064.57 INVENTORY Product Unit Begin Recvd Recvd Used Used Return Return Final Daily Name Unit Price Invent Today Total Today Total Today Total Invent cost Total Cost ENGINEER 1 625.00 0 1 20 1 2(: c' C c: 625.0C 12500.00 M-I GEL 100 LB BG 12.96 0 ~ '595 ~ 37C 0 225 0 4795.20 CAUSTIC SODA .50 LB BG 28.6.5 31 C .53 < 22 C C 31 630.30 SODA ASH .50 LB BG 16..50 37 C .58 C 21 0 C 37 346..50 GELEX BENT EXTENDER 2 LBBG 11.90 44 C 100 C 31 C 25 44 368.90 M-I BAR 100LBBG 11.91 620 C 672 C 52 0 C 62< 619.32 CITRIC ACID 50 LB BG 98.70 50 C 5C C C 0 ( 50 SPERSENE CF 50 LB BG 33..50 19 C 2(: C 1 0 c' 19 33.50 DEFOAM X 5 GA CN 88.17 74 C 77 r 3 C r 74 264.51 FWVIS 25 LB BG 197.00 69 c\ 186 ~ 117 0 C 69 23049.00 HEC-I0 .50 LB BG 195.00 0 ~ ~ C ~ 0 C ~ SAFECARB 250 50 LB BG 17..50 104 C 183 C 46 0 33 104 80.5.00 SAFECARB 40 .50 LB BG 17..50 290 C 1011 r 721 ( C 290 12617.50 SAFECARB 10 50 LB BG 17..50 16.5 C 41~ ~ 245 (J C' 165 4287.50 BORAX 50 LB BO 43.25 10 C lC C 0 0 C 10 SODIUM BICARBONATE 50 LB BG 17.75 19 C 19 C C 0 r 19 POLYPAC UL 50 LB BG 1.56.70 61 C 107 C 46 0 C 61 7208.20 CONQOR 404 55 GA DM 1152.10 12 C 13 C 1 C r 12 1152.10 M-I SEAL FINE 40 LB BG 23.50 3(, C. 97 ( 30 C 37 3C 705.00 LUBETEX 55 GA DM 734.00 15 C 28 C 12 (J 1 15 8808.00 DUALFLO 50 LB BG 82.00 8 C 85 C 77 0 r 8 6314.00 POTASSIUM CHLORIDE (KCI 50 LB BG 12.58 392 C 896 C 504 0 r 392 6340.32 GREENCIDE 55 GA DM 1641.20 1 C 4 ~ 3 ~ ~ 1 4923.60 BIOBAN 1 LB 22.00 4C C 100 C 60 (J c- 40 1320.00 VENTROL 401 40 LB BG 44.60 4C ( 4C C 0 0 C 40 DD CWT 55 GA DM 478.74 0 ( 8 C 2 C' 6 C 957.48 \ Safe-Scav NA 55 GA DM 377.33 0 C 8 C 8 ~ ( () 3018.64 WATER-BASE¿ .J.UD REPORT No. 19 Date 2/14/2003 DepthlTVD 4350 ft / 4208 ft Spud Date 1/31/2003 Mud Type FLOPRO Water Depth Activity RUN CASING Field/Area: WILDCAT Description: SEC.29ff2NIR12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 ( ~WFF Operator: MARA TIION OIL COMPANY Report For: GENE ANDERSON Well Name: ABALONE # I Contractor: INLET DRILLING Report For: MIKE LESLIE DRILLING ASSEMBLY Bit Size 12.25 in STC FGXIVC Nozzles 3x18 112 I 1/32" Drill Pipe Size Length 4 in 3519 ft Drill Pipe Size Length 5 in 725 ft Drill Collar Size Length 8 in 106 ft CASING Surface 20in ~ 170ft (170TVD) Intennediate 13.375in @J2206ft (2100TVD) Intennediate in @ft (TVD) Production or Liner MUD PROPERTIES Sample From PIT(â),21 :00 PIT~06:10 Flow Line Temp of N/A 92 DepthffVD ft 4350/4208 4350/4208 Mud Weight Ib/gal 9.5~82°F 9.5~85°F Funnel Viscosity s/qt 54 53 Rheology Temp of 120 120 R6001R300 54/40 56/41 R2001RI00 35/26 36/27 R61R3 14/11 14/12 PV cP 14 15 yp Ib/IOOft:2 26 26 1 Osll Om/30m Gel Ib/l00ft2 13/14/27 14/26/2 9 API Fluid Loss cc/30 min 7.6 7.4 lITHP FL Temp cc/30 min Cake API/HTHP 1/32" 21 21 Solids %Vol 5 5 Oil/W ater %Vol 1/94 1/94 Sand %Vol 0.5 0.5 MBT Iblbbl 10 10 pH 8.5 9.0 Alkal Mud (Pm) 0.05 0.1 Pf/Mf 0.0510.4 0.05/0.6 Chlorides mg/1 29000 29000 Hardness Ca mg/l 400 320 LSRV cps 42200 44600 Dissol Oxy~ ppm 1 Conqor 404 ppm 2352 REMARKS AND TREATMENT Add'g Greeneide, BioBan for beginn'g bacteria problem. Add Poly Pac UL to maintain fluid loss within specs. Add Safecarb to replace the material scraped off&om the wiper trip. Finish add'g drum ofConqor 404 just after midnight yesterday. Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Shakers Evaporation Centrifuge Fonnation Left in Hole Desilter Other M-I ENGR I PHONE TIME DlSTR Rig UplService Drilling Tripping Circulate Wireline Logs Reaming (bbl) o 29 o 20 o 4 10 o o o RIG PHONE BOB WILLIAMS (907) 240-4116 MUD VOLUME (bbl) Hole 608.1 Active Pits 389.9 Total Circulating Vol 998 In Storage CIRCULATION DATA Pump Make OIL WELL 1600PT OIL WELL 1600 PT Pwnp Size 5.5 X 8.in 5.5 X 8.in Pwnp Cap 2.32 gallstk 2.32 gallstk Pwnp stk/min 115~94% 115<'æ94% Flow Rate 534 gaJ/min Bottoms Up 44.4 min 10202 stk Total Circ Time 78.5 min 18054 stk Circulating Pressure 1550 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 CAUSTIC SODA 50 LB BG 4 M-I BAR 100 LB BG 30 SAFECARB 40 50 LB BG 10 POLYPAC UL 50 LB BG 10 GREENCIDE 55 GA DM 1 BlOB AN 1 LB 40 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 200/200/200 230/230/230 Hr 12 12 o 4 MUD PROPERTY SPECS Weight 9.4-9.6 Viscosity 45-60 Filtrate 8-10 REMARKS RID SWS, RIH. WashlReam 4272'-4310. RIH, 3' offill. Cire, cood mud Pump dry job, POH. liD BHA Install 9 5/8" csg rams, test. PJSM. Rig up and run 9 5/8" casing. SOLIDS ANALYSIS (%ßblbbl) NaCI .1/1. KCI 2.1119.2 Low Gravity 3.1128.2 Bentonite .91 8.2 Drill Solids 1.8/15.9 Weight Material NAI NA Chemical Cone - I 4. InertlReact 1.4166 Average SG 2.6 CarblBiCarb (m mole/L) 1./15.8 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS nplna Values 0.433/0.245 kplka (lb-s^nll00ft2) 2.86817,866 Bit Loss (psi I %) 341 122 Bit HHP (hhp I flS!) 106/.9 Bit Jet vet (ftls) 200 Arm. Vel DP (ftlmin) 97.63 Ann. Vel DC (ftlmin) 152.08 Crit Vel DP (ftlmin) 352 Crit Vel DC (ftlmin) 386 ECD ~ 4350 (lb/gal) 9.71 DAIL Y COST CUMULATIVE COST (907) 776-8680 $ 5,360.10 $ 100,439.57 ( r: ~ ~WFF WELLSITE INVENTORY DAIL Y REPORT Operator: MARATHON OIL COMPANY M-I Well No, : abalone1 Well Name: ABALONE #1 Report No. : 19 Location: CLAM GULCH, ALASKA Date : 2/14/2003 COST SUMMARY Net Daily Cost : 5360.10 Sales Tax : 0.00 Total Daily Cost: 5360.10 Cumulative Cost: 100439.57 INVENTORY Product Unit Begin Recvd Recvd Used Used Return Return Final Daily Name Unit Price Invent Today Total Today Total Today Total Invent Cost Total Cost ENGINEER 1 625.00 0 1 19 1 19 c' C 0 625.0e- 11875.00 M-I GEL 100 LB BG 12.96 C C 595 C 370 0 225 0 4795.20 CAUSTIC SODA 50 LB BG 28.65 35 C 53 22 (, ~ 31 114.6C 630.30 SODA ASH 50 LB BG 16.50 37 C 58 C 21 ~ ( 37 346.50 GELEX BENT EXTENDER 2LBBG 11.90 44 C 100 C 31 C 25 44 368.90 M-I BAR 100 LB BG 11.91 650 C 672 3C 52 ( e- 620 357.3C 619.32 CITRIC ACID 50 LB BG 98.70 50 C 5< C ~ c' C 5C \ SPERSENE CF 50 LB BG 33.50 19 ( 2C ( 1 0 C 19 33.50 DEFOAM X 5 GA CN 88.17 74 c' 77 C 3 0 c' 74 264.51 FWVIS 25 LB BG 197.00 69 C. 186 e- 117 c C 69 23049.00 HEC-I0 50 LB BG 195.00 0 C 0 ( ~ C C 0 SAFECARB 250 50 LB BG 17.50 104 C 183 ( 46 0 33 104 805.00 SAFECARB 40 50 LB BG 17.50 300 C 1011 lC 721 0 é 29(; 175.0C 12617.50 SAFECARBI0 50 LB BG 17.50 165 ( 41C' ( 245 C' C 165 4287.50 BORAX 50 LB BG 43.25 lC: C 10 ( (, c ( 10 SODIUM BICARBONATE 50 LB BG 17.75 19 C 19 C () 0 ~ 19 POL YPAC UL 50 LB BG 156.70 71 C 107 Ie' 46 (, C 61 1567.0C 7208.20 CONQ9R 404 55 GA DM 1152.10 12 C 13 f 1 0 C 12 1152.10 M-I SEAL FINE 40 LB BG 23.50 30 C 97 c' 3( e- 37 3( 705.00 LUBETEX 55 GADM 734.00 15 ( 28 C 12 ~ 1 15 8808.00 DUALFLO 50 LB BG 82.00 8 ( 85 C 77 0 C 8 6314.00 POT ASSRJM CHLORIDE (KCI 50 LB BG 12.58 392 ( 896 C 504 e- C 392 6340.32 GREENCIDE 55 GADM 1641.20 2 ( 4 I 3 0 C 1 1641.2( 4923.60 BIOBAN 1 LB 22.00 80 C 100 4C 60 0 C 4C 880.0C 1320.00 VENTROL 401 40 LB BG 44.60 40 C 40 C 0 0 C 4C DDCWT 55 GA DM 478.74 0 ( 8 ( 2 0 6 C' 957.48 Safe-Scav N A 55 GA DM 377.33 0 ( 8 C 8 c! c' < 3018.64 .{ WATER-BASEJ ..UD REPORT No. 18 Date 2/13/2003 Depth/TVD 4350 ft / 4208 ft Spud Date 1/31/2003 Mud Type FLOPRO Water Depth Activity LOGGING Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No,: abalone 1 ~WFF Operator: MARATIION OIL COMPANY Report For: GENE ANDERSON Well Name: ABALONE # 1 Contractor: JNLET DRILLING Report For: MIKE LESLIE DRILLING ASSEMBLY Bit Size 12.25 in STC FGXIVC Nozzles 3x18/121 1/32" Drill Pipe Size Length 4 in 3519 ft Drill Pipe Size Length 5 in 725 ft Drill Collar Size Length 8 in 106 ft CASING Surface 20in ~ 170ft (170TVD) Intennediate 13.375in ~2206ft (2100TVD) Intennediate in (âJft (TVD) Production or Liner MUD PROPERTIES Sample From PIT(ã»)3:30 PIT(â}IO:00 Flow Line Temp of N/A 98 DepthffVD. ft 4350/4208 4350/4208 Mud Weight I bl gal 9.45 (â}86°F 9.6(â}90°F Fwmel Viscosity sIQt 48 51 Rheology Temp of 120 120 R600/R300 48/37 53/40 R200/R100 32/26 36/28 R6/R3 14/12 14/12 PV cP 11 13 yp Ib/l00ft2 26 27 lOs/10m/30m Gel Ib/lOOft2 14/23/26 15/25/28 API Fluid Loss cc/30 min 8.8 7.8 HTHP FL Temp cc130 min Cake APIIHTHP 1/32" 21 21 Solids %Vol 4 5 OillWater %Vo1 1/95 1/94 Sand %Vo1 0.25 0.25 MBT lblbbl 7.5 10 pH 8.5 8.5 Alkal Mud (pm) 0.1 0.2 PfIMf 0.05/0.6 0.0510.6 Chlorides mg/1 28000 29000 Hardness Ca mg/l 400 400 LSRV cps 42400 43600 Dissol Oxy~ ppm 1 1 Conqor 404 ppm 2548 2548 MUD VOLUME (bbl) Hole 608.1 Active Pits 389.9 Total Circulating Vol 998 In Storage CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT PumP Size 5.5 X 8.in 5.5 X 8.in Pump Cap 2.32 gaJ/stk 2.32 gal/stk Pump stklmin 115(â}94% 115@94% Flow Rate 534 gaUmin Bottoms Up 44.4 rnin 10202 stk Total Circ Time 78.5 min 18054 stk Circulating Pressure 1550 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 CAUSTIC SODA 50 LB BG 1 SODA ASH 50 LB BG 8 POLYPACUL 50 LB BG 8 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centri~e Size 200/200/200 230/230/230 Hr 12 12 o o MUD PROPERTY SPECS Weight 9.4-9.6 Viscosity 45-60 Filtrate 8-10 REMARKS AND TREATMENT REMARKS Centr Van down. Mud weight rising to 9.6 ppg while backream'g. wash/ream to Dir drlg 4343'-4350'. Circulate hole clean, backrearn 4221'-2848'. POH to shoe. Serv btrn. POH- no problems. Repair Centr Van, process mud in pits rig. RIH-tite 4040'-4273'. Tag fiU4339'. WashlReam to 4350'. Cire. POH SLM. During logging. Reduce wt to 9.45 ppg. E-Log. TIME DlSTR Rig Up/Service Drilling Tripping Circulate Wireline Logs Reaming last 24 Hrs 1 .5 7.5 3 8.5 3.5 (bbl) o 50 o o 12 o o o 60 15 RIG PHONE MUD VOL ACCTG Oil Added Water Added Mud Received Centrifuge Fonnation Left in Hole Desilter Other Dumped Shakers M-IENGR/PHONE BOB WILLIAMS (907) 240-4116 $OLlDS ANALYSIS (%IIblbbl) NaCI .I .4 KCI 2.1/19.3 Low Gravity 2.8/25.3 Bentonite .6/5.8 Drill Solids 1.7115.5 Wei~t Material NAI NA Chenúcal Cone - I 4. lnertlReact 1.8398 Average SO 2.6 CarblBiCarb (m molelL) 1./ 15.8 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.376/0.220 kplka (Ib·s^nll00ft2) 3.796/8.936 Bit Loss (psi 1 %) 339/21.9 Bit HHP (bhpl HSI) 1061 .9 Bit Jet Vel (ftls) 200 Ann. Vel DP (ftlmin) 97.63 Ann. Vel OC (ft/min) 152.08 Cnt Vel DP (ftlmin) 357 Crit Vel OC (ftlmjn) 388 ECD (â) 4350 (Ib/gal) 9.67 DAILY COST CUMULATIVE COST (907) 776-8680 $ 2,039.25 $ 95,079.47 aI' , t WELLSITE INVENTORY ·-~WFF DAILY REPORT Operator: MARATHON OIL COMPANY Well Name: ABALONE #1 Location: CLAM GULCH, ALASKA M-I Well No. : abalone1 Report No. : 18 Date: 2/1312003 COST SUMMARY Net Daily Cost : 2039.25 Sales Tax : 0.00 Total Daily Cost : 2039.25 Cumulative Cost : 95079.47 INVENTORY Product Unit Begin Recvd Recvd Used Used Return Return Final Daily Name Unit Price Invent Today Total Today Total Today Total Invent Cost Total Cost ENGINEER 1 625.00 ~ 1 18 1 18 ~ r 0 625.0< 11250.00 M-I GEL 100LBBG 12.96 ~ ( 59S C 37( 225 0 4795.20 CAUSTIC SODA 50 LB BG 28.65 36 r 53 1 18 ~ C 35 28.65 515.70 SODA ASH 50 LB BG 16.50 45 C 58 8 21 0 e 37 132.0C 346.50 GELEX BENT EXTENDER 2LBBG 11.90 44 C 10C, C 31 r 25 44 368.90 M·I BAR 100LBBG 11.91 65C C 672 C 22 < C 65e 262.02 ClTRlC ACID 50 LB BG 98.70 50 C 5C: C e (, c SO SPERSENE CF 50 LB BG 33.50 19 ~ 2~ r 1 c: ( 19 33.50 DEFOAM X 5 GA CN 88.17 7~ C 77 C 3 ~ C. 74 264.51 FLOVIS 25 LB BG 197.00 69 C 186 (, 117 (, 69 23049.00 HEC·I0 50 LB BG 195.00 0 C c- C ~ (, (, ~ SAFECARB 250 50 LB BO 17.50 104 ( 183 ( 46 0 33 104 805.00 SAFECARB 40 50 LB BO 17.50 30e C 1011 ~ 711 < (, 30(1 12442.50 SAFECARBI0 50 LB BG 17.50 165 C 41< C 245 0 ( 165 4287.50 BORAX 50 LB BG 43.25 10 e 10 C (, < r 1(, SODIUM BICARBONATE 50 LB BG 17.75 19 C, 19 ( c: 0 ~ 19 POLYPAC UL 50 LB BG 156.70 79 C 107 8 36 0 ( 71 1253.6C 5641.20 CONQOR 404 55 GA DM 1152.10 12 e 13 e 1 0 C 12 1152.10 M·I SEAL FINE 40 LB BG 23.50 30 ( 97 C 3< r 37 3(\ 705.00 LUBETEX 55 GA DM 734.00 15 ( 28 ( 12 C 1 15 8808.00 DUALFLO 50 LB BG 82.00 8 C 85 C 77 0 ( 8 6314.00 POT ASSlUM CHLORIDE (KCl 50 LB BG 12.58 392 C 896 C 504 0 r 392 6340.32 GREENClDE 55 GA DM 1641.20 2 C 4 C 2 ( C 2 3282.40 BIOBAN 1 LB 22.00 80 C 10C C 2(, C C 8C 440.00 VENTROL 401 40 LB BG 44.60 4( C 4( C c.. r r 4C' DDCWT 55 GA DM 478.74 0 C 8 C 2 (\ 6 c: 957.48 Safe--ScavNA 5S GA DM 377.33 C C 8 C 8 ( C c: 3018.64 I~ \ WATER-BASEd .".UD REPORT No. 14 Date 2/9/2003 DepthlTVD 2764 ft /2614 ft Spud Date 1/31/2003 Mud Type FLOPRO Water Depth Activity DRilLING Field/Area: WILDCAT Description: SEC.29fT2N/R12W,SM location: CLAM GULCH, ALASKA Well No,: abalone 1 ~WFF Operator: MARATHON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: INLET DRILLING Report For: GEORGE BREWS1ER DRilLING ASSEMBLY Bit Size 12.25 in STC FGXFVC Nozzles 3x18 112 I 1/32" Drill Pipe Size Length 4 in 1881 ft Drill Pipe Size Length 5 in 783 ft Drill Collar Size Length 8 in 100 ft CASING Surface 20in @17Oft (170TVD) Intermediate 13.375in@2206ft(2100TVD) Intermediate in (âJJ\ (TVD) Production or Liner MUD PROPERTIES Sample From PIT(â)2345 PIT~1200 Flow Line Temp of 80 64 Depth/TVD ft 2764/2614 2230/2117 Mud Weight lblgal 9.2~62°F 9.05~64°F Funnel Viscosity s/qt 80 70 Rheology Temp of 120 120 R600/R300 54/43 53/44 R200/RI00 37/31 38/32 R6/R3 19/17 20/18 PV cP 11 9 yp Ib/1 00ft2 32 35 1 Os/1 Om/30m Gel Ib/100ft2 18/24/27 18/24/28 API Fluid Loss cc/30 min 6.8 6.6 HIHP FL Temp cc/30 min Cake API/f-ITHP 1/32" 1/ 1/ Solids %Vol 3.5 3 Oil/W ater %Vol 0/96.5 0/97 Sand %Vol 0.25 1R :MET lblbbl 2 0 pH 9.5 9.5 Alkal Mud (Pm) 1.45 1.4 PfJMf 0.4/1.3 0.4/1.25 CIùorides mg/l 28500 28500 Hardness Ca mg/I 100 52 LSRV cps 74600 73800 Dissol Oxygn ppm 5 4 REMARKS AND TREATMENT Displaced old system following FIT; circulated while building additional volume MUD VOLUME (bbl) Hole 384.5 Active Pits 480.5 Total Circulating Vol 865 In Storage CIRCULATION DATA Pump Make OIL WELL 1600PT OIL WELL 1600 PT Pump Size 5.5 X 8.m 5.5 X 8.m Pump Cap 2.32 gallstk 2.32 gallstk Pump stk/min 11O~94% 110~94% Flow Rate 510 gallmin Bottoms Up 29.4 min 6471 stk Total Circ Time 71.2 min 15672 stk Circulating Pressure 1200 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 CAUSTIC SODA 50 LB BG 2 SODA ASH 50 LB BG 3 SPERSENE CF 50 LB BG 1 FLOVIS 25 LB BG 31 SAFECARB 40 50 LB BG 79 SAFECARB 10 50 LB BG 71 POTASSIUM CHLORID 50 LB BG 152 SOLIDS EQUIP Derrick Shaker Denick Shaker Cleaner 1 Centrifuge Size 175/210/210 175/175/175 Hr 24 24 o o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-12 REMARKS Slipped/cut drilling line; circulated/conditioned old system; R/U, tested casing to 1500 psi fì30 minutes; clnd. out 13-3/8" csg. w/top ofFC @2163', shoe @2206'; drld. @2209'-C.B.U.; FIT t/l1.0 ppg; clnd. pill pit; displaced t/9.0 ppg FloPro w/l0 bbl water spacer, old system to tiger tank for disposal; eirc. -build additional volume; drld. @2209-2230'; eirc.-LOT t/14.5 ppg EMW; repairs; drld. @2230-2764' @midnight Continued batch mixing in pill pit to build volume all day; mud weight to 9.2+ ppgat one time--M-I solids van on location to help control mud weight and solids--rigged up @2300 hrs. TIME DISTR Last 24 Hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS (%/Ib/bbl) MUD RHEOLOGY & HYDRAULICS Rig UplService Oil Added 0 NaCI ./. nplna Values 0.329/0.171 Drilling 14 Water Added 440 KCI 2.21 20.1 kplka (lb·s^nl1 00ft2) 5.910/13.716 Tripping Mud Received 0 Low Gravity 4.31 39.2 Bit Loss (psi I %) 301 125.1 L.O.T. 1 Centrifuge 0 Bentonite -.21 -2.1 Bit HHP (hh~ I HSI) 89 1.8 F.I.T. 1 F offi1ation 0 Drill Solids 4.1137.4 Bit Jet Vel ( Is) 191 CSG. TEST 1 Left in Hole 0 Weight Material NAI NA Ann. Vel DP (ftlmin) 99.95 DRLG LINE 0.5 Desilter 0 Chemical Conc - I 4. Ann. Vel DC (ftlmin) 145.24 CIRC./COND. 6 Other 0 Inert/React 16.6005 Crit Vel DP (ftlmin) 413 REPAIRS 0.5 Dumped 400 Average SG 2.6 Crit Vel DC (ftlmin) 434 Shakers 70 Carb/BiCarb (m mole/L) 8./12.6 ECD ~ 2764 (lb/gal) 9.5 M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAll Y COST CUMULATIVE COST FAULKNER, F. (907) 242-6994 (907) 776-8680 $ 11,409.46 $ 58,679.39 ,{ ~ WATER-BASEL .~UD REPORT No. 13 Date 2/8/2003 DepthlTVD 2210 ft /2100 ft Spud Date 1/31/2003 Mud Type FLOPRO Water Depth Activity RIH Field/Area: WILDCAT Description: SEC.29fT2N/R12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 ~WFF Operator: MARATIION OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: INLET DRILUNG Report For: GEORGE BREWSTER DRilLING ASSEMBLY Bit Size 12.25 in STC FGXFVC Nozzles 3x18 112 I 1/32" Drill Pipe Size Length 4 in 1327 ft Drill Pipe Size Length 5 in 783 ft Drill Collar Size Length 8 in 100 ft CASING Surface 20in (â}170ft (170TVD) Intennediate 13.375in @2206ft (2100TVD) Intennediate in (åJ,ft (TVD) Production or Liner MUD PROPERTIES Sample From PIT@)300 PIT~1100 Flow Line Temp of N/A N/A DepthffVD ft 2210/2100 2210/2100 Mud Weight 1 bl gal 9.05~55°F 9.0~50°F FUlmel Viscosity s/Qt 78 77 Rheology Temp of 120 120 R600/R300 55/46 48/39 R200/RIOO 41/35 36130 R6/R3 23/21 19/17 PV cP 9 9 yp lb/100ft2 37 30 lOs/1Om/30m Gel lb/100ft2 22/29/31 18/28/33 API Fluid Loss cc/30 min 6.2 6.4 HTf-IP FL Temp cc130 min Cake APJIHTHP 1/32" 1/ 1/ Solids %Vol 3 3 Oil/W ater %Vol 0/97 0/97 Sand %Vol 0 0 :MBT lblbbl 0 0 pH 9.5 9.5 Alkal Mud (Pm) 1.3 1.4 Pf/Mf 0.35/1.15 0.411.2 Chlorides mg/l 31000 28000 Hardness Ca mg/l 40 20 LSRV cps 72000 68000 Dissol Oxygn ppm 4 4 REMARKS AND TREATMENT Built @500 bbls FloPro for drillout; transferred mud :lÌ"om tiger tank to pill pit to drill cement Solids van on location and rigged up (bbl) o o o o o o o o 74 o RIG PHONE TIME DISTR Last 24 Hrs MUD VOL ACCTG Rig Up/Service 2.5 Oil Added Drilling Water Added Tripping 6 Mud Received BOP Testing 4.5 Centrifuge BOP NO 3.5 Fonnation BHA 2.5 Left in Hole HANGER 1.5 Desilter BALES 1 Other STD PIPE 1.5 Dumped DRLG LINE 1 Shakers M~I ENGR I PHONE FAULKNER, F. (907) 242-6994 MUD VOLUME (bbl) Hole 306.6 Active Pits 565.4 Total Circulating Vol 872 In Storage CIRCULATION DATA Pump Make OIL WELL 1600PT OIL WELL 1600 PT Pump Size 5.5 X 8.in 5.5 X 8.in PumpC~ g~~ g~~ Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 SODA ASH 50 LB BG 1 FLOVIS 25 LB BG 18 SAFECARB 40 50 LB BG 72 SAFECARB 10 50 LB BG 18 CONQOR 404 55 GA DM 1 DUALFLO 50 LB BG 8 POTASSIUM CHLORID 50 LB BG 168 GREENCIDE 55 GA DM 1 gal/min SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 210/210/210 175/175/175 Hr o o o o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-12 REMARKS Completed mixing new FloPro system for displacement; transferred mud ftom tiger tank. for cement drilling; N/U BOPE-tested; made up, oriented BHA-RIH w/HWDP; P/U and rabbit drill pipe; RIH @2065'; slip/cut drilling line SOLIDS ANALYSIS (%/lb/bbl) NaCI .111.3 KCI 2.2/20.5 Low Gravity 2.6/23.6 Bentonite .I . Drill Solids 2.41 22.1 Weight Material NAI NA Chemical Cone - I 4. Inert/React Average SG 2.6 Carb/BiCarb (m mole/L) 7.111. WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.258/0.146 kp/ka (lbos^n/lOOft2) 9.833/17.668 Bit Loss (psi I %) / 1 Bit HHP (hhp I HSI) I 1 Bit Jet Vel (fils) Ann. Vel DP (ftlmin) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) Crit Vel DC (ftlmin) ECD @ 2210 (lb/gal) DAilY COST 466 466 9.05 CUMULATIVE COST (907) 776-8680 $ 11,325.24 $ 47,269.93 r:%;¡1WFF ( Operator: MARATHON OIL COMPANY Report For: ROWIAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: GEORGE BREWSTER DRILLING ASSEMBLY Bit Size in Nozzles 1/32" Drill Pipe Size 4in Drill Pipe Size 5in Drill Collar Size 8in Length ft Length ft Length ft CASING Smface 20in (ã}170ft (170TVD) Intennediate 13.375in (ã}2206ft (2100TVD) Intennediate Production or Liner MUD PROPERTIES Sample From PIT~0245 FlowLine Temp of N/A DepthlTVD ft 2210/2100 Mud Weight lblgal 9.0~50°F Funnel Viscosity s/qt Rheology Temp OF 120 R600/R300 48/39 R200/RI00 36/30 R61R3 19/17 PV cP 9 yp Ib/l00fF 30 1 Os/1Om/30m Gel Ib/l00ft2 18/28/33 API Fluid Loss cc/30 min 6.4 HIHP FL Temp cc/30 min Cake APIIHTHP 1/32" 11 Solids %Vol 3 Oil/W ater %Vol 0/97 Sand %Vol 0 IvIBT lblbbl 0 pH 9.5 Alkal Mud (pm) Pf/Mf 0.4/1.2 Chlorides mg/1 28000 Hardness Ca mg/l 20 LSRV cps 33000 Dissol Oxygn ppm 4 REMARKS AND TREATMENT Contaminated active system with calcium chloride brine/water--sent for injection during pit cleaning; repaired leaking valves, etc. Mixing new FloPro system for next interval per program @report time NOTE: Check is run on 2/8/03 TIME DISTR Rig Up/Service Drilling Tripping Rig Repair BOPNU Cementing (bbl) o 260 o o o o o o 325 o RiG PHONE Last 24 Hrs MUD VOL ACCTG Oil Added Water Added 0.5 Mud Received 1.5 Centrifuge 21 Formation 1 Left in Hole Desilter Other Dumped Shakers M·I ENGR I PHONE FAULKNER, F. (907) 242-6994 .,1' WA TER-BASE~ JIUD REPORT No. Date 217/2003 DepthlTVD Spud Date 1/31/2003 Mud Type Water Depth Activity Field/Area: WILOCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No.: abalone 1 12 2210 ft /2100 ft FLOPRO MIXING FLOPF~O MUD VOLUME (bbl) Hole 664.8 Active Pits 259.2 Total Circulating Vol 259.2 In Storage CIRCULATION DATA Pump Make OIL WELL 1600PT OIL WELL 1600 PT Pump Size 5.5 X 8.in 5.5 X 8.in Pump Cap gallstk gaVstk Pump stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 CAUSTIC SODA 50 LB BG 1 SODA ASH 50 LB BG 2 FLOVIS 25 LB BG 25 SAFECARB 40 50 LB BG 108 SAFECARB 10 50 LB BG 12 DUALFLO 50 LB BG 13 gallrnin SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 210/210/210 175/175/175 Hr 6 6 o o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-10 REMARKS Repaired pill pit valve; ßÚxed calcium chloride brine fi'cementers; top job-flush stack; pull, UD 1-1/4" pipe; rig down tools; NID diverter line, stack; rough cut csg.; set out stack; cut surface pipe flange; cut casing; N/U BOPE; em. pits-repair valves; mix FloPro per specs for drilling; chg. brakes on drawworks SOLIDS ANALYSIS (%/lb/bbl) NaCI .I -.1 KCI 2.2/20.1 Low Gravity 2.81 25.6 Bentonite .I . Drill Solids 2.7/24.3 Weight Material NAI NA Chemical Cone - I 4. Inert/React Average SG 2.6 Carb/BiCarb (m mole/L) 8./ 12.6 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values kp/ka (lb·s^n/lOOft2) Bit Loss (psi I %) Bit HHP (hhp 1 HSI) Bit Jet Vel (ftls) Ann. Vel DP (ftlmin) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) Crit Vel DC (ft/min) DAilY COST CUMULATBVE COST (907) 776-8680 $ 8,777.65 $ 35,944.69 " , WFF Operator: MARA mON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: INLET DRILLING Report For: GEORGE BREWSTER DRilLING ASSEMBLY Bit Size in Nozzles 1/32" Drill Pipe Size 4in Drill Pipe Size 5in Drill Collar Size 8in Length 2210 ft Length ft Length ft CASING Surface 20in @170ft (l70TVD) Intennediate 13.375in @2210ft (2100TVD) Intennediate Production or Liner MUD PROPERTIES Sample From PIT@)300 PIT@1600 Flow Line Temp of NIA N/A DepthffVD ft 2210/2100 2210/2100 Mud Weight lblgal 9.0@80°F 9.4@80°F Funnel Viscosity s/qt 54 62 Rheology Temp of 120 120 R6001R300 38/29 42/35 R2001R1OO 24/14 30/21 R61R3 413 4/3 PV cP 9 7 yp lb/l 00ft2 20 28 1 Os/l Om/30m Gel Ib/lOOft2 316/14 3/8/9 API Fluid Loss cc/30 min 12.4 11 HTHP FL Temp cc/30 min Cake APIIHTHP 1/32" 21 21 Solids %Vol 4.5 6 Oil/W ater %Vol 0/95.5 0/94 Sand %Vol 1R 0.25 IvIBT lblbbl 16 18 pH 8.8 9.0 Alkal Mud (pm) PfIMf TRIO. 65 TRIO. 9 Chlorides mg/l 3800 300 Hardness Ca mg/1 200 80 LSRV cps Dissol Oxygn ppm REMARKS AND TREATMENT Valve leak. in pill pit-lost calcium chloride brine into active system Transferred excess volume to tiger tank--hauling to injection TIME DISTR Rig Up/Service DrillitlR Tripping Rig Repair ConditIon Hole Cementing Wait 011 Cement (bbl) o o o o o o o o 138 o RIG PHONE Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Centrifuge Fonnation Left in Hole Desilter Other Dumped Shakers M· ENGR I PHONE 7 1 1 8 7 FAULKNER, F. (907) 242-6994 WATER-BASEl JUD REPORT No_ Date 2/6/2003 DepthlTVD Spud Date 1/31/2003 Mud Type Water Depth Activity Field/Area: WILDCAT Description: SEC.29rr2NIR12W,SM location: CLAM GULCH, ALASKA Well No,: abalone 1 11 2210 ft / 2100 ft GEUGELEX TOP JOB MUD VOLUME (bbl) Hole 653.7 Acti ve Pits 325.3 Total Circulating Vol 979 In Storage CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT Pump Size 5.5 X 8.in 5.5 X 8.in Pump Cap gallstk ~a1Jstk Pump stklmin Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 gal/min SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1· Centrifuge Size 210/210/210 175/175/175 Hr 24 24 o o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-12 REMARKS Rig down csg.; transferring mud to tiger tank for storage; cleaning pits; RIH-tag up w/seal; M/U cmtg. head; pumped spacer-pumped cement; lost returns--none to surface; disp, wlrig pumps; RID cmtg. head; POOH w/DP; WOC; worked on pit clng.; remove spider--ron 1-1/4" pipe t/350' outside 13-3/8" csg.; prep. t7top job; valve failed--pumped calcium cWoride brine into active; repair valve SOLIDS ANALYSIS (%/lb/bbl) NaCl .2/2.1 KCl .I . Low Gravity 4.7/43.2 Bentonite 1.4/12.7 Drill Solids 3.2/29.5 Weight Material NAI NA Chemical Cone - I 1. Inert/React 1.637 Average SO 2.6 Carb/BiCarb (m mole/L) ./-.1 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.39010.439 kplka (lb-s^nll00:ft2) 2.719/1.563 Bit Loss (psi I %) I 1 Bit HHP (hhpl HSI) I 1 Bit Jet vet (ftls) Ann. Vel DP (ft/min) Ann. Vel DC (ftlmin) Crit Vel DP (ftlmin) Crit Vel DC (ftlmin) ECD (c4 2210 (lb/gal) DAILY COST 183 187 9 CUMUlA. TIVE COST (907) 776-8680 $ 625.00 $ 27,167.04 ( WATER-BASE~ .JUD REPORT No. 10 Date 2/5/2003 DepthlTVD 2210 ft /2100 ft Spud Date 1/31/2003 Mud Type GEUGElEX Water Depth Activity LAND eSG, Field/Area: WILDCAT Description: SEC.29rr2N/R.l2W,SM location: CLAM GULCH, ALASKA Well No.: abalone 1 CASING Surface 20in @170ft (l70TVD) Intermediate 13.375in @221Oft (2100TVD) Intermediate MUD VOLUME (bbl) Hole 664.8 Active Pits 452.2 Total Circulating Vol 452.2 In Storage ~WFF Operator: MARATHON Oll.- COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRJLLING Report For: GEORGE BREWSTER DRilLING ASSEMBLY Bit Size in STC-MSDGHQC Nozzles 3x18/161 1/32" Drill Pipe Size Length 4in ft Drill Pipe Size Length 5in ft Drill Collar Size Length 8in ft Production or Liner MUD PROPERTIES Sample From PIT(ã),2300 PIT~1300 Flow Line Temp of N/A N/A DepthlTVD ft 2210/2100 2110/2100 Mud Weight lblgal 9.3~85°F 9.2~86°F FUlll1el Viscosity s/qt 62 63 Rheology Temp of 120 120 R600/R300 49/34 50/36 R200/R100 26/21 28/22 R6/R3 6/4 6/4 PV cP 15 14 yp IbllOOfP 19 22 1 Osll Om/30m Gel Ib/100fF 6114/18 6/16/20 API Fluid Loss cc/30 min 10.2 10 HTIIP FL Temp cc/30 min Cake APIIIITHP 1/32" 2/ 2/ Solids %Vol 6 5.5 Oil/W ater %Vol 0/94 0/94.5 Sand %Vol 0.75 0.75 MET lblbbl 23 23 pH 8.5 9.0 Alkal Mud (pm) 1.0 1.2 Pf/Mf TRIO. 9 TRIO. 9 Chlorides mgl1 300 300 Hardness Ca mg/l 40 40 LSRV cps Dissol Oxygn ppm REMARKS AND TREATMENT Mixed/spotted LCM pill (22.5 ppb Gel; 20 ppb SafeCarb 10; 30 ppb SafeCarb 40; 10 ppb SafeCarb 250) @1660' CIRCULATION DATA Pump Make OILWELL 1600PT Oll..WELL 1600 PT Pump Size 5.5 X 8.m 5.5 X 8.in Pump Cap gaVstk gaVstk Pwnp stk/min Flow Rate Bottoms Up Total Circ Time Circulating Pressure PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 M-I GEL 100 LB BG 26 SAFECARB 250 50 LB BG 16 SAFECARB 40 50 LB BG 40 SAFECARB 10 50 LB BG 28 M-I SEAL FINE 40 LB BG 30 gaUmin SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 210/210/210 175/175/175 Hr 24 24 o o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-12 REMARKS Mixed LCM pill #3 @1816'-spot; pull tJ1680'; ßÚx LCM pill #4-spot; observe well-losses continue; ßÚx LCM pill @5-spot; observe well; losses slowed to @2 bph; POOH slow rate; UD BHA; cleared floor of tools; removed elevator, bails; rigged up-ran casing string; broke circulation @1110'; RIH--Iand casing @midnight Mixed/spotted LCM pill (30 ppb M-I Seal F in 40 bbls whole mud) @1660' TIME DISTR Last 24 Hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS (%/lb/bbl) MUD RHEOLOGY & HYDRAULICS Rig Up/Service Oil Added 0 NaCI ./.2 np/na Values Drilling Water Added 0 KCI ./. kp/ka (lbos^n/100ftZ) Tripping 2 Mud Received 0 Low Gravity 7.2/65.9 Bit Loss (psi / %) BHA 1 Centrifuge 0 Bentonite 2.117.8 Bit HHP (hhp I HSI) Monitor/Pills 6 Fonnation 44 Dril1 Solids 5.2/47.1 Bit Jet Vel (fils) Running Casing 15 Left in Hole 0 Weight Material NAI NA Ann. Vel DP (ftlmin) Desilter 0 Chemical Cone - 1 1. Ann. Vel DC (ftlmin) Other 0 Inert/React 1.8212 Crit Vel DP (ftlmin) Dumped 0 Average SG 2.6 Crit Vel DC (ftlmin) Shakers 0 CarblBiCarb (m mole/L) ./-.1 M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAIL V COST CUMULATIVE COST FAULKNER, F. (907) 242-6994 (907) 776-8680 $ 3,136.96 $ 26,542.04 f r:-J WFF Operator: MARAlliON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: GEORGE BREWSTER DRilLING ASSEMBLY Bit Size 17.5 in STC-MSDGHQC Nozzles 3x18 /161 1/32" Drill Pipe Size Length 4 in 1326 ft Drill Pipe Size Length 5 in 752 ft Drill Collar Size Length 8 in 132 ft CASING Surface 20in @170ft (170TVD) Intennediate 13.375in @2210ft (2100TVD) Intennediate Production or Liner MUD PROPERTIES Sample From PIT@.2350 PIT~1300 Flow Line Temp of 97 96 DepthlTVD ft 2210/2100 2210/2100 Mud Weight lblgal 9 .2~90°F 9.35~90°F Funnel Viscosity s/qt 60 62 Rheology Temp of 120 120 R6001R300 52/37 53/35 R2001R100 27/20 28/22 R61R3 8/7 816 PV cP 15 18 yp lbll 00ft2 22 17 1 Osll Om/30m Gel lb/lOOft2 8/18/22 8/20/26 API Fluid Loss cc/30 min 10 10.2 HTHP FL Temp cc/30 min Cake API!lfŒIP 1/32" 2/ 2/ Solids %Vol 5.5 6 OillW ater %Vol 0/94.5 0/94 Sand %Vol 0.5 0.75 MBT lblbbl 22 22 pH 9.0 9.0 Alkal Mud (Pm) 0.1 0.1 PflMf mO.8 0.02/0.8 Chlorides mg/l 300 300 Hardness Ca mgll 40 40 LSRV cps Dissol Oxygn ppm 7 7 REMARKS AND TREATMENT Mixed/spotted 3 LCM pills on trip out (22.5 ppb Gel; 10 ppb SafeCarb 10; 30 ppb SafeCarb 40) Losses on wiper trip--mixedJspotted LCM pills on trip out (22.5 ppb Gel; 15 ppb SafeCarb 10; 20 ppb SafeCarb 40; 10 ppb SafeCarb 250) TIME DISTR Rig Up/Service Drilling Tripping Circulate Monitor/Pills Repairs (bbl) o 537 o o 80 o o 239 o 32 RIG PHONE MUD VOL ACCTG Oil Added Water Added Mud Received Dumped Shakers Evaporation Centriftlge Fonnation Left in Hole Desilter M..I ENGR I PHONE Last 24 Hrs 0.5 6.5 5 8.5 3 0.5 FAULKNER, F. (907) 242-6994 WATER-BASEl.JIUD REPORT No. 9 Date 2/4/2003 DepthlTVD 2210 ft /2100 ft Spud Date 1/31/2003 Mud Type GEUGELEX Water Depth Activity LOST CIRC, Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM location: CLAM GULCH, ALASKA Well No,: abalone 1 MUD VOLUME (bbl) Hole 639.2 Active Pits 511.8 Total Circulating Vol 1151 In Storage CIRCULATION DATA Pump Make OIL WELL 1600PT OIL WELL 1600 PT Pump Size 5.5 X 8.in 5.5 X 8.in Pump Cap 2.32 gallstk 2.32 ~aVstk Pump stklmin 110~94% 1l0(áJ94% Flow Rate 510 gallmin Bottoms Up 50.9 min 11192 stk Total Circ Time 94.8 min 20853 stk Circulating Pressure 1200 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 M-IGEL 100LBBG 101 GELEX BENT EXTEN~ 2 LB BG 7 SAFECARB 250 50 LB BG 30 SAFECARB 40 50 LB BG 213 SAFECARB 10 50 LB BG 60 POLYPACUL 50 LBBG 2 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 210/210/210 175/175/175 Hr 24 24 4 o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-12 REMARKS Drld. @1941-2110'; rig repairs; drld @2210'-CBD 2 times; mixed/spotted LCM pills on trip out (on bottom., @2008', @1630'); POOH-UD BHA; RIH @2130'-washed tJbottom; circulate/condition; monitor losses; ran water/chemicals/desilter to reduce mud weight t/9.2 ppg; mixed/pumped LCM pills (on bottom., @2000'); mixing third pill @1816' @midnight--some losses continue SOLIDS ANALYSIS (%/Ib/bbl) NaCI .I .2 KCI .I . Low Gravity 6.5159.1 Bentonite 1.9/17.5 Drill Solids 4.51 40.6 Weight Material NAI NA Chemical Cone - 1 1. Inert/React 1.639 Average SG 2.6 Carb/BiCarb (m mole/L) .I -.1 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.491/0.299 kplka (lb-s^nll00ft2) 1.847/4.583 Bit Loss (psi 1 %) 248 120.7 Bit HHP (hhp I HSI) 74/.3 Bit Jet Vel (ftls) 174 Ann. Vel DP (ftlmin) 43.07 Ann. Vel DC (ftlmin) 51.6 Crit Vel DP (ftlmin) 273 Crit Vel DC (ft/min) 291 ECD (ãì 2210 (lb/gal) 9.26 DAILY COST CUMULATIVE COST (907) 776-8680 $ 7,633.16 $ 23,405.08 WATER-BASEl .¿IUD REPORT No. 8 Date 2/3/2003 DepthlTVD 1950 ft /1863 ft Spud Date 1/31/2003 Mud Type GEUGELEX Water Depth Activity DRilLING Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM location: CLAM GULCH, ALASKA Well No,: abalone 1 r:'J1 WFF Operator: MARATHON on.. COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: INLET DRILLING Report For: MIKE LESLIE DRilLING ASSEMBLY Bit Size 17.5 in STC-MSDGHQC Nozzles 3x18 116 / 1/32" Drill Pipe Size Length 4 in 1065 ft Drill Pipe Size Length 5 in 750 ft Drill Collar Size Length 8 in 135 ft CASING Surface 20in ~ 170ft (170TVD) Intennediate 13.375in ~221Oft (2100TVD) Intennediate Production or Liner MUD PROPERTIES Sample From PIT@)350 PIT(â?1230 Flow Line Temp OF 96 96 Deµth/TVD ft 1950/1863 1765/1700 Mud Weight lblgal 9.25 (â?90°F 9.35(â?95°F Funnel Viscosity s/qt 55 54 Rheology Temp of 120 120 R600/R300 51/36 50/35 R200/RlOO 27/20 27/20 R6/R3 8/7 8/6 PV cP 15 15 yp Ib/lOOft2 21 20 I Os/1Om/30m Gel Ib/1 00ft2 8/20/23 7/18/22 API Fluid Loss cc/30 min 10 10.2 lITHP FL Temp cc/30 min Cake API/IITHP 1/32" 2/ 21 Solids %Vol 6 6 Oil/W ater %Vol 0/94 0/94 Sand %Vol 0.25 0.25 I\.ffiT lblbbl 22 21.5 pH 9.5 9.0 Alkal Mud (pm) 0.25 0.2 Pf/Mf 0.15/0.7 0.15/0.75 Chlorides mg/l 300 300 Hardness Ca mg/l 20 20 LSRV cps Dissol Oxygn ppm 7 7 REMARKS AND TREATMENT Building volume to replace losses-water, Gel, PolyPac, Caustic Soda; adding SafeCarb M while drilling for losses Built LCM pills with SafeCarb M/F TIME DISTR Rig Up/Service Drilling Tripping Circulate Monitor Repairs Lost Cire. (bbl) o 745 o o 151 o o 440 o 70 RIG PHONE Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Dumped Shakers Evaporation Centrm.tge Fonnation Left in Hole Desilter M~I ENGR I PHONE 13.5 2 2 1.5 1 4 FAULKNER, F. (907) 242-6994 MUD VOLUME (bbl) Hole 563.1 Active Pits 371.9 Total Circulating Vol 935 In Storage CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT Pump Size 5.5 X 8.in 5.5 X 8.in Pump Cap 2.32 gallstk 2.32 gallstk Pump stk/min 120(â?94% I 20 (â?94% Flow Rate 557 gal/min Bottoms Up 41 min 9851 stk Total Circ Time 70.5 min 16921 stk Circulating Pressure 1430 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 M-I GEL 100 LB BG 68 CAUSTIC SODA 50 LB BG 3 GELEX BENT EXTENC 2 LB BG 2 SAFECARB 40 50 LB BO 84 SAFECARB 10 50 LB BG 16 POLYPACUL 50LBBG 16 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 210/210/210 175/175/175 Hr 24 24 10 o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-12 REMARKS Drld. @1752'-minor losses; rig repairs; chgd. screens on shakers; drld. @1765'-mc. losses; mixed/pumped 40 bbl LCM pill (20 ppb SafeCarb M)-monitor; mixed/pumped 40 bbl LCM pill (10 ppb SafeCarb F/30 ppb SafeCarb M); monitor-CBU 3X; work pipe; wipertrlp @885'-RIH; drld. ahead; built volume in 50 bbl batches; losing volume~ran desilter/water/ehemicals as needed for volume; SOLIDS ANALYSIS (%/Iblbbl) NaCI .I .2 KCI ./. Low Gravity 6.9/62.5 Bentonite 1.91 17.1 Drill Solids 4.91 44.4 Weight Material NAI NA Chemical Conc - I 1. Inert/React 1.7942 Average SG 2.6 Carb/BiCarb (m mole/L) 3.1 4.7 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.503/0.299 kp/ka (lb·s^nl100fP) 1.673/4.583 Bit Loss (psi I %) 298/20.8 Bit HHP (hhp I HSI) 97 I .4 Bit Jet Vel (fils) 190 Ann. Vel DP (ft/min) 47.03 Ann. Vel DC (ft/min) 56.35 Crit Vel DP (ft/min) 273 Crit Vel DC (ft/min) 290 ECD @, 1950 (lb/gal) 9.32 DAILY COST CUMULATIVE COST (907) 776-8680 $ 5,873.23 $ 15,771.92 l WATER-BASEL ¡JlUD REPORT No. 7 Date 2/2/2003 DepthlTVD 1379 ft /1360 ft Spud Date 1/31/2003 Mud Type GEUGElEX Water Depth Activity DRilLING AHEAD Field/Area: WILDCAT Description: SEC.29ff2NIR12W,SM location: CLAM GULCH, ALASKA Well No.: abalone 1 ',WFF Operator: MARATHON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: INLET DRILLING Report For: MIKE LESLIE DRilLING ASSEMBLY Bit Size 17.5 in STC-MSDGHQC Nozzles 3x18 /14 / 1/32" Drill Pipe Size Length 4 in 494 ft Drill Pipe Size Length 5 in 755 ft Drill Collar Size Length 8 in 130 ft CASING Surface 20in @17Oft (170TVD) Intennediate 13.375in @221Oft (2100TVD) Intennediate Production or Liner MUD PROPERTIES Sample From FLO~01 :00 FLOcm18:30 Flow Line Temp OF 99 91 DepthffVD ft 1442/1408 1192/1181 Mud Weight lblgal 9.3cm99°P 9. 15cm91 of FUlU1el Viscosity s/qt 57 58 Rheology Temp of 120 120 R6001R300 54/37 58/40 R20 OIR 1 00 28/20 32/23 R6/R3 6/5 8/6 PV cP 17 18 yp Ib/1 00ft2 20 22 1 Os/1 Om/30m Gel Ib/100ft2 8/20/28 9/24/29 API Fluid Loss cc/30 min 10 10 HTHP FL Temp cc/30 min Cake API/HIRI' 1/32" 2/ 3/ Solids %Vol 6 5 Oil/W ater %Vo1 0/94 0/95 Sand %Vol 0.25 0.25 :MBT lblbbl 22.5 22.5 pH 9.5 9.5 Alkal Mud (Pm) 0.2 0.2 PflMf 0.2/0.7 0.2/0.6 Chlorides mg/1 300 300 Hardness Ca mg/l 20 20 LSRV cps Dissol Oxygn ppm 8 REMARKS AND TREATMENT Drlg ahead. Build'g vis w/gel, gelex. Run dsilter as needed for sand content, solids. Add 3 defoam x after DO additions. Getting clays from formation, dump/diluting with water. MUD VOLUME (bbl) Hole 396.3 Active Pits 439.7 Total Circulating Vol 836 In Storage PIT~12:40 88 1007/1005 9.1 cm82°F 52 120 47/34 27/19 6/5 13 21 8/21/26 12 3/ 5 0/95 0.25 20 10.0 0.4 0.25/0.7 200 o CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT Pump Size 4 X 8.in 4 X 8.in Pump Cap 1.227 gaVstk 1.227 ~aVstk Pwnp stk/min 120cm94% 120~94% Flow Rate 295 ga1/min Bottoms Up 54.6 min 13105 stk Total Circ Time 119 min 28566 stk Circulating Pressure 1420 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 M-IGEL IOOLBBG 18 CAUSTIC SODA 50 LB BG 3 GELEX BENT EXTENI:: 2 LB BG 2 DEFOAM X 5 GA CN 3 POLYPACUL 50LBBG 8 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 150/150/150 150/150/120 Hr 24 24 12 o MUD PROPERTY SPECS Weight 9.0-9.2 Viscosity 45-60 Filtrate 8-12 REMARKS Dir drlg 852'-881'. CIrc, chg saver sub. ODrlgto 1007', Circ hole clean, POH. Chg MWD probe, RIH. Ream 885'-1007'. Dir drlg to 1379' at midnight. (907) 776-8680 TIME DISTR Rig Up/Service Drilling Tripping Circulate BHA Saver sub Last 24 Hrs .5 17.5 2 1 2 1 (bbl) o 360 o o 157 o o 26 o 36 R!G PHONE SOLIDS ANALYSIS (%/lb/bbl) NaCI .I .2 KCI .I . Low Gravity 7.2/65.9 Bentonite 1.9/ 17.2 Drill Solids 5.2/47.7 Weight Material N AI N A Chenùcal Conc - / 1. Inert/React 1.8839 Average SG 2.6 Carb/BiCarb (m mole/L) 4./ 6.3 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.545/0.395 kp/ka (lb·s^n/l00ftZ) 1.316/2.799 Bit Loss (psi! %) 93/6.5 Bit HHP (hhp 1 HSI) 16/.1 Bit Jet Vel (fils) 106 Ann. Vel DP (filmin) 24.91 Ann. Vel DC (ft/min) 29.85 Crit Vel DP (ft/min) 244 Crit Vel DC (ft/min) 266 ECD (àJ, 1379 (lb/gal) 9.34 DAILY COST CUMULATIVE COST $ 2,486.14 $ 9,898.69 MUD VOL ACCTG Oil Added Water Added Mud Received Dumped Shakers Evaporation Centrifuge Fonnation Left in Hole DesiIter M-I ENGR I PHONE Bob Williams (907) 240-4116 ( r=J: WFF Operator: MARATHON Oll- COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: INLET DRilLING Report For: MIKE LESLIE DRILLING ASSEMBLY Bit Size 17.5 in STC-DSJC Nozzles 2x18 12x16 1 1/32" Drill Pipe Size Length 4in ft Drill Pipe Size Length 5 in 722 ft Drill Collar Size Length 8 in 130 ft CASING Surface 20in (ã)17Oft (170TVD) Intennediate 13.375in (ã)2210ft (2100TVD) hltennediate Production or Liner MUD PROPERTIES Sample From PIT~02:00 FLO~19:05 Flow Line Temp OF 82 76 DepthlTVD ft 886/886 726/726 Mud Weight Iblgal 9.1~79°F 9.0~76°F Funnel Viscosity s/qt 54 60 Rheology Temp of 120 120 R600/R300 45/33 53/39 R200/R100 26/18 33/26 R6/R3 7/5 14/11 PV cP 12 14 yp Ib/1 00ft2 21 25 I Os/1 Om/30m Gel Ib/100fF 8/24/29 18/32/42 API Fluid Loss cc/30 min 10 12 HTHP FL Temp cc/30 min Cake API/HTHP 1/32" 3/ 31 Solids %Vol 4 4 Oil/W ater %Vol 0/96 0196 Sand %Vol 0.5 0.25 Iv1BT Iblbbl 22.5 22.5 pH 10.2 10.0 Alkal'Mud (pm) 0.7 0.7 Pf/Mf 0.3/0.8 0.3/0.8 Chlorides mg/l 300 200 Hardness Ca mg/l 20 20 LSRV cps Dissol Oxygn µpm 6 WATER-BASEL ~JlUD REPORT No. 6 Date 2/1/2003 DepthlTVD 852 ft 1852 ft Spud Date 1/31/2003 Mud Type GEUGELEX Water Depth Activity DRilLING AHEAD Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM Location: CLAM GULCH, ALASKA Well No,: abalone 1 MUD VOLUME (bbl) Hole 242.5 Active Pits 449.5 Total Circulating Vol 692 In Storage CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT Pump Size 4 X 8.in 4 X 8.in Pump Cap 1.227 gallstk 1.227 gallstk Pump stk/min 120~94% 120~94% Flow Rate 295 gal/min Bottoms Up 33.5 min 8037 stk Total Circ Time 98.5 min 23645 stk Circulating Pressure 1200 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 M-I GEL 100 LB BG 27 CAUSTIC SODA 50 LB BG 1 GELEX BENT EXTENI: 2 LB BG 3 POLYPACUL 50LBBG 2 DDCWT 55 GADM 2 PIT~12:15 N/A 611/611 8. 95~68°F 58 120 47/33 26/19 8/7 14 19 10/26/34 14 3/ 4 0/96 0.25 20 10.0 0.6 0.3/0.7 200 20 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 150/150/150 150/150/120 Hr 24 24 6 o MUD PROPERTY SPECS Weight N/C Viscosity 50-80 Filtrate 8-12 REMARKS AND TREATMENT Build'g volume. Runn'g desilter as necessary for sand content, solids. Add 2 PAC (broken sx). Add Gel, Gelex for vis, YP when build'g volume. Noted slight increase in oxygen ppm on 02:00 mud check. Last 24 Hrs MUD VOL ACCTG 3.5 Oil Added 17.5 Water Added 3 Mud Received Dumped Shakers Evaporation Centrifuge Fonnatioll Left in Hole Desilter M-& ENGR I PHONE TIME DISTR Rig Up/Service Drilling Tripping Circulate Bob Williams (907) 240-4116 (bbl) o 420 o o 202 o o 21 o 18 RIG PHONE REMARKS RIH, tagbtm 175'. Dir drlgto 481'. Chgwearplate in mud pump. Dir drlgto 610'. POH. Chg out MWD, RIH. Dir drlg to 708'. Repair #2 mud pump. Dir drlg to 852' at mid. SOLIDS ANALYSIS (%/lb/bbl) NaCI .f .2 KCl .f. Low Gravity 5.7/52.2 Bentonite 2.1/ 18.9 Drill Solids 3.6/32.3 Weight Material NAI NA Chemical Cone - 1 1. Inert/React 1.2768 Average SG 2.6 Carb/BiCarb (01 mole/L) 5.811.8 WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values. 0.447/0.365 kplka (lbos^n/l00ft2) 2.162/2.940 Bit Loss (psi 1 %) 92 17.7 Bit HHP (hhp 1 HSI) 16 1 .1 Bit Jet Vel (ftls) 106 Ann. Vel DP (ftlmin) 25.71 Ann. Vel DC (ft/min) 29.85 Crit Vel DP (ftlmin) 244 Crit Vel DC (ft/min) 260 ECD @, 852 (lb/gal) 9.14 DAILY COST CUMULATIVE COST (907) 776-8680 $ 2,310.15 $ 7,412.55 ( WATER-BASEL ~JlUD REPORT No. 5 Date 1/31/2003 DepthlTVD 175 ft /175 ft Spud Date 1/31/2003 Mud Type GEUWATER Water Depth Activity DRILLING AHEAD Field/Area: WllJ:>CAT Description: SEC.29ff2N/R.12W,SM Location: CLAM GULCR ALASKA Well No,: abalone 1 ~WFF Operator: MARATHON OIL COJv1PANY Report For: ROWLAND LAWSON Well Name: ABALONE #1 Contractor: JNLET DRILLING Report For: MIKE LESLIE DRILLING ASSEMBLY Bit Size 17.5 in STC-DSJC Nozzles 2x18 /2x16 / 1/32" Drill Pipe Size Length 4in ft Drill Pipe Size Length 5 in 45 ft Drill Collar Size Length 8 in 130 ft CASING Surface 20in (â}17Oft (170TVD) Intermediate 13.375in (â}2210ft (2100TVD) Intermediate Production or Liner MUD PROPERTIES Sample From PIT~02:00 PIT~18:20 Flow Line Temp OF 66 N/A DepthffVD ft 273/273 170/170 Mud Weight lblgal 8.85~60°F 8.75~60°F Funnel Viscosity s/qt 85 81 Rheology Temp of 120 120 R6001R300 73/59 81/64 R2001R1OO 52144 59/49 R6/R3 30/26 31/27 PV cP 14 17 yp lbll 00ft2 45 47 1 Os/1 Om/30m Gel lbll OOft? 36/54/62 22/46/62 API Fluid Loss cc/30 min 12 14 HTIIP FL Temp cc/30 mill Cake API/HTHP 1/32" 3/ 3/ Solids %Vol 4 4 Oil/W ater %Vol 0/96 0/96 Sand %Vol 0.25 0.25 :MET lblbbl 20 22.5 pH 10.0 10.2 Alkal Mud (pm) 0.6 0.7 Pf/Mf 0.3/0.7 0.3/0.8 Chlorides mg/l 200 200 Hardness Ca mg/l 0 20 LSRV cps Disso1 Oxygn ppm 8 REMARKS AND TREATMENT Add gelex to iner vis, YP. TIME DISTR Rig Up/Service Drilling Tripping Circulate Exit conductor Mill BHA (bbl) o 13 o o 7 o o o o o RiG PHONE MUD VOL ACCTG Oil Added Water Added Mud Received Dumped Shakers Evaporation Centrifuge F onnation Left in Hole Desilter M~! ENGR I PHONE Last 24 Hrs 1 3 5 .5 3 9 2.5 Bob Williams (907) 240-4116 MUD VOLUME (bbl) Hole 51.6 Active Pits 455.4 Total Circulating Vol 507 In Storage PIT~04:00 N/A 170/170 8.7~64°F 70 120 58/42 28/21 17/15 16 26 22/34/38 15 3/ 4 0196 0.25 20 10.0 0.6 0.25/0.7 200 20 CIRCULATION DATA Plli-np Make OIL WELL 1600PT OIL WELL 1600 PT Pump Size 4 X 8.in 4 X Kin Pump Cap 1.227 gal/stk 1.227 ~a1Istk Pwnp stk/min 90~94% 90~94% Flow Rate 221 gal/min Bottoms Up 9.5 min 1719 stk Total Circ Time 96.4 min 17344 stk Circulating Pressure 400 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 M-I GEL 100 LB BG 5 CAUSTIC SODA 50 LB BG 1 GELEX BENT EXTENC 2 LB BG 12 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 150/150/150 150/150/120 Hr 6 6 o o MUD PROPERTY SPECS Weight N/C Viscosity 50-90 Filtrate N/C REMARKS Drill 17.5" hole 123'-170'-unable to pass 170'. Circ out, POH. RIH, attempt to drill out of conductor--no go. POH. UD bit, BHA P/U and M/U hwdp while wait'g on mill. RIB, mill fì'l69' to 175', work.'g thro shoe. POH, UD mill'g assy. RIH w/driUing ass'y. SOLIDS ANALYSIS (%/Ib/bbl) NaCI .f .1 KCI .f. Low Gravity 3.9/35.2 Bentonite 2.118.1 Drill Solids 1.9/ 17. Weight Material NAI NA Chemical Cone - I .1 InertlReact .7558 Average SG 2.6 Carb/BiCarb (m mole/L) 5.913. WAREHOUSE PHONE (907) 776-8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0.307/0.150 kplka (lb·s^n/l00fF) 9.269/21.720 Bit Loss (psi / %) 50/ 12.6 Bit HHP (hhp / HSI) 6 / Bit Jet Vel (fi/s) 80 Ann. Vel DP (ftJmin) 22.36 Ann. Vel DC (:ft/min) 22.36 Crit Vel DP (ftJrnin) 501 Cdt Vel DC (ftJmin) 501 ECD @ 175 (lb/gal) 9.06 DAilY COST CUMULATIVE COST $ 861.25 $ 5,102.40 ~WFF Operator: MARAmON OIL COMPANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: INLET DRILLING Report For: MIKE LESLIE DRilLING ASSEMBLY Bit Size 17.5 in STC-DSJC Nozzles 2x18 12x16 I 1/32" Drill Pipe Size Length 4in ft Drill Pipe Size Length 5 in 40 ft Drill Collar Size Length 8 in 130 ft MUD PROPERTIES Sample From PIT~01:30 PIT~lO:lO Flow Line Temp of 65 N/A DepthfrVD ft 170/170 149/149 Mud Weight I bl gal 8.7~63°F 8.7~56°F Funnel Viscosity s/qt 72 58 Rheology Temp of 120 120 R600/R300 55/38 45/30 R200/R100 25/17 22/15 R6/R3 9/6 6/4 PV cP 17 15 yp Ibll00fP 21 15 lOsll Om/30m Gel Ibll00ft2 9/17/26 6/15/20 API Fluid Loss cc/30 min 14 14 HTHP FL Temp cc/30 min Cake APIIHTHP 1/32" 3/ 3/ Solids %Vol 4 4 Oil/W ater %Vol 0/96 0/96 Sand %Vol 0.25 0.25 :MBT lblbbl 20 20 pH 1O~0 9.7 Alkal Mud (pm) 0.7 0.5 PflMf 0.3/0.8 0.2/0.7 Clùorides mg/l 300 300 Hardness Ca mg/l 20 20 LSRV cps Dissol Oxygn ppm 8 ( WATER-BASEL.¡fIUD REPORT No. 4 Date 1/30/2003 DepthlTVD 170 ft /170 ft Spud Date 1/31/2003 Mud Type GELlWATER Water Depth Activity SPUD Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM location: CLAM GULCH, ALASKA Well No.: abalone 1 CASING Surface 20in ~ 170ft (170TVD) Intemlediate 13.375in ~2210ft (2100TVD) Intennediate MUD VOLUME (bbl) Hole 50.2 Active Pits 449.8 Total Circulating Vol 500 In Storage CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT Pwnp Size 4 X 8.in 4 X 8.in Pwnp Cap 1.227 gal/stk 1.227 f!;allstk Pwnp stk/min 80~940/0 80@94% Flow Rate 196 gal/min Bottoms Up 10.5 min 1676 stk Total Circ Time 107.1 min 17143 stk Circulating Pressure 800 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 M-I GEL 100 LB BG 10 GELEX BENT EXTENr:: 2 LB BG 2 Production or Liner SOLIDS EQUIP Detrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 150/150/150 150/150/120 Hr 4 4 o o MUD PROPERTY SPECS Weight N/C Viscosity 50-90 Filtrate N/C REMARKS AND TREATMENT Build 40 bbl more mud volume for spud. REMARKS NIU Diverter system. PIU 36 stds drillpipe. RIH w/BHA #1. PJSM. TIME DISTR Last 24 Hrs MUD VOL ACCTG (bbl) SOLIDS ANALYSIS (%/lb/bbl) MUD RHEOLOGY & HYDRAULICS Rig Up/Service 4 Oil Added 0 NaCl ./.2 np/na Values 0.533/0.297 Drilling Water Added 52 KCl ./. kplka (lb·s^n/100ft2) 1.456/3.944 Tripping 4 Mud Received 0 Low Gravity 2.7/24.9 Bit Loss (psi 1 %) 39 1 4.9 PJSM .5 Dumped 0 Bentonite 2.1/19.4 Bit HHP (hh~1 HSI) 4/ BHA 3.5 Shakers 0 Drill Solids .615.4 Bit Jet Vel ( s) 71 BOPNU 9 Evaporation 0 Weight Material NAI NA Ann. Vel DP (ftlmin) 14.74 WeUhead 1 Centrifhge 0 Chemical Cone - I .1 Ann. Vel DC (ftlmin) 16.75 LID hanuner 2 Fonnation 0 Inert/React .2403 Crit Vel DP (ftlmin) 257 Left in Hole 0 Average SG 2.6 Crit Vel DC (ft/min) 268 Oesilter 0 Carb/BiCarb (m mole/L) 5.9/3. ECD ~ 170 (lb/gal) 8.75 M-I ENGR I PHONE RIG PHONE WAREHOUSE PHONE DAIL Y COST CUMULATIVE COST Bob Williams (907) 240-4116 (907) 776-8680 $ 778.40 $ 4,241.15 ( WATER-BASEl.JlUD REPORT No. 3 Date 1/29/2003 DepthlTVD 145 ft /145 ft Spud Date 1/31/2003 Mud Type GELlWATER Water Depth Activity DRIVE CONDUCTOR PIPE Field/Area: WILDCAT Description: SEC.29fT2N/R12W,SM location: CLAM GULCH, ALASKA Well No,: abalone 1 ~WFF Operator: MARATIION OIL COlv1P ANY Report For: ROWLAND LAWSON Well Name: ABALONE # 1 Contractor: JNLET DRILLING Report For: MIKE LESLIE DRilLING ASSEMBLY Bit Size 17.5 in STC-M300HQC Nozzles 3x18 /14/ 1/32" Drill Pipe Size Length 5 in 77 ft Drill Pipe Size Length in ft Drill Collar Size Length 8 in 68 ft CASING Surface 20in (a) 170ft (170TVD) Intennediate 13.375in (a)2210ft (2100TVD) Intennediate Production or Liner MUD PROPERTIES Sample From PIT(â)~O:OO PIT~12:35 Flow Line Temp of N/A N/A DepthffVD ft 145/145 145/145 Mud Weight lb/gal 8.7~57°F 8.7~58°F Funnel Viscosity s/qt 60 62 Rheology Temp of 12058 120 R600/R300 43/27 45/29 R200/R100 21/16 22/16 R6/R3 5/4 5/4 PV cP 16 16 yp lb/lOOft2 11 13 1 Osll Om/30m Gel Ib/lOOft2 5/15/18 6/17/20 API Fluid Loss cc/30 min 15 16 HTHP FL Temp cc/30 min Cake APIIHTIIP 1/32" 3/ 31 Solids %Vol 4 4 Oil/W ater %Vol 0/96 0/96 Sand %Vol 0.25 0.25 MET lblbbl 20 20 pH 9.8 10 Alkal Mud (Pm) 0.7 0.8 Pf/Mf 0.3/0.8 0.3/0.8 Chlorides mg/l 400 400 Hardness Ca mg/l 40 40 LSRV cps Dissol Oxygn ppm 8 REMARKS AND TREATMENT No mud mixed today. TIME DISTR Rig Up/Service Drillin~ Tripping Drive conductor (bbl) o 25 o o o o o o o o RIG PHONE Last 24 Hrs MUD VOL ACCTG 7 Oil Added Water Added Mud Received 14 Dumped Shakers Evaporation Centrifh ge Fomlation Left in Hole Desilter M-I ENGR I PHONE Bob Williams (907) 240-4116 MUD VOLUME (bbl) Hole 44.5 Active Pits 402.5 Total Circulating Vol 447 In Storage CIRCULATION DATA Pump Make OIL WELL 1600PT OILWELL 1600 PT Pump Size 4 X Kin 4 X 8.in Pump Cap 1.227 gallstk 1.227 1!;alIstk Pump stk/min 54~94% Flow Rate 66 gallmin Bottoms Up 27.6 min 1489 stk Total Circ Time 284.5 min 15361 stk Circulating Pressure 130 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 150/150/150 150/150/120 Hr o o o o MUD PROPERTY SPECS Weight N/C Viscosity 50-90 Filtrate N/C REMARKS Cheek Koomey Unit. Drive 20" conductor. SOLIDS ANALYSIS (%/lb/bbl) NaCl .I .2 KCI .I . Low Gravity 2.7/24.8 Bentonite 2.1/19.4 Drill Solids .615.3 Weight Material NAI NA Chemical Cone - 1 .1 Inert/React .2371 Average SO 2.6 Carb/BiCarb (m molelL) 5.9/4.7 WAREHOUSE PHONE (907) 776-8680 MUD RHEOLOGY & HYDRAULICS np/na Values 0.671/0.395 kplka (lb·s^nll00fP) 0.43812.240 Bit Loss (psi 1 %) 4/3.3 Bit HHP (hhp / HSI) 1 Bit Jet Vel (ftls) 24 Ann. Vel DP (ftlmin) 4.96 Ann. Vel DC (:ftJmin) 5.64 Crit Vel DP (ftlmin) 220 Crit Vel DC (ft/min) 234 ECD (á1145 (lb/gal) &,72 DAilY COST CUMULATIVE COST $ 625.00 $ 3,462.75 ~WFF Operator: MARATHON OIL COMPANY Report For: GENE ANDERSON Well Name: ABALONE #1 Contractor: INLET DRILLING Report For: MIKE LESLJE DRilLING ASSEMBLY Bit Size 17.5 in STC-M3DGHQC Nozzles 3x18/141 1/32" Drill Pipe Size Length 5 in 77 ft Drill Pipe Size Length in ft Drill Collar Size Length 8 in 68 ft MUD PROPERTIES Sample From PIT(á)16:10 PIT(â),NOON Flow Line Temp OF N/A Ñ/A DepthfTVD ft 145/145 145/145 Mud Weight lblgal 8.7 (á)60°F 8.7(á)62°F Funnel Viscosity s/qt 48 52 Rheology Temp of 120 120 R600/R300 47/31 49/32 R200/R100 25/18 24/17 R6/R3 6/4 8/6 PV cP 16 17 yp lb/100ft2 15 15 1 Osl1 Om/30m Gel 1b/100ft2 7/19/21 9/20/24 API Fluid Loss cc/30 min 14 16 HTHP FL Temp cc/30 min Cake APIIHTIIP 1/32" 3/ 3/ Solids %Vol 4 4 Oil/W ater %Vol 0/96 0/96 Sand %Vol 0.25 0.25 lvIBT lblbbl 20 20 pH 10 10 Alkal Mud (pm) 0.6 0.6 PfIMf 0.3/0.9 0.2/0.8 Chlorides mg/l 300 300 Hardness Ca mg/l 40 20 LSRV cps Dissol Oxvgn ppm 8 ·f ( CASING Surface 20in ~17Oft (170TVD) Intennediate 13.375in ~2210ft (2100TVD) Intennediate Production or Liner REMARKS AND TREATMENT Finish pump'g sweep around. Last 24 Hrs MUD VOL ACCTG Oil Added Water Added Mud Received Dumped Shakers Evaporation Centrifuge Fonnation Left in Hole Desilter M·I ENGR I PHONE ebbl) o o o o o o o 30 o o RIG PHONE TIME DISTR Rig UplService Drilling Tripping Circulate Prep f/hammer Diverter 1 1 19 3 Bob Williams (907) 240~4116 WATER-BASEl.~UD REPORT No. 2 Date 1/28/2003 DepthlTVD 145 ft /145 ft Spud Date 1/31/2003 Mud Type GEllWATER Water Depth Activity DRIVE 20" Field/Area: WILDCAT Description: SEC.29ff2N/R12W,SM location: CLAM GULCH, AlASKA Well No,: abalone 1 MUD VOLUME (bbl) Hole 44.5 Active Pits 377.5 Total Circulating Vol 422 In Storage CIRCULATION DATA Pump Make OILWELL 1600PT OILWELL 1600 PT Pump Size 4 X 8.in 4 X 8.in Pump Cap 1.227 gaVstk 1.227 gaVstk Ptunp stklmin 54@94% Flow Rate 66 gallmin Bottoms Up 27.6 min 1489 stk Total Circ Time 268.5 min 14501 stk Circulating Pressure 130 psi PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEER 1 1 GELEX BENT EXTENC 2 LB BG 1 SOLIDS EQUIP Derrick Shaker Derrick Shaker Cleaner 1 Centrifuge Size 150/150/150 150/150/120 Hr 4 4 o o MUD PROPERTY SPECS ·Weight N/C Viscosity 50-90 Filtrate N/C REMARKS TD pilot hole, pump sweep around. POH to drive 20". Prep floor. Rig up hammer. Make up and weld on 1st joint. SOLIDS ANALYSIS ('Al/lb/bbl) NaCI ./ .2 KCI ./. Low Gravity 2.7/24.9 Bentonite 2.1119.4 Drill Solids .61 5.4 Weight Material N N N A Chemical Conc - 1 .1 Inert/React .2403 Average SG 2.6 Carb/BiCarb (m molelL) 5.9/3. WAREHOUSE PHONE MUD RHEOLOGY & HYDRAULICS np/na Values 0.600/0.429 kp/ka (lb·s^n/l00ft2) 0.782/2.120 Bit Loss (psi I %) 4/3.3 Bit HHP fhhp 1 HSI) I Bit Jet Ve (ftls) 24 Ann. Vel DP (ft/min) 4.96 Ann. Vel DC (ftlmin) 5.64 Crit Vel DP (ftlmin) 227 Crit Vel DC (ftlmin) 243 ECD (â) 145 (lb/gal) 8.72 CAlLY COST CUMULATIVE COST (907) 776-8680 $ 636.90 $ 2,837.75 (~. ,10 \, ;3 j ( ( 90d-J~1 ) ( CEMENT JOB REPORT CUSTOMER MarathonOilCo ¡DATE 14-FEB-03 !F.R.# 363310004 !SERV.SUPV. David Wallingford -LEASE & WËLL' NAM'E' "'-'~...,.. ,-.- .... '~'-'-"'--!ï~~OcAT¡ON- ..----- - .._- .-.-. _.__._-- ! COUNTY -PÃRISH-BLOCK __·u_.._...· "~4"_ --- I ABALONE 1 - API 5013320517??oo i 29-2N-12W : Kenai Alaska -DISTRICT -...--..- IDRILLlNG CONTRACTOR RIG # ¡TYPE OF JOB .. K~~~~.~g:g._:&." h'~g'_ciFPbÛ(;-š=·-· . ·f·- . ~~d'Š·T~¡~~~:R~WARE· ·'·====r-_~:~.===·=.P,tlY§.l.CA¿~~~~~~r:OPEïÙI~§.·...._.___._...._~.:.~.=::~.~_~.....'=' Cement Plug, Rubber, Bottom 9-5/8 ¡¡I SACKS ¡SLURRY! SLURRY I WATER ¡ PUMP! Bbl! Bbl ...-..........0 .- ! OF i WGT I YLD I GPS I TIME I SLURRY I MIX Cement Plug, Rubber, Top 9-5/8 in ¡ ! CEMENT! PPG i FT3: ¡ HR:MIN ; ! WATER -L ... ..._ _.__. ._.......__.._..__....,....__..._...___..__.._._.......__.....-.......-..l..--..--.L....-...-·-..-.·····..·t····.---···-.·-'.-..-..............---1-___.......___.....__ .. --"MATËRiALS Fuï~Nïs'HED BY BJ ¡! ¡ ¡ i \ : --..........-. ....... ... . ......0..-..··-.-.-...---.----·--·-------···-----··----r--.h·-·-..--.-t---.~.·-._.---+----.·-- . ---;..-.._._.1...__..__ MCS-4D , ; 10 I ¡ i i 40 ; .--.-.. ....-....... .... ...-.-.. ..................... ........_,.... ....-...-.....-. ............-...---.......--. ..-...............- ---i-···-..···..·····-·--··-····t···-· ........-.----t-.-....-u....-- .., ..........--.......---.¡........-.-:--..... ·ï-····_...-··-..~ ........-. ....--...- I 550 I 13.5 ~ 1.84! 9.27! 00.77 : 180.07 I 121.40 ---- I I 9.21~:~·=~=_~_.~-==¡~~=~~~=1~._.~.23nr.~::=..== ._ ____ i 135 _______.~.~1___.2.491 11.20 I' 07:15 i 59.91 i 35.99 \ I Ii \ ' ¡ I I : I I I ' : i -·Ä;~iîab¡;; Mix Water -50õ--ãï;l--Avalï;';i;-¡:;¡;Pï:Fi~;"-----500-- B,,¡:+···----·+·-----+-------1·-~~~~ --I 603.761 1 57.40 HOLE ¡ TBG-CSG·D.P. i COLLAR DEPTHS -sfiE- % EXCESŠ-r-')E-PTH ···t·-·$i7F·....·····T·······WGT~-···· TYPE I DEPTH-r·--GRA·De·'-+'··· SHOe-···-r·----Fi..OAT .. 12.25 ! 4350 ! 9.625 I 40 CSG i 4350) ! I I i I ¡ I : I I I I! I LAST CASING ¡ PKR-CMT RET-BR PL-LlNER ¡ PERF, DEPTH TOP CONN I WELL FLUID 1 ~'~~5 ~T TvPCrõi:;t1=-BRAND & TYPE-t--QE1!IIIfTOP tJlTM=rSIZE-TftiRËÃÕr-TYP.ê::::::.-r wGï:= i II II " ¡ ) I .1 ¡ i I I I , , ~·~~I-~I~~I,~~~~~t~I-~- I J ¡¡I EXPLANATION: TROUBLE SETTING TOOL, RUNNING CSG, ETC. PRIOR TO CEMENTING: .,......--- Production Tail -.-.-.-..-.-.---- Drilling Mud ___.._,.........."_._a.___._..__ Lead Cement .-----.-.......--.....-,--....,- STAGE PRESSURE/RATE DETAIL I EXPLANATION TIME .. ·········;····¡;RE-ŠSl.-.~E:·psì· ....... 'T- RATE -·liibi:..Fi.ljiDIFLÜïD·....·I;.··sAFËïY..MËËTï·ÑG:·BJ-Cï~EW I X Icci'RE'P:lTl 1 ---.......................... .. ....-.-- HR:MIN. r-Pi~-~ _~~ L~NNULUS I' .......~!'.~__._L!_UM.~~~..-L TYP~__ TESTLINES 250Õ···psP--n-...-...""""...---- \ I I ¡... ! . CIRCULATING WELL . RIG ! XJ··-· BJ ! ...1'-......... 22:30! ! : ! -.. ........-! C~ïied .- ~ ......----.---.-.....--..-- ..........: 1-..·······.. 1_······----1..······· ...,_. 621 LEAD.~!~lead<?~~~~~ ..._ RE8EIVED ----- 05:04 I : ! i TAIL St rt t 'I . ...-......-...............-.-.-......--...............- 05·:1··3·-·..i······594~-_·····-I-·· ·-è.24·f··· 631 -...._uo+-_~...~__n__._......n " _.__._.. .._... _ - 05:3Õ-·..·¡---¡išr--.. .....,_.. ... 5.58+-' "~6't-' -....-\-. ..--........--.. .-.. MAY '+~2003-"" . .-.....---- "'05:36 :".---- ..~-.-n.. ..... ·L.!.-- .... .~.... 184· ...-.-....-L...-.........._..._... ..---- - --..... v..____. .--_...._.__...._.._. - ...-.. n.--j- _. .___.. _nJ. ...__.__._...... .... .._.-+.. ... ..._.._... I Lead done. Dr~ plug ....~}T.. L.... .. _._.L. -.... __-L_. ....____._.....__.......} ell\lATER .___fPÙmp õüt'~;lug .. - ·..-AljjiIQü&l~äšCorii~~·-·-···-·- =::00:15j 1}~~-==±::===-t-_3i-9_51~\JD _ -- I :~m~:~~g -__=~=_=:=~-::= ~=:=----------- ! i i : . I I ---l i -. ---~- PSI TO - ;.. I'EST -:' BàL~'CM'¡: ¡'TOTAL I·--·n-psi--t "S'Pòii- .....-. .----. -. - i BUMPED: BUMP I FLOAT i RETURNS/! BBL. I LEFT ON ¡ TOP OUT i SERVo SUPV, I -y PLU~~O~~UG . t :~~~-r~_ER_S~DJ!~:U:~~ìo- CSGl~EM~;l ~ ~. _=~-~_~_~~-~_-~=~-=~~~=~~ I PT 1552 (12198) Page 1 Jr8004 ( ( c Load Sheet ) (£j DISTRICT .K~n9i. DISPATCH SHEET NO. CUSTOMER MªTªJb9.o9i! ço.. . .. ._.u._.._.. . ...._ JOB DATE F;_ê.~.J_~--=-2º--<!.~_._____..__... BRANCH BULK PLANT Kenai, AK ____..__._._.._...__....__._... FIELD RECEIPT NO 3_~~31 0-º04 _...__._._...____ FIELD RECEIPT DA TE£J~.ê::J~2003 ___. \. I ¡ QUANTITY ' ¡ VERIFIED ITEM! ¡:-··-···----··ri,ÕADEDI __._u_._._ NET I TO FIELD PRODUCT DESCRIPTION NO. I UOM I ORDERED ¡ BLENDED RETURNED USAGE ¡ RECEIPT Class G Cement 100021 I sacks I 685i 685! 0: 685! ~~~~~e=tdOride___- -. -... . ...------. :....m:~:~~~I}~~{~~=-~]I~~~:__:-I__-__:-~:~~t::-·f,~~[--. ..-.11:-.. .1-'~~F-··-·-- ~o.diuæ Meta~ili~.élJ~._ i 100275 : Ibs I 259 259i 01 259: J~9..r.rt~,J?yIK_ .. _. ....... _..._.... ...... . . . ··_··.._,_..·~...h..·_.. .".._....,_.,.._..,._."-..",._"'_..~"..,, . .~~:~1F~~e .......-.--......--...............................-.--..... . .I::~~:~. J:~:. ....--....--+ -.-...?!~~~....- ...?t~i~···" " ~I' . ...?I~i:+'--' -..- ASA~·3Õ1·· ......... ................-....-........-......... ..:..:..::...~~:::~:... . .....' ._.~~:~7~~~_~·~.-: :~j~~_ ~-r' -- .. ..... 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I ...L......... ... .....1..... ..11 I I I I I I . --:=:::----------:=:]·==::-·-=~f~=:~:-~l=~=:-~:~~~:~:-:=:::::l:~~:=~-~r:---::-:)::::-::-:=: ~~~i~~:~~~ñ;~:~~~:-pj~g~~~i~~l;;~-~~~~l~9~~~_~~~~~i-~~~~~~~~t~~~:bü~~~ätP~~.~~:~~:~~:~_~~~ï~~~~~j:s~º;;:;-::;; - ... _..__u .. ,,_ . WELL NAME A~~.~.9~~ .1. . - .-..........-.....-.....,..... ,.,' . .~..' ".... _".___, .._..____.., _..._....,. _.__.. _.ÞO_.... ......."..~._._'._,.._..._-,,,....',,._.......,. ..". ""..,." , ..""" "......".-..-,..- ,.....-.,.......-..'''...... , ,,,,,' .......,....--...".., .. .."'......-.,.....-"..."''',...'''',.... "" ..."...-..-..."..... .",,-.....-...."'"'''. ..., ....."......".,......" .."". .. .......-......."".........."". ..--." .." ..........."... -. .....--........... .... ,...,....--... .. ..........-...-..... '''''. ......."....-......."".. .... --~....,,_.-...,.... ISSUED BY Marshall Brown ._,....._,."... ,-. ..,......-..""..... ...... '-""~'''''''. .....- RECEIVED TO LOCATION Dªyi.Q WªII.in9fQrº__....._._... . ... .....-.".. .............~.. .""....".~ "---'."~"" ''''".~._..,._.."~....,,..........._..._~.... .._..........._~.-..........".........."..... DA TE!:§ê:~.~:~º-º}_.._ DA TEF!;!'..::l~-~Q()~ . ."..."...'.."..........----...-.--............."......" SERVICE SUPERVISOR RETURNS VERIFIED BY APPROVAL Edwin Post DATE ....,..._.._.."....."..~....",."".."...._. OPERA TrONS SUPERVISOR CUSTOMER SIGNATURE ......".-....... .... RepO!1 Printed on: February 15. 20037: Page 1 Jr7301 Job Start: Saturday, February 15, 2003 ..- .------------------- -_..---...... -- - - - ----.-. ... ,.-.. ........ "'--"'0) Ec. Q.c.. .c .........,. .........,. "......", N> +- ~m ~e. o >< - ::::s U-<e +x ~o 75 .--.- 5 "-- .."-".."-.------- - -_______ .-._~_.. ___ ._.."..____ -- -_______._.____._ -_______ __ _ _.._ __",0" __ '__."_ __ _ _ .__ _____"___.________.__ __.__~_.__n___ _.___"______. _. __ _..__._ .._._"_"_______ _ __._n_".___".__"____________._ __ __ ._, ____._ _. _._. _ _. BJ Services 40 Elapsed Time (min) 60 20 -- +~ ~ ""fI'"\' l' ~, r~ o r-r\r .; f\ I o rJ r tn ::' 15000 ---- Q.I/ .........c. - ......... UJ_ a..rn Q.Q. § :¡ 10000- a. ~ 'n ~N tn tn tn tn (þ (I) ...... 5000 ---.' c..a. DO ~\ Y1rV\ l ~~'~~ .---. 1 0 .~~, .n_ 15 20 .....-...- .- 20000 ..-.. ...---.,. .............----. ---.....-...___._..._ _. _.__...____ ......... ,. - '_ ...._... ..._..... _. '''''._'. .._. .._u_ __ _~__._._._._ ".._..n_n.__._·__ .._._.._'.._.___ .__._._._. _..' .-..' .__.. .. ·_.·._·n........_···..··_··....··_· ....... - -.. -- .._, . . .' -. -- . . ... . ...... ...... .. - ., - . . - 1 ~...., BJ Services JobMaster Program Version 2.6082 _ ~ Job Number: Customer: Marathon Oil Company Well Name: Clam Gulch Field Abalone #1 ( ~~~fY\~ éJoB -j d~ MARATHON OIL COMPANY Page 1 of 1 WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS 1 MTS Mob rig fl KU 14-6RD workover to Abalone #1. OPERATION COMMENTS RDMO Glacier Rig 1 to Abalone #1 location. KB Daily Drilling Report Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 65 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE 907-283-1312 COUNTYIOTHER I LAST CASING Kenai (â2 0 124 HR FORECAST Start MIRU to new location. MOCWI 60.0000 TVD I DFSO I DOL1 I RPT # DATE 65 1 23-Jan-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL' 2,695,000 I DAILY WELL CO'-:'T I CUM WELL COST \ NEXT CASING I LEAKOFF 20.000 (in) tã2 145 (ft) NRI MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 216.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION FRo.M TO. HRS 18:00 06:00 12.00 FROM 65 TO. SUB 65 AF OPERATIONS SUMMARY PHASE OP TRBL MIRU RIG DESCRIPTION RDMO Glacier Rig #1. Pre-drive 20", 133 ppf, K-55, PE drive pipe to 65' BGL prior to rig move. COMPANY Glacier Drilling Marathon .SERVICE PERSONNEL DATA NO. HOURS COMPANY 18 108.00 Alaska Petroleum Contra 1 12.00 Weaver Brothers (WBI) . SERVICE POB.@06:00: NO.. HOURS 4 48.00 3 48,00 CASINGStlMMARY LAST CASING TEST: MAX SICP 1 MD I rVD 'I LAST BOP TEST: SIZE 1 ID ISHOETËST NEXT BOP TEST: WT I GRADE BURST , ~~\Þ.\- o\\fê\~~~O\'~ C ~\G~~ r''''{.E-. C''''E~MV'· _D· 1 i'lI .. ' , I",~. W, ."",~ ~,~~.11 . Ml'Y 1 3 t¡)~a~~ (ìti & Gs.s Gr,)!1f:., (>;:\m~nøw~ Md'ß~'~¡\~;· Printed: 3/12/2003 2:44:36 PM f ( MARATHON OIL COMPANY Page 1 of 1 WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS MIRU drilling rig. OPERATION COMMENTS MIRU drilling rig. KB Daily Drilling Report Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 65 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE TVD I DFSO I DOL2 I RPT # DATE 65 2 24-Jan-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST 60.0000 . I LAST CASING I NEXT CASING I LEAKOFF ~ 0 20.000 (in) ~ 145 (ft) 124 HR FORECAST MIRU drilling rig to Abalone #1. 907-283-1312 COUNTY/OTHER Kenai MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 342.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Cold weather RD, load out and rig move. SAFETY SUMMARY BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION FROM TO HRS 06:00 06:00 24.00 FROM 65 TO SUB 65 AF OPERATIONS SUMMARY PHASE OP TRBl MIRU RIG MIRU drilling rig. DESCRIPTION COMPANY Glacier Drilling Marathon Alaska Petroleum Contra SERVICE PE~SONNEL DATA NO, HOURS COMpANY 18 216.00 Weaver Brothers (WBI) 2 28.00 Weatherford 3 36.00 Veco Alaska SERVICE POB @06:00: NO. HOURS 4 48.00 1 2.00 1 12.00 LAST BOP TEST: SIZE 10 I· SHOE TEST . CASING SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST ~1\~\.- co~f~~€\"\o\.-~ 1\Gti \ Printed: 3/12/2003 2:44:38 PM WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS MIRU drilling rig. OPERATION COMMENTS MIRU drilling rig. MANHRS WORKED I ACCIDENT TYPE 360.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 06:00 24.00 FROM 65 COMPANY Glacier Drilling Marathon Alaska Petroleum Contra LAST BOP TEST: SIZE I 10 I SHOE rEST Daily Drilling Report Exploitation Gas \GL \24 HR PROG TMD 21.0 282.00 65 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ( KB ,( ,{ MARATHON OIL COMPANY Page 1 of 1 TVD I DFSO \ DOL3 I RPT # DATE 65 3 25-Jan-2003 SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL COS..T I CUM. WELL COST 60.0000 _ I LAST CASING I NEXT CASING . I LEAKOFF (â} 0 20.000 (in) (â} 145 (ft) \24 HR FORECAST MIRU drilling rig to Abalone #1. WBS 907-283-1312 COUNTY/OTHER Kenai I LAST SAFETY MTG 1/22/2003 TO SUB 65 AF SERVICE SAFETY SUMMARY IBOP PSI TEST \ LAST STOP CARD AUDIT \ RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION OPERATIONS. SUMMARY PHASE OP TRBL MIRU RIG MIRU drilling rig. DESCRIPTION PERSONNEL DATA NO. HOURS COMPANY 18 216.00 Weaver Brothers (WBI) 1 24.00 Veco Alaska 3 36.00 Gate Guard POB @ 06:00: . NO, HOURS 4 60.00 1 12.00 1 12.00 SE~VICE ,·CASINGSUMMARY LAST CASI NG TEST: MAX>SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST ~1\~\ø co~f~~e~o\..~ 1\G{\ Printed: 3/12/2003 2:44:41 PM WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS MIRU drilling rig. OPERATION COMMENTS MIRU drilling rig. MANHRS WORKED I ACCIDENT TYPE 345.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 06:00 24.00 FROM 65 COMPANY Glacier Drilling Marathon Alaska Petroleum Contra LAST BOP TEST: SIZE I 10 I SHOE TËST Daily Drilling Report Exploitation Gas I GL \ 24 HR PROG TMD 21.0 282.00 65 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ( KB ( MARATHON OIL COMPANY Page 1 of 1 TVD \ DFSO \ DOL4 I RPT # DATE 65 4 26-Jan-2003 SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST ... 60.0000 _ \ LAST CASING I NEXT CASING I LEAKOFF cæ 0 20.000 (in) cæ 145 (ft) \24 HR FORECAST MIRU drilling rig to Abalone #1. WBS 907-283-1312 COUNTY/OTHER Kenai I LAST SAFETY MTG 1/22/2003 TO SUB 65 AF SERVICE SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION OPERATIONS SUMMARY PHASE OP TRBL MIRU RIG MIRU drilling rig. DESCRIPTION PERSONNEL DATA NO. HOURS COMPANY 18 216.00 Weaver Brothers (WBI) 1 24.00 Veco Alaska 3 36.00 Gate Guard SERVICE POB @06:00: NO, HOURS 3 45.00 1 12.00 1 12.00 CASINGSOMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST "ø, DEtt"\~\.. cot~.r ~ ûO\..E 1\Gf\-\1' £\ Printed: 3/12/2003 2:44 :43 PM WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS RU top drive. OPERATION COMMENTS MIRU drilling rig. MANHRS WORKED \ ACCIDENT TYPE 278.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 06:00 24.00 FROM 65 COMPANY Glacier Drilling Marathon LAST BOP TEST: SIZE I 10 I SHOETEST Daily Drilling Report Exploitation Gas \ GL \24 HR PROG TMD 21.0 282.00 65 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ( KB ~: MARATHON OIL COMPANY Page 1 of 1 I DFSO \ DOLS I RPT # DATE 65 5 27 -Jan-2003 SAPJWBS COST DX02.07227 .CAP .DRL 2,695,000 MOC WI NRI I DAILY WELL COST \ CUM WELL COST 60.0000 I LAST CASING I NEXT CASING I LEAKOFF lã2 0 20.000 (in) (âl145 (ft) 124 HR FORECAST Fin RU. Prep to drill & drive 20". TVD WBS 907-283-1312 COUNTY/OTHER Kenai I LAST SAFETY MTG 1/22/2003 TO SUB 65 AF SERVICE SAFETY SUMMARY ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION OPERATIONS· SUMMARY PHASE OP TRBL MIRU RIG DESCRIPTION MIRU. Extend mast, RU derrickboard, install winterizing tarps. RU top drive. PERSONNEL DATA NO. HOURS COMþANY 18 216.00 Weaver Brothers (WBI) 1 24.00 Gate Guard PQB@06:QO: NO. HOURS 3 26.00 1 12.00 SERVICE CASIN<3SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST rne.~'1\"\- co~f IV ~.O\-e. 1\G~1 (,. Printed: 3/12/2003 2:44:46 PM WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Pull rotary table. OPERATION COMMENTS Fin RU drilling rig. Clean out 20" to 65' and drill pilot hole to 145'. Remove rotary and prep to PU hammer. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 343.00 None 1/22/2003 1/23/2003 N ACCIDENT DESCRIPTION: ( ( MARATHON OIL COMPANY Page 1 of 2 Daily Drilling Report Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 80.0 145 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE KB I DFSO I DOL6 I RPT # DATE 145 6 28-Jan-2003 SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 MOC WI NRI I DAILY WELL COST_ I CUM WELL COST 60.0000 _ I LAST CASING I NEXT CASING 1 LEAKOFF cæ 0 20.000 (in) cæ 145 (ft) 124 HR FORECAST RU hammer & drive 20" conductor. TVD WBS 907-283-1312 COUNTY/OTHER Kenai I LAST RIG INSPECTION SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 12:00 6.00 65 65 AF MIRU RIG Fin RU top drive. RU floor, tongs spinners, stand pipe. MU muc line & choke line. Change saver sub. 12:00 16:00 4.00 65 65 AF MIRU RIG Test run mud pumps, pump through pop off valve, change shaker screens. String geolograph line. 16:00 19:30 3.50 65 65 AF DRIVE DRVCSG Open conductor, RKB to GL 21.0'. Rack, strap & MU 17-1/2" clean out BHA. Mix spud mud. RU vac trucks to take returns f/ cellar to shakers. 19:30 00:00 4.50 65 145 AF DRIVE DRVCSG RIH tag fill @ 35'. Clean out 20" conductor f/ 35' to 65'. Drill f/ 65' to 145' RKB w/ gel/water mud. (ART 4 hrs) 00:00 01:00 1.00 145 145 AF DRIVE CIRC Circulate hole clean. 01:00 02:00 1.00 145 145 AF DRIVE TRIP POOH to drive 20" casing. 02:00 06:00 4.00 145 145 AF DRIVE EQUIP RD tie back, pull rotary table motor, floor plates. Pull rotary table, remove flow line & secure area to PU hammer equipment. COMMENTS AOGCC notified of spud and upcoming diverter test on 1/27/2003 (Lou Grimaldi). BIT/RUN SIZE MANUF. TYPE SERIAL NO. 1 /1 17.500 STC MSDGHQC LK1029 BIT / RUN WOB RPM GPM PRESS 1/1 /5 80 I 90 348 180 DENSITY(ppg)I FV PV/YP 74 16/25 1..ppl WUHTHP 18.0/ 8.70 GELS 14/27 ECDI8.76MUDDATADAIL.YCpSTI Fcrr.SOL OIW %Sand/MBT Ph/pM Pf/Mf 3.01 / 0.50/17.5 10.00/0.7 0.210.5 2201.00 CIICa 500 140 I CUM COST 2201.00 CaCI2(wt%; H2S LIME ES 6RPM BITS JETS OR TFA 18/18/18/1411111/ bEPTHIN DATE IN 35.0 1/27/2003 I·()"D·L·B-G·O-R 2-2-NO-A-4- I-NO- TD P BIT 121 HRS 4.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 110.0 24.44 4.50 110.0 24.44 BHA I EFF WT. I PICKUP I SLACK OF1 ROT WT. I TORQUE (iaX/min) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS Tri-Cone Bit, Bit Sub, Drill Collar (2), Heavy Weight Drill Pipe (2) 1'tÞtL CONf\D~OLE "\G~" n . BHA NO, I. LENGTH 1 126.55 BHA DESCRIPTION Printed: 3/12/2003 2:44:48 PM ( ( WELL NAME ABALONE 1 MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas IGL 124 HR PROGTMD 282.00 80.0 145 Page 2 of 2 IKB 21.0 ITVD 145 I DFSO I DOL6 I RPT # I DATE 6 28-Jan-2003 NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 5.500 55 131.69 180 263.38 8.000 5.500 55 131.69 180 263.38 KILL SPM I PRESSURE ~. o!'., COMPANY Glacier Drilling Marathon Weaver Brothers (WBI) Lynden Transport Peninsula Sanitation Atigun SERVICE PERSONNEL DATA NO. HOURS COMPANY 18 216.00 Weaver Brothers (WBI) 1 24.00 Alaska Pipe & Supply 1 12.00 M-I Drilling Fluids 1 1.00 Gate Guard 1 1.00 ABB Vetco Gray 4 40.00 Smith International SERVICE POB @ 06:00: NO. HOURS 3 14.00 1 1.00 1 20.00 1 12.00 1 1.00 1 1.00 LAST BOP TEST: SIZE I ID I SHOE TEST I CASING SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST C NF~Dl~\'lT'Al TIGHT HOLE Printed: 3/12/2003 2:44:48 PM Daily Drilling Report Exploitation Gas I GL \24 HR PROG TMD 21.0 282.00 145 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ( WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Prep to start driving 20" (CQ 07:00 hrs. OPERATION COMMENTS RU hammer. Weld on additional 20" conductor. MANHRS WORKED I ACCIDENT TYPE 386.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 12:00 6.00 FROM 145 12:00 21 :00 9.00 21 :00 06:00 9.00 DENSITY(PP9ll FV PVIYP 48 16/15 8.70 ·>GELS 7/19 Ippl WUHTHP 14.0/ 145 145 KB ( MARATHON OIL COMPANY Page 1 of1 MOCWI 60.0000 I DFSO I DOL7 I RPT # DATE 145 7 29-Jan-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 I DAILY WELL COST I CUM WELL COST - ~ I NEXT CASING I LEAK OFF 20.000 (in) (CQ 145 (ft) TVD NRI 907-283-1312 COUNTY/OTHER I LAST CASING Kenai (CQ 124 HR FORECAST Drive 20" condo I LAST SAFETY MTG 1/22/2003 TO SUB 145 AF 145 AF 145 AF IECDI FCIT.SOL 3.01 COMPANY SERVICE Glacier Drilling Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard Baker Hughes Inteq Toloff hammer LAST BOP TEST: SIZE I ID I SHOE TEST o Install starting head. NU diverter. Prep hammer to drive conductor. SAFETY SUMMARY ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION OPERATIONS SUMMARY PHASE OP TRBL DRIVE DRVCSG DRIVE DESCRIPTION Remove torque tube turnbuckles, install scaffolding in cellar, prep to PU hammer. Offload & PU hammer. Remove floor plates. Change rigging & hang hammer in top drive. PU & weld on 32.10' section of 20" conductor. Ready hammer to drive conductor. Delay hammer operation until 07:00 hrs, 01/29/03 (noise considerations). Ready diverter equipment, install water line f/ rig to change house. Clean choke house. Service Koomey unit. Prep cellar for diverter. DRVCSG DRIVE DRVCSG MUDDATAOAILYCOS:r OIW %Sand/MBT Ph/pM Pf/Mf I 0.25/20.0 10.0010.6 0.3/0.9 637.00 CIICa 300 /40 I CUM COST 2838.00 CäCI2(wt%:H2S LIME ES 6RPM PERSONNEL DATA NO. HOURS COMPANY SERVICE 18 216.00 Alaska Oil Sales 1 24.00 Lynden Transport BHI 1 10.00 BJ Services cement 1 24.00 Alaska Petroleum Contra Welders 2 24.00 Alaska Petroleum Contra crane 2 32.00 ZEE Medical First Aid Kits 2 17.00 POB @ 06:00: NO, HOpRS 1 1.00 2 4.00 2 6.00 2 20.00 1 5.00 1 3.00 CASING SUMMARY LAST CASING TEST: MAXSICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST CON~lDE.N"\"L 1'GH" HOLE Printed: 3/12/2003 2:44:51 PM WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Adjust torque tube. OPERATION COMMENTS Drive 20" conductor CSG. Weld on starting head. UD 20" hammer. Install floor plates and rotary table. Adjust torque tube. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 426.00 None 1/29/2003 1/23/2003 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Driving conductor. FROM TO HRS FROM 06:00 07:00 1.00 07:00 07:30 0.50 07:30 09:30 2.00 09:30 10:00 0.50 10:00 11:30 1.50 11:30 12:00 0.50 12:00 14:30 2.50 14:30 15:00 0.50 15:00 17:00 2.00 17:00 18:00 1.00 18:00 20:30 2.50 20:30 21:00 0.50 21:00 00:00 3.00 00:00 01 :30 1.50 01 :30 03:30 2.00 03:30 05:30 2.00 05:30 06:00 0.50 DENSITY(þpg) I FV . PVNÞ 60 16/11 8.70 GELS 5/15 COMPANY Glacier Drilling Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard Baker Hughes Inteq ( f \ MARATHON OIL COMPANY Page 1 of 2 Daily Drilling Report Exploitation Gas I GL \24 HR PROG TMD 21.0 282.00 145 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 TVD I DFSO I DOL8 I RPT # DATE 145 8 30-Jan-2003 WBS SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 I DAILY WELL COST I CUM WELL COST I NEXT CASING I LEAKOFF 13.375 (in) (ã2 2,200 (ft) KB RIG PHONE MOCWI 907 -283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 20.000 (in) (ã2 170 (ft) 124 HR FORECAST NIU diverter. Test diverter. NRI PIU Drilling tools. OPERATIONS SUMMARY TO SUB PHASE OP TRBL DESCRIPTION AF DRIVE DRVCSG Prepare 21 1/4" diverter equipment while wait for 07:00 starting time for drive pipe. AF DRIVE DRVCSG Drive 20" CSG Joint#3 from 86' to 91' RKB AF DRIVE DRVCSG Prepare and weld joint#4. AF DRIVE DRVCSG Drive 20" CSG F/91' to 107' RKB. AF DRIVE DRVCSG Prepare and weld on joint#5. AF DRIVE DRVCSG Drive 20" CSG F/107' to 124'RKB. AF DRIVE DRVCSG Prepare and weld on joint#6. AF DRIVE DRVCSG Drive 20" CSG 124' to 141' RKB. AF DRIVE DRVCSG Prepare and weld on joint#6. AF DRIVE DRVCSG . Drive 20" CSG 142' to 157' RKB AF DRIVE DRVCSG Prepare and weld on joint#7. AF DRIVE DRVCSG Drive 20" CSG 157' to 170' RKB (149'BGL). AF DRIVE DRVCSG Cut off 20" and UD cut joint(30.5'joints #6 and #7 UD). RIU to UD hammer. AF DRIVE NUND Weld on 21 1/4" starting head and nipple for drain valve. AF DRIVE DRVCSG UD 20" hammer. AF DRIVE EQUIP Install floor plates and rotary table. Connect rotary motor. AF DRIVE EQUIP Adjust TO torque tube and turnbuckles. Ipp· WUHTHP 15.01 I Ec:DI FC:IT.SOL 3.0/4.0 I·MÙ[).·DATA I DAILy COST···...I OIW %Sànd/MBT Ph/pM Þf/Mf 0.25/20.0 9.8010.7 0.310.8 625.00 CI/Ca 400 140 I. CUM COST 3463.00 CaCI2(Wt%: H2S LIME ES 6RPM PERSONNEL DATA SERVICE NO. HOURS COMPANY SERVICE 17 204.00 Toloff hammer 1 24.00 BJ Services cement 1 8.00 Alaska Petroleum Contra Welders 1 24.00 Alaska Petroleum Contra crane 2 24.00 United Rentals POB @06:00: NO. HOURS 1 17.00 2 6.00 2 20.00 1 5.00 1 2.00 3 44.00 eOl\ FniEN11M. TIGHT HOLE Printed: 3/12/2003 2:44:53 PM I( ( WELL NAME ABALONE 1 MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas GL \24 HR PROGTMD 282.00 145 Page 2 of 2 IKB 21.0 TVD 145 IDFSO I DOL8 I RPT #8 I DATE 30-Jan-2003 LAST BOP TEST: SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 170 170 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 BURST (psi) 3,060 }\~\~~ ~~\Qe~o\-~ C1\G~1 Printed: 3/12/2003 2:44:53 PM C~f~ ~ 1\G~ \ Daily Drilling Report Exploitation Gas I GL \24 HR PROG TMD 21.0 282.00 25.0 170 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ( MARATHON OIL COMPANY Page 1 of 2 TVD I DFS1 I DOL9 I RPT # DATE 170 9 31-Jan-2003 WBS SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 I DAILY WELL COST I CUM WELL COST I NEXT CASING I LEAKOFF 13.375 (in) ({Q 2,200 (ft) WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STAT E/P ROV Alaska CURRENT STATUS / MTS Service rig while wait on 17 1/2" mill. OPERATION COMMENTS Install torque tube turnbuckles. M/U standpipe manifold. N/U 21 1/4" Diverter system. P/U 4" DP. M/U BHA. Clean out CSG to 170'.Can not drill through shoe. POOH. CIO bit attempt to drill out shoe. POOH. Service rig while wait on 17 1/2" mill. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 366.00 None 1/30/2003 1/23/2003 N ACCIDENT DESCRIPTION: KB MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 20.000 (in) ~ 170 (ft) 124 HR FORECAST Mill out shoe. Drill ahead. SAFETY MTG TOPICS: General safety. FROM TO HRS FROM TO SUB 06:00 07:30 1.50 145 145 AF 07:30 15:30 8.00 145 145 AF 15:30 19:30 4.00 145 145 AF 19:30 23:00 3.50 145 145 AF 23:00 23:30 0.50 145 145 AF 23:30 01:00 1.50 145 170 AF 01:00 01:30 0.50 170 01:30 02:00 0.50 170 02:00 03:00 1.00 170 03:00 04:00 1.00 170 04:00 04:30 0.50 170 04:30 05:00 0.50 170 05:00 06:00 1.00 170 DËNSITY(ppg) 8.70 Ippl FV PV/yP GELS· WUHTHP 72 17/21 9/17 3.01 NRI OPERATIONS SUMMARY PHASE OP TRBL DRIVE DRVCSG DRLSUR NUND DRLSUR TRIP DRLSUR TRIP DRLSUR TRIP DRLSUR DRILL DESCRIPTION Install torque tube turnbuckles. M/U standpipe manifold. N/U 2 1/4" diverter and 163/4" diverter line. P/U and rack back 72 joints 4" 14ppf S-135 HT-38 DP. P/U 17.5" Directional BHA. Scribe motor and MWD. PJSM prior to drilling. RIH w/5" HWDP. Tag @ 123'. Spud well @23:30hrs. Clean out 20" CSG to 170'. Can not get out of CSG. Circ. clean. POOH. BIO bit. Bit 1/4" out of gauge. 170 AF DRLSUR CIRC 170 TA DRLSUR TRIP CSOT 170 T A DRLSUR RIG CSOT 170 TA DRLSUR TRIP CSOT 170 TA DRLSUR DRILL CSOT 170 TA DRLSUR TRIP CSOT 170 TA DRLSUR RIG CSOT lecol FC/T:SOL 3.0/4.0 Service rig. M/U RR bit#3. RIH to 170'. Attempt to drill ahead. Erratic torque. Can not drill through shoe. POOH. BIO bit. Service rig while wait on 17 1/2" mill. IMUDDATA DAILYCOST om %Sand/MBT Ph/pM Pf/Mf I 0.25/20.0 10.0010.7 0.3/0.8 780.00 CI/Ca 300 120 I qµMCOST 4243.00 CaCI2(wt%;H2S LIME ES 6RPM 9 BITS· BIT/RUNSIZE MANUF. TYPE SERIAL NO. JETSORTFA DEPTH IN DATE IN I-O.;D"L-B~G-O.;R 2/1 17.500 STC DSJC ML6617 18/18/16/1611/111 145.0 1/30/2003 o-0------ 3 IRR1 17.500 STC MSDGHQC LK1029 18/18/18/14111111 170.0 1/3112003 0-0------ BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/1 1 15 60 I 60 418 500 177 1.50 25.0 16.67 1.50 25.0 16.67 31 RR1 I I 464 700 BHA BHA~O. IL~~~~1~ IE~~~å Ip'~~660 IS~6~60~F1R~~~OTå ITORf6~¿~~~~;) IBHAHRSIJARHRS IMWDHRSIMTRHRS SSHRS BHA DESCRIPTION 171/2" MSDGQC STC BIT I 8" Mach1C/1.2AK0/17 1/4" UBHS, 171/4" IBS 8" Collar MWD 8" HANG OFF SUB, 8" Printed: 3/12/2003 2:44:56 PM ) ) MARA.l'HONOILCC>MPANY Pág~20f2 Daily Drilli ngR~Þºrt Exploitation Gas IGL 124 HR PROGTMD 282.00 25.0 170 WELL NAME ABALONE 1 IKB 21.0 IrVD 170 IDFS1 IDO~ I RPT # I DATE 9 31-Jan-2003 BHA BHA DESCRIPTION Monel DC ,6 5/8"H:90-P X 41/2"IF-B, 5" 49.5PPF HWDP(5), 61/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (20), 4 1/2"IF-P X HT-38-B 4" 14PPF S-135 DP NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP/HYDRAULIC DATA STROKE (in) LINER (in) SPMQ (gpm) PRESS.(psi) TOTAL Q KILL SPM I PRESSURE 8.000 5.500 100 232.03 700 464.06 8.000 5.500 100 232.03 700 464.06 COMPANY Glacier Drilling Marathon Weaver Brothers (WBI) M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Gate Guard 1 24.00 Baker Hughes Inteq 1 8.00 Epoch Well Services 1 24.00 R&K Industrial SERVICE POB@06:QO: NO. HOURS 2 24.00 2 48.00 2 24.00 2 10.00 LAST BOP TEST: SIZE (in) ID(in) SHOE TEST (ppg) 20.000 18.730 CASING SUMMARY LAST CASING TEST: MAX SlOP MD (ft) TVD(ft) (psi) @ (ppg) 170 170 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 BURST (psi) 3,060 ~~\~\-, co~~~~€~o\..~ 1\.~t"' Printed: 3/12/2003 2:44:56 PM dl~~~?E"...........; MA~TH(¡)NØIÞ··C(¡)MPJ\NY ) '\"\G\-\1n. .. .. WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS Drilling ahead <æ 462'. OPERATION COMMENTS Attempt to drill out of 20" CSG shoe. Drill 12 1/4" hole F/170'-175'. Mill out CSG shoe w/17.5" mill. Drill F/175' to 462'. MANHRS WORKED I ACCIDENT TYPE 373.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM 06:00 07:30 08:00 09:00 09:30 HRS 1.50 0.50 1.00 0.50 2.50 TO 07:30 08:00 09:00 09:30 12:00 12:00 13:00 1.00 13:00 14:30 1.50 14:30 17:00 2.50 17:00 19:30 2.50 19:30 20:00 0.50 20:00 21 :00 1.00 21 :00 22:00 1.00 22:00 23:00 1.00 23:00 00:00 1.00 00:00 06:00 6.00 OENSITY(ppg) FV PVNP 85 14/45 FROM 170 170 170 170 175 175 175 175 175 175 175 175 175 175 175 8.85 GELS 36/54 I PP I WUHTHP 12.01 Daily· ..[)rillin·~.··.· Report Exploitation Gas I GL \ 24 HR PROG TMD 21.0 282.00 292.0 462 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 20.000 (in) @ 170 (ft) 124 HR FORECAST Drill ahead. KB I LAST SAFETY MTG 1/30/2003 TO SUB 170 T A 170 TA 170 T A 175 TA 175 TA 175 TA 175 TA 175 TA 175 TA 175 TA 175 TA 175 TA 175 TA 175 TA AF IECOI FCIT.SOL 3.0/4.0 TVD 462 IDFS2 I DOL I RPT # DATE 10 10 01-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST WBS NRI DX.02.07227.CAP.DRL I DAILY WELL COST I NEXT CASING 13.375 (in) (ã} 2,200 (ft) LEAKOFF SAFETY SUMMARY IBOP PSI TEST \ LAST STOP CARD AUDIT I REGULATORY INSP? 1~~2003 N I LAST RIG INSPECTION OPERATIONS SUMMARY PHASE OP TRBL DRLSUR TRIP CSOT DRLSUR DRILL CSOT DRLSUR TRIP CSOT DRLSUR DRILL CSOT DRLSUR WAIT CSOT I MUD DATAl DAILY COST I OIW %Sand/MBT Ph/pM Pf/Mf I 0.25/20.0 10.0010.6 0.3/0.7 DRLSUR TRIP CSOT DESCRIPTION RIH W/17 1/2" bit and slick assy. Could not drill past shoe @ 170'. POOH and B/O bit. M/U 12 1/4" bit and slick assy. RIH. Drill 12 1/4" hole F/170' to 175'. POOH. While wait on 17 1/2" mill to be built and delivered to location repair the elevators. Pull test tugger lines. P/U 17 1/2" flat bottom mill and 103/4" junk basket. Mill would not pass through rotary table(mill would not pass through 17.5" gauge ring). B/O and LID mill. While wait on mill to be cut down test pull the bridge cranes. While wait on mill to be cut down P/U and rack back 20 joints 5"HWDP in derrick. While wait on mill to be cut down rack 13 3/8" CSG. M/U 17 1/2" mill. RIH and tag @ 165'. Wash down to 169'. Mill out 20" CSG F/169' to 170'(small slivers of steel across shakers). Drill 17 1/2" hole F/170' to 175'. Work mill across CSG shoe. POOH LID mill and junk basket. Junk basket full of gravel wlsmall slivers of steel. M/U 17 1/2" bit and directional BHA. RIH to 175. Drill and survey F/175' to 462'(ART=4). 862.00 CI/Ca 200 I I CUM COST CaCI2(wt%; H2S 5105.00 LIME ES 6RPM 30 DRLSUR WAIT DRLSUR WAIT CSOT CSOT BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-Q-R 4/RR2 17.500 STC MSDGHQC LK1029 18/18/18/14/11111 170.0 1/3112003 0-0------ 5/RR 12.250 STC FGS+C MJ0920 16/16/16/18111111 170.0 1/3112003 0-0------ 6/1 17.500 Baker Flat Botto 175.0 1/31/2003 0-0------ 7/RR1 17.500 STC DSJC ML6617 18/18/16/16111111 175.0 1/3112003 2-2-WT-A-8- 3-SD-DTF BIT / RUN WOB RPM I GPM I PRESS I P BIT HRS I 24Hr DIST 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP DRLSUR WAIT DRLSUR TRIP DRLSUR FISH CSOT CSOT CSOT DRLSUR DRILL DRLSUR TRIP CSOT CSOT DRLSUR TRIP DRLSUR DRILL CSOT Printed: 3/12/2003 2:44:59 PM ) -) MA~ATHQNØILCØI\llF?AN'¥ Page2Óf2 BIT I RUN 4 I RR2 51 RR 6/1 7 I RR1 [)~ityDrillingRèpôrt Exploitation Gas IKB IGL 124 HR PROG I TMD ITVD IDFS2 IDOL IRPT# I DATE 21.0 282.00 292.0 462 462 10 10 01-Feb-2003 WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP I I 499 1,000 I I 499 1,000 0.50 5.0 10.00 , 0.50 5.0 10.00 .. I I 499 1,000 10 I 20 50 I 50 500 900 253 4.00 287.0 71.75 4.00 287.0 71.75 WELL NAME ABALONE 1 BHA NO. I LENGTH 7 885.11 BHA DESCRIPTION BHA I· EFF WT.· I PICK UP SLACKOF1 ROT WT. TORQUE (måxlmin) I BHA HRS I JAR HRS I MWD HRS I MTR.HRS I SS HRS 47,000 40,000 40,000 40,000 4,000 I 2,000 17.5" STC DSJC , 8" Mach1C/1.2AK0/17 1/4" UBHS , 17 1/4" IBS , 8" Collar MWD , 8" HANG OFF SUB, 8" Monel DC , 65/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (20), 4 1/2"IF-P X HT-38-B , 4" 14PPF S-135 DP NO. MAKE: OF PUMP 1 OILWELL 2 OILWELL PUMP/HYDRAULIC DATA STROKE (in) LINER (in) SPM Q(gpm) PRESS.(psi) TOTALQ KILLSPM/PRESSURE 8.000 5.500 110 255.23 1,000 498.86 8.000 5.500 105 243.63 1,000 498.86 SURVEY DATA MD INCL< AZIMUTH TVD VS N/SCUM EIWCUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 287 0.44 48.70 287.00 -0.63 0.74 -0.64 1.65 196 0.35 311.70 196.00 -0.32 0.40 -0.45 0.18 345 0.35 78.90 345.00 -0.87 0.92 -0.30 0.39 255 0.26 314.10 255.00 -0.50 0.61 -0.68 0.15 COMPANY Glacier Drilling Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard SERVICE PERSQNNEL.DATA NO. HOURS COMPANY 17 204.00 Baker Hughes Inteq 1 24.00 Epoch Well Services 2 12.00 R&K Industrial 1 24.00 S&R Enterprises 2 24.00 POB@ 06:00: NO. HOURS 2 48.00 2 24.00 3 12.00 1 1.00 LAST BOP TEST: SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 170 170 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 BURST (psi) 3,060 ~~1\~~ co\'\f\~ \\0\-" .~ '1\G~ \ Printed: 3/12/2003 2:44:59 PM .... .. .. . ....... ..\.)l, (¡~~~~1r.MA~~~~~:[1;n~~::NY I GL 124 HR PROG TMD 21.0 282.00 518.0 980 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Drilling ahead @2 980. OPERATION COMMENTS Drill f/462' to 481'. Repare pump#2. Drill F/481 , to 610'. MWD failed. POOH cIa MWD. Service rig. Drill F/708' to 881'. C/O TDS saver sub. Drill F/881 , to 980'. MANHRS WORKED I ACCIDENT TYPE 409.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 06:30 0.50 06:30 08:00 1.50 08:00 11 :00 3.00 FROM 462 481 481 11:00 13:00 2.00 610 13:00 13:30 0.50 610 13:30 14:00 0.50 610 14:00 17:00 3.00 610 17:00 18:30 1.50 708 18:30 00:00 5.50 708 00:00 00:30 0.50 852 00:30 01:30 1.00 881 01:30 06:00 4.50 881 DENSITY(ppg) 9.10 Ipp I FV PVNP GELS WUHTHP 54 12/21 8/24 10.01 ') KB IDFS3 I RPT # DATE 11 02-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST IDOL 11 TVD 977 WBS MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 20.000 (in) @2 170 (ft) 124 HR FORECAST Drill ahead. DX.02.07227 .CAP. DRL I DAILY WELL COST I NEXT CASING 13.375 (in) @2 2,200 (ft) LEAKOFF NRI RIH. Drill F/61 0' to 708'. Repair pump#2. I LAST SAFETY MTG 1/30/2003 SAFETY SUMMARY ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION TO SUB 481 AF 481 TA 610 AF OPERATIONS SUMMARY PHASE QP TRBL DRLSUR DRILL DRLSUR RIG DRLSUR DRILL FLDS DESCRIPTION Dir drill and survey F/462' to 481'(ART=Ohrs AST=.5hrs). cia wear plate on pump#2 cylinder#3. Dir drill and survey F/481 , to 610'. MWD failed(ART=.52hrs AST=1.2hrs). POOH C/O MWD(stab and bit balled up). Service rig. RIH survey @ 570' and 605'. Dir drill and survey F/61 0' to 708'(ART=1.03hrs AST=.8hrs). Weld on suction screen box pump#2 leaking. Repair weld. Dir drill and survey F/708' to 852'(ART=.68hrs AST=1.87hrs). Dir drill and survey F/852' to 881'(ART=1.17hrs AST=Ohrs). cIa TDS saver sub F/4 1/2 IF to HT-38. Dir drill and survey F/881 , to 980'(ART=.17hrs AST=2.0hrs). 610 TA DRLSUR TRIP MWD 610 AF DRLSUR RIG 610 TA DRLSUR TRIP MWD 708 AF DRLSUR DRILL 708 TA DRLSUR RIG FLDS 852 AF DRLSUR DRILL 881 AF DRLSUR DRILL 881 T A DRLSUR RIG TOPS 980 AF DRLSUR DRILL IECDI FCIT.SOL 3.0/4.0 IMUD DATADAILYCOST I O/w %Sand/MBT Ph/pM 'Pf/Mf I 0.50/22.5 10.2010.7 0.3/0.8 2310.00 CI/Ca 300 120 ICUMCO$T 7415.00 CaCI2(wt%: . H2S LIME ES 6RPM 7 BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-Q-R 7/RR1 17.500 STC DSJC ML6617 18/18/16/16/111/1 175.0 1/3112003 2-2-WT-A-8- 3-SD-DTF BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr DlST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 7 I RR1 20 I 40 60 I 80 557 1,500 328 10.00 518.0 51.80 14.00 805.0 57.50 BHA \ EFF WT, I PICK UP I SLACK OF1 ROT WT. ITORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 47,000 60,000 60,000 60,000 6,000/4,000 17.5" STC DSJC, 8" Mach1C/1.2AKO/17 1/4" UBHS ,171/4" IBS ,8" Collar MWD, 8" HANG OFF SUB, 8" Monel DC, 65/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (20), 4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP BHA NO. I LENGTH 7 885.11 BHA DESCRIPTION Printed: 3/12/2003 2:45:02 PM ) ) MARATH()N·..··QlI...C0MPANY Page20f2 Daily Dri II ingReport Exploitation Gas IGL 124 HR PROGTMD 282.00 518.0 980 ITVD 977 IDFS3 IDOL 11 IRPT# I DATE 11 02-Feb-2003 WELL NAME ABALONE 1 IKB 21.0 NO. 1 2 MAKE OF PUMP PUMP! HYDRAULlCDAr~ STROKE (in) LINER (in) SPM Q(gpm) PRESS, (psi) 8.000 5.500 120 278.43 1,500 8.000 5.500 120 278.43 1,500 TO~ AL Q 556.86 556.86 KILLSPM I· PRESSURE -t OILWELL OILWELL SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM E/W' CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 406 0.50 303.90 406.00 -1.04 1.11 -0.33 1.29 647 5.40 187.30 646.67 8.27 -8.06 -1.92 2.10 467 0.35 320.10 466.99 -1.28 1.40 -0.67 0.31 706 6.70 188.80 705.34 14.48 -14.22 -2.80 2.22 526 2.50 187.30 525.98 -0.11 0.26 -0.95 4.66 767 7.70 189.10 765.86 22.13 -21.77 -3.99 1.64 555 3.00 184.60 554.94 1.28 -1.12 -1.10 1.78 826 9.50 188.00 824.19 30.95 -30.50 -5.30 3.06 585 4.10 186.90 584.88 3.13 -2.97 -1.29 3.70 890 10.60 189.90 887.21 42.12 -41.53 -7.04 1.79 COMPANY Glacier Drilling Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard SERVICE PERSONNEL .DATA NO, HOURS COMPANY 17 204.00 Baker Hughes Inteq 1 24.00 Epoch Well Services 2 12.00 R&K Industrial 1 24.00 S&R Enterprises 2 24.00 SERVICE POB@ 06:00: NO. HOURS 2 48.00 2 24.00 3 48.00 1 1.00 LAST BOP TEST: SIZE (in) ·ID (in) SHOE TEST(ppg) 20.000 18.730 CASING SUMMARY LAST CASING TEST: MAX SICP MD(ft) (psi) @ (ppg) 170 TVD(ft) 170 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 BURST·(psi) 3,060 CON~U)EN'T\Al . '7:GH1 HOLE Printed: 3/12/2003 2:45:02 PM ) ) MAf{À'l'HØNØ'LéOr;~F'DE NTIAiø2 pailYDr.HU~QRéPortTIG~iTh 0 l E Exploitation Gas .... . .. . I GL 124 HR PROG TMD TVD I DFS 21.0 282.00 695.0 1,675 1,619 4 RIG NAME & NO. AUTH MD WBS GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENTSTATUS/MTS Drilling ahead @2 1675'. OPERATION COMMENTS Drill F/980'to 1007'. CBU X3. KB I DOL I RPT # DATE 12 12 03-Feb-2003 SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST ~ 60.0000 . I LAST CASING I NEXT CASING I LEAKOFF 20.000 (in) @2 170 (ft) 13.375 (in) @2 2,200 (ft) 124 HR FORECAST Drill ahead to 2200'. Wiper trip. 907-283-1312 COUNTY/OTHER Kenai POOH. C/O bit and MWD. RIH. W/R F/883' to 1007'. Drill F/1007' to 1675'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT I R. EGULATORY INSP? 409.00 None 1/30/2003 1/23/2003 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM 06:00 07:00 08:00 09:00 TO 07:00 08:00 09:00 10:00 10:00 12:00 2.00 12:00 12:30 0.50 12:30 06:00 17.50 DI:NSIT'((ppg)I 9.30 FV PVIYP GELS 57 17/20 8120 HRS 1.00 1.00 1.00 1.00 FROM 980 1,007 1,007 1,007 I LAST RIG INSPECTION TO SUB 1,007 AF 1,007 TA 1,007 TA 1,007 TA OPERATIONS SUMMARY PHASE OP TRBL DRLSUR DRILL DRLSUR CIRC DRLSUR TRIP DRLSUR TRIP 1,007 1,007 1,007 Ipp WUHTHP 10.01 DESCRIPTION Dir drill and survey F/980' to 1 007'(ART=.42hrs AST=O). MWD Circ. Clean(CBUX3) MWD POOH(hole tight F/914' to 883'). MWD Pull MWD and find rag has plugged tool and caused wash out in tool. Bit and stabs balled up. C/O bit(two cones wobble). MWD RIH w/BHA. Test MWD. Repair hydraulic connection on TDS. Cant. RIH to 883'. DRLSUR TRIP MWD W/R F/883' to 1007'. DRLSUR DRILL Dir drill an survey F/1007' to 1675'(ART=5.07hrs AST=7.68). eCD9.34MUDDATAI D,ð,ILYCOSr 2486.00 I CUM COST 9901.00 FCIT.SOL OIW %Sal1d/MBT Ph/pM Pf/Mf CI/Ca CaCI2(wt%:H2$ LIME ES 6RPM 2.0/5.0 I 0.25/22.5 9.50/0.2 0.210.7 300/20 6 1,007 TA DRLSUR TRIP 1,007 TA 1,675 AF BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATEIN I·O~D·L·B·G·O·R 7/RR1 17.500 STC DSJC ML6617 18/18/16/16111I11 175.0 1/3112003 2-2-WT-A-8- 3-SD-DTF 8 IRR4 17.500 STC MSDGHQC LK1029 18/18/18/14111111 1,007.0 2/2/2003 3-3-WT-A-E- 2-SD-TD BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 7 I RR1 20 I 40 60 I 80 557 1,500 328 0.42 27.0 64.29 14.42 832.0 57.70 8 I RR4 15 I 30 70 I 80 557 1,700 331 12.70 668.0 52.60 12.70 668.0 52.60 BHA NO. I LENGTH 8 885.11 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 23,024 65,000 60,000 63,000 7 I 5 17.5" STC MSDGHQC, 8" Mach1C/1.2AKO/171/4" UBHS I 171/4"IBS, 8" Collar MWD, 8" HANG OFF SUB, 8" Monel DC ,65/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (20),4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM / PRESSURE 8.000 5.500 120 278.43 1,700 556.86 8.000 5.500 120 278.43 1,700 556.86 NO. MAKE OF PUMP 1 OILWELL 2 OILWELL Printed: 3/12/2003 2:45:05 PM ) ) WELL NAME ABALONE 1 I\IfA~ATHQNØ1L..C()nnÞANY ÐailYDril1 ihgRéÞPrt EXPloitati()n Gas ··COMPANY SERVICE NO; ... lHouRS COMPANY SERVICE NO. HOURS Inlet Drilling Alaska 17 204.00 Baker Hughes Inteq 2 48,00 Marathon 1 24.00 Epoch Well Services 2 24.00 Weaver Brothers (WB/) 2 12.00 R&K Industrial 4 48.00 M-I Drilling Fluids 1 24.00 S&R Enterprises 1 1.00 Gate GUard 2 24.00 SURVEYJMTA MD ¡NCL AZIMUTH TVO VS N/S CUM E/W CU~DOGLEG I MD INCL AZIMUTH TVD VS N/S CUM EIW CU~DOGLËG 954 12.60 190.50 949.90 54.98 -54.19 -9.33 3.13 1,326 24.80 181.70 1,302.23 '171.63 -170.76 -18.98 , 4.13t 1,016 14.00 187.80 1,010.24 69.24 -68.27 -11.58 2.47 1,386 26.00 185.50 1,356.43 197.24 -196.43 -20.62 3.37 1,078 16.30 187.20 1,070.08 85.44 -84.33 -13.69 -L 3.72 1,449 26.80 185.60 1,412.86 225.20 -224.31 -23.33 1.27 1,140 18.40 184.90 1,129.25 103.90 -102.72 -15.61 I 3.56 1,511 26.90 187.50 1.468.18 253.17 -252. 13 -26.52 1.39 1,202 20.60 182.30 1,187.70 124.49 -123.37 -16.89 3.81 1,576 27.60 1 193.00 1,525.98 282.90 -281.38 -31.83 4.02 1,264 22.30 183.10 1,245.40 147.03 -146.01 -17.96 2.78 II I DATE 03-Feb-2003 PERSONNEL DATA POB @ 06:00: LAST CASING TEST: MAX S/CP MD ft (psi) @ (ppg) 170 CO\fFT JSNTIAl. TIGHT HOLE Printed: 3/12/2003 2:45:05 PM -··...·..)~l CQt\fU?~ ·.·...·..i i ... ·~AIt4.'FI'tØNØILCOMPÅNY TIG El FI 0 l.E DailYD~illingltøport Exploitation. Gas I GL 124 HR PROG TMD 21.0 282.00 490.0 2,165 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ) TVD I DFS5 I DOL I RPT # DATE 2,057 13 13 04-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST 60.0000 . I LAST CASING I NEXT CASING I LEAKOFF - 20.000 (in) lCQ 170 (ft) 13.375 (in) lCQ 2,200 (ft) [24 HR FORECAST Drill ahead to 2210'. Wiper trip. Run 133/8" CSG. WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS 1 MTS Drilling ahead lCQ 2165'. OPERATION COMMENTS Drill F/1675' to 1765'. Losses to the hole of 150bbl/hr. Mix LCM pill and spot. Losses 26bbl/hr. Mix LCM pill and spot. Losses droped to 1 bbl/hr. Wiper trip. RI H drill F/1765' to 2110'. Repair #2 mud pump. Drill F/211 0' to 2165'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? I LAST RIG INSPECTION 409.00 None 1/30/2003 1/23/2003 ACCIDENT DESCRIPTION: KB 907-283-1312 COUNTY/OTHER Kenai SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM .TO SUB PHASE OP TRBL DESCRIPTION 06:00 08:00 2.00 1,675 1,752 AF DRLSUR DRILL Dir drill and survey F/1675' to 1752'{ART=1.15hrs AST=.58hrs) small fluid loss while drilling. 08:00 09:00 1.00 1,752 1,752 AF DRLSUR CIRC Circ. while change packing on #2 pump rod oiler. C/O shaker screens. 09:00 09:30 0.50 1,752 1,765 AF DRLSUR DRILL Dir drill and survey F/1752' to 1765'. Losses increased to 150bbl/hr @ 1765'{ART=.28hrs AST=Ohrs). 09:30 10:00 0.50 1,765 1,765 TA DRLSUR LSCIRC LCIR Slow circulate while mixing LCM pill. 10:00 12:00 2.00 1,765 1,765 TA DRLSUR LSCIRC LCIR Pump 40bbls 20#/bbl Med CaC03 5#/bbl gel pill and displace to end of bit. POOH to 1630'. 12:00 12:30 0.50 1,765 1,765 TA DRLSUR LSCIRC LCIR Mix LCM pill while observe well. Static losses 26bbllhr. 12:30 13:00 0.50 1,765 1,765 TA DRLSUR LSCIRC LCIR Pump 40bbl 30#/bbl Med CaC02 and 10#/bbl Fine CaCo2 5#/bb gel LCM pill and displace to end of BIT. 13:00 16:00 3.00 1,765 1,765 TA DRLSUR LSCIRC LCIR Mix LCM pill while observe well. Static losses 26bbl/hr@1300hrs. 16bbl/hr@14:30hrs. 10bbl/hr@15:00hrs. 1bbl/hr@15:30 hrs. 1bbl/hr@16:00hrs. 16:00 17:00 1.00 1,765 1,765 AF DRLSUR CIRC Circ. hole clean @ 1630'(CBUX2). 17:00 18:00 1.00 1,765 1,765 AF DRLSUR TRIP POOH to 885'. Test MWD. 18:00 18:30 0.50 1,765 1,765 AF DRLSUR TRIP RIH to 170l'{Tagged tight spot). W /R from 1692' to 1765'. 18:30 03:30 9.00 1,765 2,110 AF DRLSUR DRILL Dir drill and survey F/1765' to 211 O'(ART=2.81 hrs AST=1.63hrs) 25bbl/hrs losses w/pumps. 15bbl/hr losses static 03:30 04:00 0.50 2,110 2,110 TA DRLSUR RIG FLDS Repair suction screen box #2 mud pump. 04:00 06:00 2.00 2,110 2,165 AF DRLSUR DRILL Dir drill and survey F/2110' to 2165'(ART=1.25hrs AST=Ohrs). 25 bbl/hr losses w/pump. 15bbllhr losses static. DENSITY(ppg) FV PVIYP 55 15/21 I PP I WUHTHP 10.0/ 9.25 GELS 8/20 BIT/RUN SIZE 8/RR4 17.500 MANUF. STC BIT / RUN WOB \ECD 9.32 MUD DATAl DAILY COST I FCrr.SOL OIW 'YoSand/MBT Ph/pM Pf/Mf 2.0/6.0 0.25/22.0 9.5010.2 0.2/0.7 TYPE SERIAL NO. MSDGHQC LK1029 BITS JETS OR TFA 18/18/18/14/11111 RPM I GPM I PRESS I P BIT 5873.00 I CUM COST CI/Ca CaCI2(wt%: H2S 300 120 15774.00 LIME ES 6RPM 8 DEPTH IN DATE IN 1,007.0 21212003 I-O-D-L-B-G-Q-R 3-3-WT-A-E- 2-SD-TD HRS I 24Hr DIST 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP Printed: 3/12/2003 2:45:08 PM ) ) WELL NAME ABALONE 1 MARATIHONQILCÖMPANY Page2of2 Daily···DrillingReport Exploitation Gas GL 124 HR PROGITMD 282.00 490.0 2,165 !TVD I DFS 2,057 5 IDOL 13 !RPT# I DATE 13 04-Feb-2003 IKB 21.0 BIT I RUN 8 I RR4 WOB 15 I 25 RPM 70 I 80 GPM 550 PRESS 1,900 PBIT 321 HRS 8.18 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 490.0 59.90 20.88 1,158.0 55.46 BHA NO. LENGTH 8 885.11 BHA DESCRIPTION BHA EFF WT. I PICK UP SLACK OF1 ROT WT, TORQUE (maximin) I BHA HRS I JAR HRS MWD HRS I MTR HRS ISS HRS 47,000 75,000 63,000 70,000 8,000/4,000 17.5" STC MSDGHQC ,8" Mach1C/1.2AK0/17 1/4" UBHS ,171/4" IBS , 8" Collar MWD, 8" HANG OFF SUB, 8" Monel DC, 65/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (5),61/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (20),4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP .... PUMP 1 HYDRAULIC DATA NO, MAKE OF PUMP STROKE. (in) LINER (in) SPM Q(gpm) PRESS. (psi) TOTALQ KILLSPM I PRESSURE 1 OILWELL 8.000 5.500 120 278.43 1,900 556.86 2 OILWELL 8.000 5.500 120 278.43 1,900 556.86 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EIWCUMDOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 1,640 27.30 195.20 1,582.77 312.28 -309.99 -39.01 1.65 1,888 24.60 187.20 1,806.30 418.93 -413.63 -66.39 5.73 1,700 26.60 197.10 1,636.26 339.26 -336.11 -46.57 1.85 1,952 25.00 188.20 1,864.40 445.76 -440.23 -69.99 0.91 1,733 26.10 197.80 1,665.83 353.75 -350.08 -50.96 1.78 1,982 24.80 186.70 1,891.61 458.39 -452.76 -71.63 2.21 1,761 25.80 196.90 1,691.00 365.87 -361.78 -54.62 1.77 2,014 24.60 188.20 1,920.69 471.75 -466.02 -73.36 2.06 1,797 25.10 195.10 1,723.51 381.22 -376.65 -58.88 2.90 2,045 24.20 188.50 1,948.92 484.56 -478.69 -75.22 1.35 1,822 24.70 192.50 1,746.19 391.71 -386.87 -61.39 4.66 2,076 24.30 187.30 1,977.18 497.29 -491.30 -76.97 1.62 1,860 24.10 190.90 1,780.79 407.39 -402.24 -64.58 2.35 2,158 24.00 188.00 2,052.01 530.83 -524.55 -81 .43 0.51 COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Baker Hughe$ Inteq 1 24.00 Epoch Well Services 2 12.00 R&K Industrial 1 24.00 S&R Enterprises 2 24.00 SERVICE POB @ 06:00: NO; HOURS 2 48.00 2 24.00 4 48.00 1 1.00 LAST BOP TEST: SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) (psi) @ (ppg) 170 TVD (ft) 170 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 BURST (psi) 3,060 cor"f\OE~"\AL ~ 1\GH" HOLE Printed: 3/12/2003 2:45:08 PM ) CO~r~1·Q~NT'Al orìGf·(T HOLE MARATHQNOIL...····.OOMPANY WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENTSTATUS/MTS POOH. OPERATION COMMENTS Drill F/2165' to 2210'. Circ. hole clean. Spot LCM Pill. POOH and spot LCM pills. POOH(SLM). Observe well. RIH to 2127'. W/R F/2127' to 2210'. Circ. hole clean and decrease MW F/9.3ppg to 9.2 ppg. Pump LCM pills and observe well. SAFETYSUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? I LAST RIG INSPECTION 409.00 None 1/30/2003 1/23/2003 ACCIDENT DESCRIPTION: KB DclilyPrillingReport Exploitation· ·Gas I GL 124 HR PROG TMD 21.0 282.00 45.0 2,210 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE TVD 2,100 WBS DFS6 I DOL I·RPT # DATE 14 14 05-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST 907-283-1312 COUNTY/OTHER Kenai DX.02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 20.000 (in) (ã2 170 (ft) 13.375 (in) (ã2 2,200 (ft) \24 HR FORECAST POOH. Run and cement 13 3/8" CSG. LEAKOFF SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 07:00 1.00 2,165 2,210 AF DRLSUR DRILL Dir drill and survey F/2165' to 2210'(ART=.9hrs). Losses wi pumps on 25bbl/hr. Losses w/pumps off 15bb/hr. 07:00 09:00 2.00 2,210 2,210 AF DRLSUR CIRC Circ. hole clean(CBUX2). 09:00 09:30 0.50 2,210 2,210 TA DRLSUR LSCIRC LCIR Mix LCM pill while while circ. 09:30 10:00 0.50 2,210 2,210 TA DRLSUR LSCIRC LCIR Spot 40bbl 30#/bbl Med CaCo2 10#/bbl Fine CaC02 5#/bbl Gel LCM pill. 10:00 10:30 0.50 2,210 2,210 TA DRLSUR TRIP LCIR POOH to 2006'. Mix LCM pill while observe well static losses 6bbl/hr. 10:30 11:00 0.50 2,210 2,210 TA DRLSUR LSCIRC LCIR Spot 40bbl 30#/bbl Med CaCo2 10#/bbl Fine CaC02 5#/bbl Gel LCM pill. 11:00 11:30 0.50 2,210 2,210 TA DRLSUR TRIP LCIR POOH to 1630'. (Hole tight 1943' to 1879'. W/R 1879' to 1816') 11 :30 12:30 1.00 2,210 2,210 TA DRLSUR LSCIRC LCIR Spot 40bbl 30#/bbl Med CaCo2 10#/bbl Fine CaC02 5#/bbl Gel LCM pill. Observe well static losses 5bbl/hr. 12:30 15:00 2.50 2,210 2,210 AF DRLSUR TRIP POOH(SLM). LID MWD cartridge. LID Hang-Off sub. (Bit and Stabs balled up) 15:00 15:30 0.50 2,210 2,210 AF DRLSUR RIG Observe well while service rig. Losses 2bbl/hr. 15:30 17:30 2.00 2,210 2,210 AF DRLSUR TRIP RIH to 2127'. 17:30 18:30 1.00 2,210 2,210 AF DRLSUR DRILL W/R F/2127' to 2210'. 18:30 21:30 3.00 2,210 2,210 TA DRLSUR CIRC LCIR Prior to circ. static losses 2bbl/hr. Circ. one bottoms up with minimallosses(550gpm). After 1 bottom up losses increased to 40bbllhr with pumps and 30bbl/hr static. After 3 bottoms up decreased MW F/9.3ppg to 9.2ppg. 21:30 22:30 1.00 2,210 2,210 TA DRLSUR LSCIRC LCIR Mix and pump 40bbl LCM Pill10#/bbllarge CaCo2, 20#/bbl med CaC02, 15#/bbl Fine CaCo2, 5#/bbl Gel. Displace to bit. 22:30 23:00 0.50 2,210 2,210 TA DRLSUR LSCIRC LCIR POOH to 2006'(tight @ 2160'). 23:00 23:30 0.50 2,210 2,210 TA DRLSUR LSCIRC LCIR Mix and pump 40bbl LCM Pill10#/bbllarge CaC02, 20#/bbl med CaC02, 15#/bbl Fine CaC02, 5#/bbl Gel. Displace to bit. 23:30 00:30 1.00 2,210 2,210 TA DRLSUR LSCIRC LCIR While Mix LCM pill observe hole. Static losses 10bbl/hr. Pump 40bbl LCM pill10#/bbl CaCo2 Large, 20bbl CaCo2 Med, 15#/bbl CaCo2 Fine, 5#/bbl gel. Displace to bit. Static losses Printed: 3/12/2003 2:45:11 PM ) ) WELL NAME ABALONE 1 IKB 21.0 FROM TO HRS 23:30 00:30 1.00 00:30 01 :30 1.00 TO SUB 2,210 TA 2,210 TA FROM 2,210 2,210 01 :30 04:30 3.00 2,210 2,210 TA 04:30 06:00 1.50 2,210 TA 2,210 MARATHON OIL COMPANY page 2 of2 DaUy.·prillihs.RépOI1 Exploitation Gas IGL 124 HR PROGITMD 282.00 45.0 2,210 ¡WD 2,100 \DFS6 IDOL 14 IRPT# I DATE 14 05-Feb-2003 OPERATIONS SUMMARY PHASE OP TRBL DRLSUR LSCIRC LCIR DRLSUR LSCIRC LCIR DESCRIPTION DRLSUR LSCIRC LCIR increased to 20bbl/hr. POOH to 1692'. Observe ~ell while mix LCM pill 20#/bbl Cat02 fine, 30#/bbl CaC02 Med, 10#/bbl CaC02 large, 5#/bbl Gel. Static losses decreased to 2bbl/hr. Pump 40bbl pill. Displace tc bit. Observe well while mix LCM pill. Static losses: 02:00 20bbl/hr. 02:30 15bbl/hr. 03:00 20bbl/hr. 03:30 20bbl/hr. 04:00 20bbl/hr. 04:30 20bbl/hr. Pump 30#/bbl MI seal fine LCM pill. Observe well. Losses 1.5bbl/hr. DRLSUR LSCIRC LCIR DENSITY(ppg) FV PV/YP 60 15/22 I PP I WUHTHP 10.01 I ECD 19.261 MUD DATAl DAILY COST I FCIT.SOL OIW %Sand/MBT Ph/13M Pf/Mf 2.0/5.5 I 0.50/22.0 9.0010.1 0.210.8 7633.00 Cl/Ca 300 140 I CUM COST 23407.00 CaCI2(wt%: H2S LIME ES 6RPM 8 9.20 GELS 8/18 BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO; JETS. OR TFA DEPTHIN.DATEIN I-O-D-L-B-G-O-R 8/RR4 17.500 STC MSDGHQC LK1029 18/18/18/1411111I 1,007.0 2/2/2003 3-3-WT -A-E- 2-80- TO 9 IRR4 17.500 STC MSOGHQC LK 1 029 18/18/18/14111111 2,210.0 2/4/2003 0-0------ BIT / RUN WOB RPM GPM PRESS PSIT HRS 24H r DlST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 8 I RR4 15 I 25 60 I 70 550 1,900 321 50.00 21.78 1,203.0 55.23 9 I RR4 I I 557 1,900 BHA !EFFWT. ¡PICKUP SLACKOF1ROTWT. ITORQÙE{~axlmin) IBHAHRS IJARHRS MWDHRSMTRHRS ISSHRS 17.5" STC MSDGHQC, 8" Mach1C/1.2AKO/171/4" UBHS, 171/4" IBS , 8" Collar MWD, 8" Monel DC, 6 5/8" H-90-P X 4 1/2"IF_B , 5" 49.5PPF HWDP (5),61/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWOP (20), 4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP BHANO.. .¡LENGTH 9 881.76 BHA DESCRIPTION NO. MAKE OF PUMP 1 OILWELL 2 OILWELL COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard SERVICE LAST BOP TEST: SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 PUMP fHYDRAULlC DATA STROKE (in) LINER (in) SPM Q{gpm) PRESS. (psi) TOTALQ KILL SPM / PRESSURE 8.000 5.500 120 278.43 1,900 556.86 8.000 5.500 120 278.43 1,900 556.86 PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Baker Hughes Inteq 1 24.00 Epoch Well Services 2 12.00 R&K Industrial 1 24.00 S&R Enterprises 2 24.00 POB @ 06:00: NO. HOURS 2 48.00 2 24.00 4 48.00 1 1.00 SERVICE CASING SUMMARY LAST CASING TEST: MAX SICP MD (tt) (psi) @ (ppg) 170 NEXT BOP TEST: WT (Ibltt) GRADE 133.00 K-55 TVD (tt) 170 BURST (psi) 3,060 CONf\DEN1\ÄL ~f\GH1 t\G'-E Printed: 3/12/2003 2:45:11 PM ') 0'~f~'OEN1\Þ.t C .,~~,.,",O\..E KB ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS I MTS RIH w/cement stinger on 4"DP. OPERATION COMMENTS POOH. UD 17 1/4" stab and BIO 17.5" bit. ') MARATHONOILCQIVIÞANY Dé)ilyDriUingReport Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 2,210 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE TVD I DFS7 2,100 was I DOL I RPT # DATE 15 15 06-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST 907-283-1312 COUNTY/OTHER Kenai DX.02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING \ NEXT CASING 13.375 (in) @ 2,208 (ft) 9.625 (in) @ 4,250 (ft) \ 24 HR FORECAST Cement CSG. NID diverter. Install wellhead. N/U BOPE LEAKOFF RlU to run 13 3/8" CSG. PJSM. Run 13 3/8" CSG. RID CSG tools. Run 4" DP innerstring. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 425.00 None 2/5/2003 1/23/2003 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running CSG. FROM TO HRS 06:00 08:00 2.00 08:00 09:00 1.00 09:00 10:00 1.00 10:00 14:00 4.00 14:00 14:30 0.50 14:30 15:00 0.50 15:00 16:00 1.00 16:00 17:00 1.00 17:00 00:00 7.00 00:00 03:00 3.00 03:00 06:00 3.00 DENSITY(ppg) I FV PVIYP 62 15/19 FROM 2,210 2,210 2,210 2,210 2,210 2,210 2,210 2,210 2,210 2,210 2,210 9.30 GELS 6/14 I PP.I WUHTHP 10.21 TO SUB 2,210 AF 2,210 AF 2,210 AF 2,210 AF 2,210 AF 2,210 AF 2,210 AF 2,210 AF 2,210 AF 2,210 AF 2,210 AF IECDI FCfT.SOL 2.0/6.0 OPERATIONS SUMMARY PHASE OP TRBL DRLSUR TRIP DRLSUR TRIP CSGSUR CSG CSGSUR CSG CSGSUR SAFETY CSGSUR CSG CSGSUR CSG CSGSUR CSG CSGSUR CSG CSGSUR CSG CSGSUR TRIP DESCRIPTION POOH. UD stabs and BIO bit(stabs and bit balled). Stand back motor. Clear floor of 171/2" tools. Remove DP elevators and short bales. RlU to run 13 3/8" CSG. RlU long bales. Adjust top drive torque tube. PJSM prior to running 133/8" CSG. P/U joint#1. Adjust turnbuckles on TO torque tube. Baker Lok stab-in float and M/U into float collar top of joint#1. P/U joint#2 and Baker Lok to stab-in float. Break circulation through Joint#1 and Joint#2. Run 133/8" 68PPF K-55 BTC CSG(total 54joints). Remove bell guide from CSG elev. Land casing w/130K down wt. 160k up wt RID CSG running tools. C/O bales. Install DP elev. Adjust and secure TO torque tube. RlU false rotary to run 4" DP. M/U cement stinger. RIH w/4" DP. ¡MUD DATAl DAILY COST I OIW %Sand/MBT Ph/pM Pf/Mf I 0.75/23.0 8.5010.1 0.1/0.9 3137.00 CI/Ca 300 140 I CUM COST 26544.00 CaCI2(wt%: H2S LIME ES 6RPM 6 BITS JETS OR TFA 18/18/18/141111I1 BIT/RUN SIZE MANUF. TYPE SERIAL NO. 9/RR4 17.500 STC MSDGHQC LK1029 BIT / RUN WOB RPM GPM PRESS 9 / RR4 I P BIT DEPTH IN DATE IN 2,210.0 2/4/2003 I-O-D-L-B-G-Q-R 0-0------ HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP BHA NO. \ LENGTH 9 881.76 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF1ROT WT. I TORQUE (~ax/min) \ BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 17.5" STC MSDGHQC , 8" Mach1C/1.2AK0/17 1/4" UBHS , 17 1/4" IBS , 8" Collar MWD , 8" Monel DC , 65/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (20), 4 1/2"IF-P X Printed: 3/12/2003 2:45:14 PM WELL NAME ABALpNE 1 )) MARATHON OIL. COMPANY ·Pågá2of2 DailyDrilllngR~þort Exploitation. Gas !GL ¡ 24 HR PROGITMD· 282.00 2,210 ¡ þ KB _ 21.0 !TVD I DFS 2,100 7 ~ BHA DESCRIPTION HT..38~B , 4"14PPF S-135 OP aHA COMPANY Inlet Dri\ling ~Ia~ka Marathon r Weaver Brothers (YVBI) M~I Drilling Fluìds Gate Guard þ . Baker Hugh~s Inteq SERVICE LAST BOP TEST: SIZE (in) . 10 (in) SHOETES-IJppg) _ 20.000 18.730 . 13.375 12.4151 PERSONNEL DATA ! NO. 'HOURS I . COMPANY 17 204.00 I~ Epoch Well Services 1 I 24.00 R&K Industrial 2 8.00 S&R Enterprises 1 24.00 (, Weatherford 221 24.00 BJ Services 4~.OO \ CASING SUMMARY LAST CASING TEST: MAX SICP ~D(ft) (psi) @ (ppg) 170 (psi) @ (ppg) 2,208 TVOJft) 170 2,097 K \ Eti1\AL C rTIG~" ,",OLE ,) IDOL 15 SERVICE NEXT BOP TEST: WT (lb/f'!) GRADE 133.00 K~55 68.00 K-55 IRPT# ¡DATE 15 06-Feb-2003 POB @ 06:00: I NO. ¡ HOURS 2 24.00 1 8.00 1 1.00 3 36,00 4 24.00 I BURST (psi) 3,060 3,450 Printed: 3/12/2003 2:45:14 PM ') CÖNf'DE.N11Jt~1ØA~l'HONâILØ~NtÞANY t'G{-ITHOlE. DailYDrmÎI1{JRø~ort - . Exploitation. Gas I GL \24 HR PROG TMD 21.0 282.00 2,210 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 ) RIG PHONE TVD I DFS8 I DOL I RPT # DATE 2,100 16 16 07-Feb-2003 WBS SAPIWBS COST DX02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST 60.0000 I LAST CASING \ NEXT CASING I LEAKOFF 13.375 (in) (á2 2,208 (ft) 9.625 (in) (á2 4,250 (ft) \24 HR FORECAST N/D diverter. Install wellhead. N/U BOPE. Test BOPE. WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS N/D diverter. OPERATION COMMENTS RIH w/cement stinger. Perform innerstring cement job. annulus. Perform top job. N/D diverter. KB 907-283-1312 COUNTY/OTHER Kenai POOH wlcement stinger. Wait on cement. Run 1 1/4" hydril tubing in 20" X 13 3/8" MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 510.00 None 2/6/2003 ACCIDENT DESCRIPTION: SAFETY SUMMARY ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP7 1/23/2003 I LAST RIG INSPECTION SAFETY MTG TOPICS: Cementing safety practices. OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 07:00 1.00 2,210 2,210 AF CSGSUR TRIP RIH w/cement stinger on 4" DP. 07:00 07:30 0.50 2,210 2,210 AF CSGSUR CEMT Sting into the float collar @ 2161'. Break circulation and pump 45bbls mud. 07:30 08:00 0.50 2,210 2,210 AF CSGSUR SAFETY PJSM prior to cementing. 08:00 09:00 1.00 2,210 2,210 AF CSGSUR CEMT R/U cement head and cement line. Pump 25bbls 8.4ppg spacer w/rig pumps. Pump 2bbls water w/BJ unit. Test BJ lines to 2000psi. 09:00 09:30 0.50 2,210 2,210 AF CSGSUR CEMT C/O leaking grease cert on low torque valve with a plug. Test BJ lines to 2000psi. 09:30 11:00 1.50 2,210 2,210 AF CSGSUR CEMT Mix and pump 950sxs Type1 cement w/20%LW-6, 20% MPA-1, 1 % CaCI2, .3% CD-32, 1 % A-2 and 1 ghs FP-6L to yield 411bbls 12ppg slurry. After pumping 285bbls returns were lost. Reduced pump rate and regained partial returns after 325bbls were pumped. Partial returns were observed until cement pumping was stopped(actual cmnt volumes 442bbls/992sxs). Lost total of 168bbls to the hole. Cement fell back after pumping stoped. Filled annulus with 32bbls mud. CIP@11:00hrs. 11:00 12:00 1.00 2,210 2,210 AF CSGSUR CEMT Drop DP wiper plug and displace w/3bbls water from BJ and 18bbls mud from rig. Check floats. UD BJ head. Screw TD into DP and sting out from float collar. Displace DP wiper plug from DP. 12:00 13:30 1.50 2,210 2,210 AF CSGSUR CEMT POOH wlcement stinger. UD stinger. 13:30 19:00 5.50 2,210 2,210 AF CSGSUR WAIT While wac cIa bales and elevators. Organize rig floor and location. 19:00 21:30 2.50 2,210 2,210 TA CSGSUR CEMT CMTL Release CSG from elevators. P/U 1 1/4" hydril tubing. Run to refusal @ 350'. R/U 1502 connection and cement hose. Observe 20" X 13 3/8" annulus to be taking 1 bbl/hr losses 21:30 22:00 0.50 2,210 2,210 TA CSGSUR SAFETY CMTL PJSM prior to doing top job. 22:00 22:30 0.50 2,210 2,210 TA CSGSUR CEMT CMTL Pump 10bbls water ahead. Test BJ lines to 2000psi. Valve Printed: 3/12/2003 2:45:17 PM ) ) WELL NAME ABALONE 1 IKB 21.0 FROM TO HRS 22:00 22:30 0.50 TO SUB 2,210 TA FROM 2,210 22:30 00:00 1.50 2,210 TA 2,210 00:00 01 :00 1.00 01 :00 02:00 1.00 2,210 2,210 2,210 TA 2,210 TA 02:00 03:00 1.00 2,210 2,210 TA 03:00 06:00 3.00 2,210 2,210 AF DEN SITY(ppg) FV PVfYP 62 7/28 I PP I WUHTHP 11.01 ECD FCfT.SOL 2.0/6.0 9.40 GELS 3/8 COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard SERVICE LAST BOP TEST: SIZE(in) ID(in) SHOE TEST(ppg) 20.000 18.730 13.375 12.415 MARATHON ·OIL ·.GOMPANY Page.20f 2 Daily· DrilllngReport ExploitatiònGas IGL 124 HR PROGTMD 282.00 2,210 ITVD 2,100 IDFS8 [DOL 16 IRPT# I DATE 16 07-Feb-2003 OPERATIONS SUMMARY PHASE OP TRBL DESCRIPTION CSGSUR CEMT CMTL malfunctioned during transfer of CaCI to BJ unit. Lost CaCI2 into active system. CSGSUR CEMT CMTL Repair valve in pill pit while wait on CaCI2. PJSM with crew coming on duty. CSGSUR CEMT CMTL Cont. to repair valve in pill pit. CSGSUR CEMT CMTL Mix and pump 335sx Class "G" cement w/2%CaC12 to yield 68bbls 15.8ppg slurry. 20bbls cement to surface. Observe fluid level to be static. CSGSUR CEMT CMTL Flush cement from stack with retarded water. Pull and UD 1 1/4" hydril tubing. CSGSUR NUND N/D diverter line and 21 1/4" diverter. Empty pits. I MUDDATADAILYCOST I OIW %Sand/MBT Ph/pM Pf/Mf I 0.25/18.0 9.00/9.0 10.9 625.00 CI/Ca 300 180 I CUM COST 27169.00 CaCI2(wt%: H2S LIME ES 6RPM 4 PERSONNELDATA NO. HOURS COMPANY 17 204.00 Baker Hughes Inteq 1 24.00 Epoch Well Services 2 8.00 R&K Industrial 1 24.00 BJ Services 2 24.00 AOGCC POB.@ 06:00: NO: HOURS 2 48.00 2 24.00 4 48.00 4 96.00 1 10.00 SERVICE CASING SUMMARY LAST CASING TEST: MAX SICP MD(ft) (psi) @ (ppg) 170 (psi) @ (ppg) 2,208 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 68.00 K-55 TVD (ft) 170 2,097 BURST (psi) 3,060 3,450 C Nf\t)E'[~1\AL . 1\GH1 HOLE Printed: 3/12/2003 2:45:17 PM ) CN:IOe.\tIAl atlGrtT HOLE WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Testing BOPE. OPERATION COMMENTS Cut 13 3/8" CSG. N/D 21 1/4"diverter. joint and test BOPE. Mix mud. Daily Drilling ·Report Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 2,210 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE KB ) Page 1 of1 MARATH()N·· OIL GOMPANY I DFS9 I DOL I RPT # DATE 2,100 17 17 08-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 I DAILY WELL COST I CUM WELL COST l ~ I NEXT CASING I LEAKOFF 9.625 (in) @ 4,250 (ft) TVD MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 13.375 (in) @ 2,208 (ft) \24 HR FORECAST Test BOPE. Drill out. I LAST SAFETY MTG 2/6/2003 TO SUB 2,210 AF 2,210 AF 2,210 AF 2,210 AF IECD Fcrr.SOL 1.0/3.0 SERVICE NRI Install and test 13 5/8" Vetco sliplock wellhead. Empty and clean pits. N/U 13 5/8"-5M BOP. RIU test SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION MANHRS WORKED I ACCIDENT TYPE 417.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 08:30 2.50 FROM 2,210 08:30 12:00 3.50 2,210 12:00 03:30 15.50 2,210 03:30 06:00 2.50 2,210 DENSITY(ppg) I FV PVfYP 50 9/30 9.00 GELS 18/28 I.pp I WUHTHP 6.41 COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard Baker Hughes Inteq LAST BOP TEST: SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 OPERATIONS SUMMARY PHASE OP TRBL CSGSUR NUND CSGSUR NUND DESCRIPTION Rough cut 13 3/8" and UD cut Jnt. Set out diverter stack on stand from sub. Empty pits. Cut off 21 1/4" starting head. Make final cut on 13 3/8" CSG. Tag cement TBGL in 13 3/8" X 20" annulus. Slip on 13 5/8" 5M Vetco Slip Lock Multibowl Wellhead. Test seals to 1200psi/10min. Empty and clean pits. N/U Shaffer 13 5/8" 5M R,S,Rd,A BOP stack. Repair valves in mud pits. CIO damaged brakes on drawworks. Mix mud. R/U test joint. Install test plug. Function BOP. Tighten flange between mud-X and sigle gate. Test upper and lower TO valves, TIW valve, IBOP 250/3000psi 5min. Cont. mix mud. CSGSUR NUND CSGSUR TEST IMUDDATA! DAILYCOST OIW %Sand/MBT Ph/pM Pf/Mf I 9.501 0.4/1.2 8778.00 CI/Ca 2,800 120 ,. CUM COST 35947.00 CãCI2(wt%: H2S LIME ES 6RPM 19 PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Epoch Well Services 1 24.00 R&K Industrial 1 12.00 AOGCC 1 24.00 S&R Enterprises 2 24.00 ABB Vetco Gray 2 48.00 SERVICE POB @ 06:00: NO. HOURS 2 24.00 4 36.00 1 1.00 1 12.00 1 8.00 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) (psi) @ (ppg) 170 (psi) @ (ppg) 2,208 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 68.00 K-55 TVD (ft) 170 2,097 BURST (psi) 3,060 3,450 Printed: 3/12/2003 2:45:20 PM ) c. . .. .NfrJ;:\~I"lAli ... Y¡G~îT FOlE~A:~~::I:~~~~:::NY Exploitation G.as I GL 124 HR PROG TMD 21.0 282.00 2,210 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENTSTATUSIMTS CBU. OPERATION COMMENTS Test BOP. Modify standpipe for third mud pump. R/U centrifuge unit. P/U M. motor and MWD. Test CSG to 1500psi. Drill shoe tract and shoe. CBU. KB ) Page.1.·of'2 TVD 2,100 WBS I DFS I DOL I RPT # DATE 10 18 18 09-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST 907-283-1312 COUNTYIOTHER Kenai DX.02.07227 .CAP .DRL MOC WI NRI I DAILY W,ELL COST 60.0000 I LAST CASING I NEXT C¡'SING 13.375 (in) ~ 2,208 (ft) 9.625 (in) ~ 4,250 (ft) 124 HR FORECAST Per. FIT. Drill 20' new hole. Perform LOT. Drill. MANHRS WORKED I ACCIDENT TYPE 444.00 None ACCIDENT DESCRIPTION: I LAST SAFETY MTG 2/6/2003 SAFETY MTG TOPICS: FROM TO HRS FROM TO SUB 06:00 08:00 2.00 2,210 2,210 AF 08:00 09:30 1.50 2,210 2,210 AF 09:30 10:30 1.00 2,210 2,210 AF 10:30 14:30 4.00 2,210 2,210 AF 14:30 17:00 2.50 2,210 2,210 AF 17:00 22:00 5.00 2,210 2,210 AF 22:00 23:00 1.00 2,210 2,210 AF 23:00 01:00 2.00 2,210 2,210 AF 01:00 02:00 1.00 2,210 2,210 AF 02:00 05:00 3.00 2,210 2,210 AF 05:00 06:00 1.00 2,210 DENSITY(ppg) 9.00 I PP I FV PVNP GELS WUHTHP 78 9/37 22/29 6.21 2,210 AF ¡ECDI FCIT.SOL 1.0/3.0 LEAKOFF P/U 4" DP. RIH to 2065'. Slip and cut drill line. SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION OPERATIONS SUMMARY PHASE OP TRBL CSGSUR TEST CSGSUR DRILL CSGSUR EQUIP CSGSUR EQUIP CSGSUR TRIP CSGSUR TRIP CSGSUR TRIP CSGSUR RIG CSGSUR TEST CSGSUR DRILL CSGSUR CIRC DESCRIPTION Test 4" lower pipe rams, upper variable rams, annular, blind rams, 1-12 CMV, HCR, choke and kill line manual valves, and check valve to 250/3000psi 5min. Pull and LID test plug. M/U 9 5/8" hanger and LJ. LID same. Run wear bushing. cIa bales. Modify standpipe to accommodate third mud pump. Reset HCR control timer. Prep for R/U centifuge unit. cia mud motor. Orient MWD. RIH w/HWDP. R/U centrifuge unit. PU 66jnts 4" DP and rack back in derrick. RI H to 2065'. Slip and cut drill line. Test 13 3/8" CSG 1500psi/30min. Blow down choke manifold. Tag TOC in 133/8" CSG@2160'. Drill Float collars F/2161' to 2165'. Drill Shoe tract and shoe 2165' to 2208'. Circulate Clean IMUD DATAl DAILY COST I OIW %SandIMBT Ph/pM Pf/Mf I 9.50/1.3 0.4/1.2 11325.00 CIICa 2,800 120 I CUM COST CaCI2(wt%; H2S 47272.00 LIME ES 6RPM 23 BITS JETS OR TFA 18/18/18/121111I1 BIT/RUN SIZE MANUF. TYPE SERIAL NO. 10/1 12.250 STC FGXiVC MM3664 BIT / RUN WOB RPM GPM PRESS 10/1 P BIT DEPTH IN DATE IN 2,210.0 2/8/2003 I-O-D-L-B-G-Q-R 2-2-WT-A-E- 1-SD-PR HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP BHA NO. I LENGTH 10 854.47 BHA DESCRIPTION BHA \ EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) \ BHA HRS \ JAR HR8 I MWD HRS I MTR HR8 I S8 HR8 47,000 85,000 60,000 68,000 6,000/4,000 12.25" STC FGXiVC, 8"M1C/12 1/8"UBHS/1.2AKO, 12 1/8" IBS ,8" Collar MWD , Hang-Off Sub, 8" Monel DC, Cross Over, 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2"IF-P X HT-38-B , Printed: 3/12/2003 2:45:22 PM ) co,· r=lJ æN'fiIALMARArHONøJt(ÇOMPANY T:GF·~HOI..E IKB 21.0 WELL NAME ABALONE 1 BHA DESCRIPTION 4" 14PPF S-135DP COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard Baker Hughes Inteq Epoch Well Services SERVICE LAST BOP TEST: SIZE (in) ID(io) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 ') DailyDrillingR¢port Exploitation Gas I GL 124 HR PROGITMD 282.00 2,210 ITVD I DFS I DOL I RPT # I DATE 2,100 10 18 18 09-Feb-2003' BHA PERSONNEL DATA NO. HOURS COMPANY ~SERVICE 17 204.00 R&K Industrial 1 24.00 S&R Enterprises Sand 2 20.00 ABB Vetco Gray 1 24.00 AOGCC 2 24.00 M-I Drilling Fluids Cent 2 48.00 Alaska Petroleum Contra 2 24.00 POB @ 06:00: NO, HOU~S 4 24.00 1 8.00 1 8.00 1 4.00 2 16.00 2 16.00 CASING SUMMARY LAST CASING TEST: MAX SICP MD(ft) (psi) @ (ppg) 170 (psi) @ (ppg) 2,208 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 TVD (ft) 170 2,097 BURST (psi) 3,060 3,450 Printed: 3/12/2003 2:45:22 PM ) CQI~t~ ENTIAl)~~r~AtFHGN()ILeGMP~Y JIG ;..,'THOlE WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drilling ahead ~ 3025'. OPERATION COMMENTS Perform FIT to 11.5. Drill F/2210' to 2230'. MANHRS WORKED I ACCIDENT TYPE 405.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 07:00 1.00 FROM 2,210 ) D·aily....·.O.rill..i·ng..· .·Repo.·rt .. E:xploitationGas I GL 124 HR PROG TMD 21.0 282.00 815.0 3,025 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE KB TVD I DFS I DOL I RPT # DATE 2,878 11 19 19 10-Feb-2003 WBS SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 I DAILY WELL COST I CUM WELL COST I NEXT CASING I LEAKOFF 9.625 (in) ~ 4,250 (ft) 14.51 MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 13.375 (in) ~ 2,208 (ft) 124 HR FORECAST Drill ahead. NRI Perform LOT to 14.5ppg. cIa grabber dies. Drill F/2230' to 3025'. SAFETY SUMMARY I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 2/6/2003 1/23/2003 N I LAST RIG INSPECTION TO SUB 2,210 AF OPERATIONS SUMMARY PHASE OP TRBL CSGSUR TEST DESCRIPTION Perform FIT to 11.5ppg(pressured up to 250psi w/9.3ppg mud. (Bled off 30psi in 10min). Blow down choke manifold. Clean pill pit. cIa to 9.0ppg Flopro mud. Dir drill and survey F/2210' to 2230'(AST=.4hrs). Circ. and condo mud for LOT. Perform LOT to 14.5 PPG EMW(9.0ppg mud 600psi bled down to 450psi in 10min). Blow down choke manifold. CIO grabber dies in TDS. Dir drill and survey F/2230' to 3025'(ART=6.05hrs AST=5.25hrs ). 07:00 10:30 3.50 2,210 2,210 AF CSGSUR MUD 10:30 11:00 0.50 2,210 2,230 AF CSGSUR DRILL 11:00 12:00 1.00 2,230 2,230 AF CSGSUR CIRC 12:00 13:00 1.00 2,230 2,230 AF CSGSUR TEST 13:00 13:30 0.50 2,230 2,230 TA DRLlN1 RIG TOPS 13:30 06:00 16.50 2,230 3,015 AF DRLlN1 DRILL I:)E;NSITY~ppg) I FV PVNP 80 11/32 9.20 GELS 18/24 Ipp I WUHTHP 6.81 ECDI9.50 IMODDATAIDAILYCOST I 11410.00 FCrr.SOL OIW %Sarid/MBT Ph/pM Pf/Mf CIICa 1.0/3.5 I 0.25/2.0 9.50/1.5 0.4/1.3 28,500 /100 CUM'(X)ST 58682.00 CaCI2(wt%;· H2S LIME ES 6RPM 19 BITS BIT/RUN SIZE MANUF. lYPE SERIAL NO, JETS· OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 10/1 12.250 STC FGXiVC MM3664 18/18/18/12/11/1/ 2,210.0 2/8/2003 2-2-WT-A-E- 1-SD-PR BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DlST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 10/1 15 I 20 75 I 75 510 1,400 301 11.70 815.0 69.66 11.70 815.0 69.66 BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. ¡TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 47,000 110,000 70,000 85,000 8,000/6,000 12.25" STC FGXiVC , 8"M1C/12 1/8"UBHS/1.2AKO, 121/8" IBS 18" Collar MWD , Hang-Off Sub, 8" Monel DC , Cross Over, 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2"IF-P X HT-38-B , 4" 14PPF S-135 DP BHA NO. .\ LENGTH 10 854.47 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP OILWELL OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 5.500 110 255.23 1,400 8.000 5.500 110 255.23 1,400 TOTAL Q 510.46 510.46 KilL SPM / PRESSURE 60 260 60 260 Printed: 3/12/2003 2:45:25 PM ) ) c . \I.,? I.. E \tIAl~J\::~~:I~~:~~:::NY :Ii2 HT ~ 21.0 IGL::::ital:~;;~:GiTM~,025 MUD GAS AVG. TRIP: MAX. TRIP: TVD I DFS 2,878 11 IDOL 19 I RPT # I DATE 19 10-Feb-2003 UNITS AVG. CONN: MAX. CONN: AVG. BKGRD: MAX. DRL: ... 28 60 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 2,231 23.90 185.80 2,118.72 560.44 -553.96 -85.00 1.23 2,607 14.00 191.10 2,4 70.95 690.34 -683.09 -100.10 3.88 2,295 23.50 185.50 2,177.32 586.12 -579.56 -87.53 0.65 2,669 12.60 187.10 2,531.29 704.59 -697.16 -102.38 2.70 2,357 22.30 185.50 2,234.44 610.20 -603.57 -89.84 1.94 2,731 10.60 187.90 2,592.02 717.05 -709.52 -104.00 3.24 2,419 21.20 185.10 2,292.02 633.12 -626.45 -91.96 1.79 2,793 8.40 189.30 2,653.16 727.29 -719.64 -105.51 3.57 2,482 19.20 186.90 2,351.14 654.84 -648.08 -94.22 3.32 2,855 6.80 188.30 2,714.62 735.48 -727.74 -106.77 2.59 2,545 16.40 190.40 2,411.12 674.09 -667.12 -97.07 4.76 2,918 6.00 189.70 2,777.23 742.51 -734.68 -107.87 1.29 COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard SERVICE PERSONNELDATA NO, HOURS COMPANY 17 204.00 Baker Hughes Inteq 1 24.00 Epoch Well Services 1 5.00 R&K Industrial 1 24.00 M-I Drilling Fluids 2 24.00 SERVICE PQB@06:00: NO. HOURS 2 48.00 2 24.00 3 36.00 2 16.00 Cent LAST BOP TEST: SIZE (in) ID(ih) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 14.51 CASING SUMMARY LAST CASING TEST: MAXSICP MD(ft) (psi) @ (ppg) 170 1,580 (psi) @ (ppg) 2,208 TVD(ft) 170 2,097 NEXT BOP TEST: WT.(lb/ft) GRADE 133.00 K-55 68.00 K-55 BURST (psi) 3,060 3,450 RECEIVED MAY 13 2003 Alaeka œ & Gas Cons. Commiwion And\«~ Printed: 3/12/2003 2:45:25 PM ) 0\· F'·D.~N'·'At~"t~~~Ø'L.Q~~~A~Y '7"IG FTHOl£ .. Ð<!~þ~t::~t7:n~~ort WELL NAME KB I GL 124 HR PROG TMD ABALONE 1 21.0 282.00 640.0 3,665 SUPERVISOR RIG NAME & NO. AUTH MD R C. Lawson GLACIER DRILLING 1 FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENTSTATUS/MTS Drilling ahead(âl3665'. OPERATION COMMENTS Drill F/3025' to 3346'. CBUX2. ) Pagètof2 TVD I DFS I DOL I RPT # DATE 3,524 12 20 20 11-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 I DAILY WELL COST I CUM WELL COST - I NEXT CASING I LEAKOFF 9.625 (in) (âl4,250 (ft) 14.51 MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 13.375 (in) (âl 2,208 (ft) 124 HR FORECAST Drill ahead. NRI POOH to CSG shoe. Install breaker for new pump house. Service rig. RIH. Drill F/3346' to 3665'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 427.00 None 2/6/2003 1/23/2003 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FRÖM TQ HRS 06:00 15:30 9.50 FROM 3,025 15:30 17:00 1.50 17:00 18:00 1.00 18:00 19:00 1.00 19:00 19:30 0.50 19:30 20:00 0.50 20:00 06:00 10.00 DENSlry(ppg)I 9.35 FV, PVfYP .GEL.S 49 11/27 18/23 3,346 3,346 3,346 3,346 3,346 3,346 Ipel WUHTHP 9.01 TO SUB 3,346 AF OPERATIONS SUMMARY PHASE OP TRBL DRLlN1 DRILL DESCRIPTION Dir drill and survey F/3025' to 3346'(ART=4.98hrs AST=1.98hrs). DRLlN1 CIRC CBUX2. DRLlN1 TRIP POOH to CSG shoe(hole slick). DRLlN1 RIG Install electrical breaker for new pump house. DRLlN1 RIG Service rig. DRLlN1 TRIP RIH to 3346'. DRLlN1 DRILL Dir drill and survey F/3346' to 3665'(ART=7.86hrs AST=Ohrs). I EÇD 19.61 IMUDDÄ TA DAII..YCösr.1 8290.00 CYNlCOST 66972.00 FC{J'.$QL OIW o;.Saod/MBT Ph/pM Pf/Mf CI/Ca. CaCI2(wt%: ... H2S LIME ES 6RÞM 2.0/5.0 1/94 0.50/3.0 9.20/1.2 0.3/1.1 34,000/80 17 3,346 AF 3,346 AF 3,346 AF 3,346 AF 3,346 AF 3,665 AF BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS ORTFA DEPTH IN DATE IN I"O-D-L-B-G-O-R 10/1 12.250 STC FGXiVC MM3664 18/18/18/12111//1 2,210.0 2/8/2003 2-2-WT-A-E- 1-SD-PR BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 10/1 15 1 30 70 1 77 520 1,700 318 14.80 640.0 43.24 26.50 1,455.0 54.91 BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 47,000 115,000 75,000 90,000 12,000/6,000 12.25" STC FGXiVC, 8"M1C/121/8"UBHS/1.2AKO, 121/8" IBS ,8" Collar MWD , Hang-Off Sub, 8" Monel DC, Cross Over, 5" 49.5PPF HWDP (5), 61/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2"IF-P X HT-38-B , 4" 14PPF S-135 DP BHA NO. I LENGTH 10 854.47 BHA DESCRIPTION NO. MAKE OF PUMP 1 OILWELL 2 OILWELL AVG. CONN: MAX. CONN: PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 5.500 116 269.15 1,700 524.38 8.000 5.500 110 255.23 1,700 524.38 KILL SPM / PRESSURE 60 280 60 280 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 30 AVG. BKGRD: MAX. DRL: 30 505 Printed: 3/12/2003 2:45:28 PM ) c .. \ ·.FrDel\rTIÄh~RA11t1·G)NÔIL..·CØMP~'( -:: G [":rHOtEDa~~p~J:J2t¡jn~~Ort IGL \24 HR PROGITMD 282.00 640.0 3,665 -) WELL NAME ABALONE 1 IKB 21.0 ITVD IDFS IDOL IRPT# ¡DATE 3,524 12 20 20 11-Feb-2003 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EJW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EJW CUM DOGLEG 2,980 5.60 184.80 2,838.91 748.76 -740.89 -108.67 1.03 3,356 1.00 154.90 3,214.37 766.95 -758.76 -112.04 1.48 3,042 4.20 182.60 2,900.68 754.04 -746.17 -109.02 2.28 3.417 1.10 143.30 3,275.3G' 767.80 -759.71 -111.47 0.38:~ 3,105 3.30 191.80 2,963.54 758.14 -750.25 -109.50 1.71 3.481 0.80 132.40 3,339.35 768.4 7 -760.51 -110.77 0.55 3,169 2.40 204.50 3,027.47 761.27 -753.27 -110.43 1.71 3,543 0.90 154.40 3.401.34 769.11 -761.24 -110.24 0.55 3,231 2.40 198.50 3,089.41 763.80 -755.68 -111.38 0.41 3,611 0.60 161.20 3.469.33 769.86 -762.06 -109.90 0.46 3,294 1.30 199.50 3,152.38 765.81 -757.61 -112.04 1.75 COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard SERVICE PERSONNEL DATA NO~ HOURS COMPANY 17 204.00 Baker Hughes Inteq 1 24.00 Epoch Well Services 2 18.00 R&K Industrial 1 24.00 M-I Drilling Fluids 2 24.00 S&R Enterprises SERVICE POB·@06:00: NO, HOURS 2 48.00 2 24.00 3 36.00 2 24.00 1 1.00 Cent LAST BOP TEST: SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 14.51 CASING SUMMARY LAST CASING TEST: MAX SICP MD(ft) (psi) @ (ppg) 170 600 (psi) @ 9.00 (ppg) 2,208 TVD (ft) 170 2,097 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 BURST· (psi) 3,060 3,450 Printed: 3/12/2003 2:45:28 PM ) Q'Oi ....... .............. it: r\.....=..,......... ·..·-r..·.I·Ail;... ... ................ ..... .ii. . . ... . . », \ ...,1 I.J.I.,. ..,~~)MJ!¡RA1J1H(j)N(j)IL:G~~P~~y 11Gh r HOlE WELL NAME ABALONE 1 SUPERVISOR R C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS RIH. OPERATION COMMENTS Drill F/3665' to 3900'. CBUX3. POOH to 3400'. CBUX2. Cont. POOH wet. CIO bit. RIH to CSG shoe. Repair pipe grabbers on TDS. RIH to 3158'. MANHRS WORKED I ACCIDENT TYPE 421.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 12:30 6.50 12:30 15:00 2.50 15:00 16:30 1.50 16:30 18:00 1.50 18:00 21:00 3.00 21 :00 22:00 1.00 22:00 00:00 2.00 00:00 05:00 5.00 05:00 06:00 1.00 DENSITY(ppg) I FV PVIYP 46 11/24 FROM 3,665 3,900 3,900 Déli1y.. Drillir1g~~pbrt ExploitatiohG~s I GL 124 HR PROG TMD 21.0 282.00 235.0 3,900 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE KB ) TVD 3,759 WBS IDFS IDOL 13 21 I RPT # DATE 21 12-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST 907-283-1312 COUNTY/OTHER Kenai DX.02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 13.375 (in) @ 2,208 (ft) 9.625 (in) @ 4,250 (ft) 124 HR FORECAST Drill ahead to TO. Condition hole. Log. LEAKOFF 14.51 I LAST SAFETY MTG 2/6/2003 SAFETY·SUMMARY ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 1/23/2003 I LAST RIG INSPECTION TO SUB 3,900 AF 3,900 AF 3,900 AF OPERATIONS. SUMMARY PHASE dp TRBL DRLlN1 DRILL DRLlN1 CIRC DRlIN1 TRIP DESCRIPTION Dir drill and survey F/3665' to 3900'(ART=6.08hrs). CBUX3 while repair trip tank pump. POOH wet to 3400'. Tight @ 3685',3680',3655. W/R 3657' to 3597'. Tight @ 3575'. W/R 3590' to 3534'. Tight @ 3528'. W/R 3530' to 3475'. Tight @ 3465'. W/R 3469' to 3414'. Tight @ 3355'. W IR 3490' to 3350'. CBUX2@3400'. Cont. POOH wet. B/O bit. M/U new 12 1/4" bit. RIH to CSG shoe. Repair pipe grabbers on TDS. RIH to tight spot @ 3158'. ECDI9.50 \MUDDATADAILYCOST 17460.00 Fcrr.SOL OIW %Sand/MBT Ph/13M Pf/Mf CIICa 2.0/4.0 1/95 0.50/10.0 9.0010.7 0.310.9 28,000/60 CUM COST 84432.00 CaCI2(wt'Yo;. H2S LIME ES ·6RPM 16 DEPTH IN DATEIN 2,210.0 2/8/2003 3,900.0 2/12/2003 I-O-D-L-B-G-O-R 2-2-WT -A-E- 1-SD-PR 2-2-WT-A-E- (-NO-TO 3,900 3,900 AF DRLlN1 CIRC 3,900 3,900 AF DRLlN1 TRIP 3,900 3,900 AF DRlIN1 TRIP 3,900 3,900 AF DRlIN1 TRIP 3,900 3,900 TA DRlIN1 RIG TOPS 3,900 3,900 AF DRlIN1 TRIP 9.25 GELS 16/20 pp I WU!-4T!-4P 8.41 BITS JETS OR TFA 18118/18/12111111 18/18/18/12111111 P BIT 318 HRS 6.08 24Hr DIST 235.0 24Hr ROP 38.65 CUM HRS CUM DEPTH CUM ROP 32.58 1,690.0 51.87 BITIRUN SIZE MANUF. TYPE SERIAL NO. 10/1 12.250 STC FGXiVC MM3664 11/1 12.250 STC FGXiVC MM3272 BIT 1 RUN WOB RPM GPM PRESS 10/1 15 I 30 70 I 77 520 1,700 11 11 I I 510 1,700 BHA I EFF WT. I PICK UP I SLACK OF~ ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 47,000 115,000 75,000 I 90,000 12,000 I 6,000 12.25" STC FGXiVC, 8"M1C/12 1/8" UBHS/1.2AKO ,121/8" IBS ,8" Collar MWD ,8" Hang Off Sub, 8" Monel DC , 6 5/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (5),61/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP BHA NO. I LENGTH 11 854.47 BHA DESCRIPTION Printed: 3/12/2003 2:45:31 PM QN;~:!)E~.l TlGH THOLE WELL NAME ABALONE 1 NQ MAKE OF PUMP 1 OILWELL 2 OILWELL AVG. CONN: MAX. CONN: MD 3,668 3,730 INCL 1.10 0.90 COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) M-I Drilling Fluids Gate Guard Baker Hughes Inteq LAST BOP TEST: SIZE (in) ID (ill) SHOETEST(ppg) 20.000 18.730 13.375 12.415 14.51 ) IKB 21.0 Dai··I¥.·...·Dri.I·I··i n..~.·..·....·.~~·þOrt Exploitation· Gas IGL \24 HR PROGTMD 282.00 235.0 3,900 ITVD IDFS IDOL 3,759 13 21 I RPT # I DATE 21 12-Feb-2003 PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 5.500 110 255.23 1,700 51 Q.46 8.000 5.500 110 255.23 1,700 510.46 MUD GAS AVG. TRIP: MAX. TRIP: SURVEY·DATA N/S CUM E/W CUM DOGLEG MD INCL -762.84 -109.58 0.88 3,793 1.00 -763.84 -109.18 0.34 3,855 1.10 PERSONNEL DATA NO, HOURS COMPANY 17 204.00 Epoch Well Services 1 24.00 R&K Industrial 2 6.00 M-I Drilling Fluids 1 24.00 S&R Enterprises 2 24.00 Smith International 2 48.00 CASING SUMMARY LAST CASING TEST: MAX SICP MD(ft) (psi) @ (ppg) 170 600 (psi) @ 9.00 (ppg) 2,208 30 AZIMUTH 177 .40 174.90 KILL SPM / PRESSURE 60 280 60 280 UNITS AVG, BKGRD: MAX. DRL: 30 505 TVD VS N/S CUM Ef\NCUM DO(3LEG 3,651.31 772.49 -764.86 -108.99 0.48 3,713.30 773.60 -765.99 -108.91 0.18 SERVICE POB@06:00: NO, HOÜRS 2 24.00 3 36.00 2 24.00 1 1.00 1 6.00 Cent TVD (ft) 170 2,097 NEXT BOP TEST: WT (Ibltt) GRADE 133.00 K-55 68.00 K-55 BURST (psi) 3,060 3,450 Printed: 3/12/2003 2:45:31 PM COI\,-:J;3r;.~1., TIGHt HOLE WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Wipe hole to 13-3/8" casing shoe. OPERATION COMMENTS FTFNB. Drill f/3900' to 4350' MD. Wipe hole to shoe. MANHRS WORKED I ACCIDENT TYPE 436.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM 06:00 06:30 07:00 08:00 10:30 00:30 01:30 TO HRS 06:30 0.50 07:00 0.50 08:00 1.00 10:30 2.50 00:30 14.00 01:30 1.00 04:30 3.00 FROM 3,900 3,900 3,900 3,900 3,900 4,350 4,350 04:30 05:30 1.00 4,350 05:30 06:00 0.50 4,350 DENSITY(pp!;¡) 9.35 IpPI FV PV/YP GELS WUHTHP 51 11/28 13/23 8.5/ Dai lV' Drilling . Report . ExploitatiqnGas I GL 124 HR PROG TMD 21.0 282.00 450.0 4,350 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 907-283-1312 COUNTY/OTHER Kenai KB RIG PHONE I LAST SAFETY MTG 2/6/2003 TO SUB 3,900 AF 3,900 AF 3,900 AF 3,900 AF 4,350 AF 4,350 AF 4,350 AF 4,350 AF 4,350 AF ') IViARATHONOIL¢QMPÄN'{ TVD 4,208 WBS I DFS I DOL I RPT # DATE 14 22 22 13-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST DX.02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASI 13.375 (in) (á2 2,208 (ft) 9.625 (in) @ 4,250 (ft) 124 HR FORECAST TIH. Circ. POOH. Run open hole logs. LEAKOFF 14.51 SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/8/2003 1/23/2003 I LAST RIG INSPECTION OPERATIONS SUMMARY PHASE OP TRBL DESCRIPTION DRLlN1 TRIP TIH to 3472' MD. DRLlN1 TRIP W/R f/3472' to 3534' MD. DRLlN1 CIRC Circulate and Condition Hole. DRLlN1 TRIP W/R f/3534' to 3900' MD. DRLlN1 DRILL Drill f/ 3900' to 4350' MD. (ART 11.65) DRLlN1 CIRC Circulate and Condition Hole for wiper trip. DRLlN1 TRIP Wiper trip. Back Ream f/4221' to 2848' MD. Hole tight & sticky. DRLlN1 TRIP FPOOH to shoe. DRLlN1 RIG Service Rig IECD 19.58MÜDDATADAILYÇ()SII 8610.00 FCIT.SOL OIW o/.sand/MBT Ph/pM Pf/Mf CIICa 2.0/5.0 / 0.30/8.0 8.5010.6 0.1/0.8 26,000/400 I CUM COST 93042.00 CaCI2(wt%: . H2S LIME ES 6RPM BITS BIT/RUN ·SIZE MANUF. TYPE SERIAL NO, JETSORTFA DEPTH IN DATEIN I-O-D-L-B-G-O-R 11 11 12.250 STC FGXiVC MM3272 18/18/18/12//111/ 3,900.0 2/12/2003 2-2-WT-A-E- I-NO-TD BIT 1 RUN WOB RPM GPM PRESS P BIT HRS 24Hr DlST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 11 / 1 20 / 30 75/ 80 551 1,550 356 14.00 450.0 32.14 14.00 450.0 32.14 BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS o 125,000 80,000 100,000 6/12 12.25" STC FGXiVC, 8"M1C/12 1/8" UBHS/1.2AKO , 12118" IBS, 8" Collar MWD, 8" Hang Off Sub, 8" Monel DC, 6 5/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP BHA NO. I LENGTH 11 854.47 BHA DESCRIPTION NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 5.500 115 275.35 1,550 550.70 8.000 5.500 115 275.35 1,550 550.70 KILL SPM 1 PRESSURE 60 300 60 300 Printed: 3/12/2003 2:45:34 PM ) ) Páge.2óf2 CO" I nEti.TTIA·r M~RATHØN01LCOMPANY . .. ~·ul'.r., !~~1HT ~B 21.0 AVG, CONN: MAX. CONN: MD INCL 3,917 1.20 3,980 1.40 4,041 1.10 4,103 1.40 AZIMUTH 171.10 160.20 160.90 141.90 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq TVD 3,775.29 3,838.27 3,899.26 3,961.24 VS 774.79 776.10 777.26 778.31 SERVICE LAST BOP TEST: 2/8/2003 SIZE (in) lOOn) SHOI2 TEST (ppg) 20.000 18.730 13.375 12.415 14.51 DallyD rilling.· Report Exploitation Gas IGL 124 HR PROGITMD 282.00 450.0 4,350 MUD GAS AVG. TRIP: MAX. TRIP: 42 SURVEY DATA N/S CUM E/W CUM DOGLEG MD INCL -767.23 -108.76 0.20 4,166 1.50 -768.60 -108.39 0.50 4,229 1.60 -769.86 -107.95 0.49 4,290 1.30 -771.01 -107.29 0.82 4,350 1.30 AZIMUTH 150.70 139.40 135.50 135.50 PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Epoch Well Services 1 24.00 R&K Industrial 2 48.00 M-I Drilling Fluids 2 24.00 S&R Enterprises 2 48.00 CASING SUMMARY LAST CASING TEST: MAXSICP MD(ft) (psi) @ (ppg) 170 600 (psi) @ 9.00 (ppg) 2,208 TVO (ft) 170 2,097 IrvD I DFS I DOL 4,208 14 22 AVG. BKGRD: MAX. DRL: ~ TVD VS 4,024.22 779.48 4,087.20 780.69 4,148.18 781.66 4,208.16 782.47 SERVICE Cent I RPT # I DATE 22 13-Feb-2003 UNITS 13 224 J¡ N/S CUM EfW CUM DOGLEG -772.34 -106.41 0.39 -773.73 -105.43 0.51 -774.87 -104.39 0.52 -775.84 -103.44 0.00 POB@06:00: NO, HOURS 4 48.00 2 24.00 2 14.00 2 2.00 NEXT BOP TEST: .... WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 2/15/2003 BURST (psi) 3,060 3,450 Printed: 3/12/2003 2:45:34 PM ) CO f(t:I....~ a\ TIA~~R.ðimHâN OILCOMPANY r~ GhJE" OLE Pagè·fÒf2 WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENTSTATUS/MTS Circulate & condition hole for 9-5/8" casing. OPERATION COMMENTS TIH. Condition mud. POOH. Run open hole logs. TIH. KB Daily···DrillingRêport Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 4,350 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE 907-283-1312 COUNTY/OTHER Kenai TVD I DFS I DOL I RPT # DATE 4,208 15 23 23 14-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST 60.0000 ,_, . I LAST CASING I NEXT CASING I LEAKOFF 13.375 (in) ~ 2,208 (ft) 9.625 (in) ~ 4,250 (ft) 14.51 124 HR FORECAST POOH. Run & cement 9-5/8" casing. Condition hole for casing. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 457.00 None 2/13/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Chocking casing on racks, tripping hazards, open hole logging, weUslippery location SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/8/2003 1/23/2003 I LAST RIG INSPECTION OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 06:30 0.50 4,350 4,350 AF DRLlN1 RIG Service Rig 06:30 07:30 1.00 4,350 4,350 AF DRLlN1 TRIP TIH. Tight hole f/4040' to 4273' MD. Tag fill @ 4339' MD. 07:30 08:00 0.50 4,350 4,350 AF DRLlN1 TRIP Fill pipe. W/R f/4339' to 4350' MD. 08:00 10:00 2.00 4,350 4,350 AF DRLlN1 CIRC Circulate and Condition Hole for open hole logs. 10:00 14:30 4.50 4,350 4,350 AF DRLlN1 TRIP Pump slug. POOH for open hole logs. SLMOOH. No correction. 14:30 15:30 1.00 4,350 4,350 AF DRLlN1 TRIP LD MWD, motor, bit. Stand back 8" monels. 15:30 20:00 4.50 4,350 4,350 AF EV AL 1 LOG RU loggers. PJSM. RIH wi PEXlAITH tool. WL TO 4346' MD. Run PEXlAITH log f/4346' to 150'. POOH. 20:00 21:00 1.00 4,350 4,350 AF EV AL 1 LOG LD PEXlAITH tool, PU DSI/GR tool. 21:00 00:00 3.00 4,350 4,350 AF EV AL 1 LOG RIH wI DSI/GR tool. Run DSI/GR log f/4346' to 2245'. POOH. 00:00 00:30 0.50 4,350 4,350 AF EV AL 1 LOG RD loggers. 00:30 02:30 2.00 4,350 4,350 AF CSGIN1 TRIP MU BHA. PU bit, stablizer. 02:30 04:30 2.00 4,350 4,350 AF CSGIN1 TRIP TIH to condition for casing. 04:30 05:00 0.50 4,350 4,350 AF CSGIN1 TRIP Fill pipe. W/R f/4272' to 4310' MD. CO fill f/4347' to 4350' MD. 05:00 06:00 1.00 4,350 4,350 AF CSGIN1 CIRC Circulate and Condition Hole for 9-5/8" casing. COMMENTS Strap & drift 110 jts, 9-5/8", 40 ppf, L-80, BTC casing (OAL 4515.50'). Install 4" liners in #3 pump. Installed drillers console controls for #3 pump. DENSITY(ppg) I 9.45 I PP I I ECD 19.671 MUD DATAl DAilY COST I 2039.00 I CUM COST 95081.00 FV PVNP GELS WUHTHP FCIT.SOl OIW %Sand/MBT Ph/pM Pf/Mf CI/Ca CaCI2(wt%: H2S LIME ES 6RPM 48 11/26 14/23 8.81 2.0/4.0 I 0.25/7.5 8.5010.1 0.110.6 28,000/400 BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-l-B-G-Q-R 11 11 12.250 STC FGXiVC MM3272 18/18/18/12111111 3,900.0 2/12/2003 2-2-WT-Ä-E- I-NO-TD 12/RR1 12.250 STC FGXiVC MM3272 18/18/18/12111111 4,350.0 2/14/2003 2-2-WT-A-E-I-NO-CM BIT / RUN WOB RPM GPM PRESS P BIT HRS 24Hr DlST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 11 11 20 I 30 75 I 80 551 1,550 356 32.14 14.00 450.0 32.14 Printed: 3/12/2003 2:45:36 PM ) c .. "cfD.~\10IAlM'~RA'I'HøNiø'Lø~MPAN¥ T~ G ~ THOlE [)â~~::::2t~:n~:ort WELL NAME I KB I GL 124 HR PROG I TMD ABALONE 1 21.0 282.00 4,350 ') TVD I DFS I DOL 4,208 15 23 RPT# DATE 23 14-Feb-2003 BIT I RUN 12 1 RR1 WOB 1 RPM 70 1 80 GPM 540 PRESS 1 ,400 PBIT 346 HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CU M ROP BHA NO. LENGTH 12 830.78 BHA DESCRIPTION BHA EFF ~T. P~~~,~~O IS~b~606FF~~~~~Ò ITOR~~~¿~~~~~) BHAHRS JAR HRS MWD HRS MTR HRS SS HRS 12.25" STC FGXiVC , Bit Sub, 121/8" IBS, 8" Monel DC, 12" IBS , 8" Monel DC, Cross Over, 5" 49.5PPF HWDP (5), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP NQ MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP! HYDRAULIC DATA STROKE (in) LINER (in) SPM Q(gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 8.000 5.500 115 275.35 1,400 550.70 8.000 5.500 115 275.35 1,400 550.70 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq Epoch Well Services SERVICE PERSONNEL DATA NO. HOURS COMPANY. SERVICE 17 204.00 M-I Drilling Fluids Cent 7 42.00 Schlumberger 1 24.00 Atigun 2 24.00 BJ Services 2 48.00 Weaver Brothers (WBI) 3 36.00 POB @06:00: NO,HOURS 1 8.00 3 48.00 2 12.00 3 9.00 1 2.00 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) (psi) @ (ppg) 170 600 (psi) @ 9.00 (ppg) 2,208 LAST BOP TEST: 2/8/2003 SIZE(in) ID(in) SHOETEST(ppg) 20.000 18.730 13.375 12.415 14.51 TVD (ft) 170 2,097 NEXT BOP TEST: WI (lb/ft) GRADE 133.00 K-55 68.00 K-55 2/15/2003 BURST (psi) 3,060 3,450 Printed: 3/12/2003 2:45:36 PM ) CQNF'DEI\TIAl, rlGfiTf(OlE ) MÞtRAT'HONOILCOMPANY Ðai lyQrilllngRèport Exploitation.··Gas I GL \24 HR PROG TMD 21.0 282.00 4,350 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE TVD I DFS I DOL I RPT # DATE 4,208 16 24 24 15-Feb-2003 WBS SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 MOC WI NRI I DAILY WELL COST CUM WELL COST 60.0000 I LAST CASING I NEXT CASING . 9.625 (in) <æ 4,336 (ft) 3.500 (in) <æ 10,140 (ft) 124 HR FORECAST Set pack off, clean mud pits, change rams, test BOPE. KB 907-283-1312 COUNTY/OTHER Kenai SAFETY MTG TOPICS: Running casing, cementing casing. WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENTSTATUS/MTS Displace cement. OPERATION COMMENTS Condition hole for casing. POOH. Run & cement 9-5/8" casing. Displacing cement at report time. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT 486.00 None 2/13/2003 2/812003 1/23/2003 ACCIDENT DESCRIPTION: FRo.M TO. HRS 06:00 08:00 2.00 FRo.M 4,350 LEAKOFF I ~EGULATORY INSP? I LAST RIG INSPECTION TO. SUB 4,350 AF OPERATIONS····SUMMARY PHASE o.P TRBL CSGIN1 CIRC 08:00 12:00 4.00 4,350 4,350 AF CSGIN1 TRIP 12:00 13:00 1.00 4,350 4,350 AF CSGIN1 TRIP 13:00 15:00 2.00 4,350 4,350 AF CSGIN1 NUND 15:00 17:00 2.00 4,350 4,350 AF CSGIN1 CSG 17:00 23:00 6.00 4,350 4,350 AF CSGIN1 CSG 23:00 00:00 1.00 4,350 4,350 AF CSGIN1 CIRC 00:00 02:00 2.00 4,350 4,350 AF CSGIN1 CSG 02:00 04:00 2.00 4,350 4,350 AF CSGIN1 CIRC 04:00 06:00 2.00 4,350 4,350 AF CSGIN1 CEMT DESCRIPTlo.N Circulate and Condition Hole for 9-5/8" casing. Mix & pump dry job. POOH to run 9-5/8" casing. LD BHA (bit & DC's). Install 9-5/8" rams in upper carrier. Test door seals to 250 psi low/3000 psi high, ok. Pull wear bushing. RU to run 9-5/8" casing. Run 9-5/8", 40 ppf, L-80, BTC casing to 13-3/8" shoe. Break circulation & circulate hole. Ran 110 joints (4336.31') 9-5/8", 40 ppf, L-80, BTC casing. Bottom of shoe at 4336' MD, top of collar at 4251' MD. Circulate casing prior to cementing. PJSM. Test surface lines to 3000 psi. Drop bottom plug. Mix & pump 40 bbls MCS-4 preflush ahead of cement, weight 10.0 ppg. Mix & pump 135 sx (60 bbls) Class 'G' + 18% LW-6 + 0.4% CD-32 + 1.0 gal/100 sx FP-6L + 20% MPA-1 + 0.2% R-3lead slurry, weight 12.0 ppg, 2.49 cf/sk yield, followed by 550 sx (180 bbls) Class 'G' + 0.4% CD-32 + 1.0 gal/100 sx FP-6L + 0.5% Sodium Metasilicate + 0.1 % ASA-301 + 10% BA-90 + 2.5% BA-56 + 0.05% Static Free tail slurry, weight 13.5 ppg, 1.84 cf/sk yield. Drop top plug. Displacing cement at report time (planned displacement 322 bbls). Co.MMENTS Witness of BOPE test waived by John Spaulding, AOGCC, 19:45 hrs, 02/14/03. DENSITY(ppg) I FV PVNP 54 14/26 I PP I WUHTHP 7.61 9.50 GELS 13/14 BIT/RUN SIZE 12/RR1 12.250 MANUF. STC BIT 1 RUN Wo.B I ECD 19.711 MUD DATAl DAILYCo.ST I 5360.00 FCIT.So.L 0.1W %Sand/MBT Ph/pM Pf/Mf Cl/Ca 2.0/5.0 1 0.50/10.0 8.5010.1 0.110.4 29,000/400 I CUM Co.ST CaCI2(wt%: H2S 100441.00 LIME ES 6RPM TYPE FGXiVC SERIAL NO.. MM3272 BITS JETS o.R TFA 18/18/18/12111111 I-o.-D-L-B-G-O-R 2-2-WT -Ä-E- I-NO-CM RPM I GPM I PRESS I P BIT DEPTH IN DATE IN 4,350.0 2/14/2003 HRS I 24Hr DIST I 24Hr Ro.P 1 CUM HRS I CUM DEPTH I CUM Ro.P Printed: 3/1212003 2:45:39 PM ) " Cº~'.FI .~~7IAh;A~"I1~~O'~.CØ~PANY 1 ,GtvITHOlE Da~~:J:~~t'i;n't;ort IGL 124 HR PROGTMD 282.00 4,350 WELL NAME ABALONE 1 IKB 21.0 BIT I RUN 12 1 RR 1 WOB 1 HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CU M ROP .. RPM 1 PRESS GPM PBIT ') ITVD IDFS IDOL 4,208 16 24 RPT# DATE 24 15-Feb-2003 BHA NO. LENGTH 12 830.78 BHA DESCRIPTION BHA EFF WT. PICK UP I SLACK OF1 ROT WT. TORQUE <;8x/min) BHA HRS ¡JAR HRS MWD HRS I MTR HRS Iss HRS 12.25" STC FGXiVC , Bit Sub, 121/8" IBS , 8" Monel DC ,12" IBS I 8" Monel DC , Cross Over, 5" 49.5PPF HWDP (5),6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2"IF-P X HT-38-B ,4" 14PPF S-135 DP AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: 32 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids Atigun SERVICE PERSONNEL DATA . NO. HOURS COMPANY 17 204.00 BJ Services 2 26.00 BJ Services 2 30.00 Weatherford 2 24.00 Smith International 2 48.00 R&K Industrial 2 24.00 S&R Enterprises 1 4.00 ABB Vetco Gray 2 30.00 Cent LAST BOP TEST: 2/8/2003 SIZE (in) ID(in) SHOETEST(ppg) 20.000 18.730 13.375 12.415 14.51 9.625 8.835 CÄSINGSÛMMARY LAST CASING TEST: MAX SICP MD (ft) (psi) @ (ppg) 170 600 (psi) @ 9.00 (ppg) 2,208 2,185 (psi) @ 9.50 (ppg) 4,336 TVD.(ft) 170 2,097 4,194 RECEIVED UNITS AVG. BKGRD: MAX. DRL: SERVICE offload cement cementers POB@ 06:0Q: NO. HOURS 2 2.00 4 24.00 3 45.00 1 2.00 2 16.00 1 1.00 1 6.00 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 2/15/2003 BURST (psi) 3,060 3,450 5,750 MAY 13 2003 Alaska on & Gas Cons. Commis8ion AmhGftge Printed: 3/12/2003 2:45:39 PM ") c ~ [DeNTIA_r~~N·Q'.LÞOMFt~NY ŒL"IG hTHOlE ) Pagètof2 - WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS MU BHA & RIH. OPERATION COMMENTS Fin cementing casing. KB Dail¥Drilling·..· Report Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 4,350 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE TVD 4,208 WBS I DFS I DOL I RPT # DATE 17 25 25 16-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST 907-283-1312 COUNTY/OTHER Kenai DX.02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 9.625 (in) @ 4,336 (ft) 3.500 (in) @ 10,140 (ft) 124 HR FORECAST TIH, drill shoe, LOT, trip for 6-1/8" BHA, drill ahead. LEAKOFF Install/test packoff. Test BOPE. PU DP. MU BHA & TIH. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 418.00 None 2/13/2003 2/15/2003 1/23/2003 ACCIDENT DESCRIPTION: I LAST RIG INSPECTION SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 06:30 0.50 4,350 4,350 AF CSGIN1 CEMT Finish displacing cement wi 322 bbls 9.5 ppg mud. Displaced a 10 bpm. Late pump pressure 750 psi, bump plug with 1300 psi. CIP at 06:15 hrs, 2/15/03. Bleed pressure. Floats held. 06:30 07:00 0.50 4,350 4,350 AF CSGIN1 CEMT RD casing running equipment. 07:00 09:00 2.00 4,350 4,350 AF CSGIN1 EQUIP Change bales. Blow down mud lines, fold up stabbing board, rehang tongs. Change liners to 4" in #1 pump. 09:00 12:00 3.00 4,350 4,350 AF CSGIN1 TEST Back out & LD landing joint. Install & test 9-5/8" packoff. Test to 5000 psi. 12:00 14:00 2.00 4,350 4,350 AF CSGIN1 NUND Change 9-5/8" rams to VBR's (2-7/8" to 5"). Install riser. 14:00 17:30 3.50 4,350 4,350 AF CSGIN1 TEST RU & test BOPE. Test upper rams, lower rams, blind rams, inside kill line valve, outside kill line valve, choke manifold valves 1 - 12, dart valve, upper TO check valve, HCR valve, manual choke line valve and annular to 250 psi low/3500 psi high. RD test equipment. Install wear bushing. 17:30 21:00 3.50 4,350 4,350 AF CSGIN1 TRIP TIH wi 4-1/2 HWDP. POOH LD HWDP. Rack 4" DP. 21:00 22:30 1.50 4,350 4,350 AF CSGIN1 RIG Service Rig. Change out Dennison drive line. 22:30 03:00 4.50 4,350 4,350 AF CSGIN1 TRIP PU & rack back 31 stds 4" DP. 03:00 05:00 2.00 4,350 4,350 AF CSGIN1 TRIP Rack, strap & tally drill out BHA. Strap & tally 100 jts 4", HT38 DP. 05:00 06:00 1.00 4,350 4,350 AF CSGIN1 TRIP MU & TIH wI 8-1/2" drill out BHA. COMMENTS Finished cleaning mud pits, Currently mixing new Flopro. 4" liners installed in #1, #2 & #3 pumps. DENSITY(ppg) I 9.50 I PP I IECD9.69\MUD DATAl DAILY COST I 625.00 I CUM COST 101066.00 FV PVNP GELS WUHTHP FCfT.SOL OIW %Sand/MBT Ph/pM Pf/Mf CIICa CaCI2(wt%; H2S LIME ES 6RPM 54 16/22 11/22 10.01 2.015.0 1 0.50/12.5 8.5010.1 0.1/0.5 28,500 1320 BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-Q-R 13/1 8.500 STC MS681 ER6059 16/16/161111111 4,350.0 2/16/2003 O-O-NO-A-E- I-NO-BHA BIT / RUN WOB RPM I GPM I PRESS I PBIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP Printed: 3/12/2003 2:45:42 PM ) CQ\F fD,· .1\tIALAAATHONGILCOMPANY TI··.G r...rr·· . ... ..... ... ... .. ~ · - HOLE ) Page 20f 2 WELL NAME ABALONE 1 IKB 21.0 DailyDriUingRE!port Exploitation Gas IGL 124 HR PROGTMD 282.00 4,350 TVD IDFS IDOL 4,208 17 25 RPT# ¡DATE 25 16-Feb-2003 BIT I RUN 13/1 WOB I RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP BHA NO. LENGTH 13 494.99 BHA DESCRIPTION BHA EFFWT. PICK UP SLACK OF1ROT WT. I TORQUE(~axlmin) I BHAHRS I JAR HRS MWD HRS I MTR HRS I SSHRS Tri-Cone Bit, Bit Sub, Cross Over, Heavy Weight Drill Pipe (4), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (11) AVG, CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS 32 AVG. BKGRD: MAX. DRL: COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids 1 24.00 BJ Services 2 24.00 R&K Industrial 2 48.00 ABB Vetco Gray SERVICE PQB@.06:00: NO. HOURS 2 24.00 1 4.00 4 12.00 2 48.00 1 6.00 Cent cementers LAST BOP TEST: 2/15/2003 SIZE (in) ID(in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 14.51 9.625 8.835 CASING SUMMARY LAST CASING TEST: MAXSICP MD(ft) (psi) @ (ppg) 170 600 (psi) @ 9.00 (ppg) 2,208 2,185 (psi) @ 9.50 (ppg) 4,336 TVD (ft) 170 2,097 4,194 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 2/22/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:45:42 PM WELL NAME ABALONE 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Fin clean pits for mud changeover. OPERATION COMMENTS TIH. Test casing to 3350 psi. Drill shoe track & 20' of new hole to 4370'. remaining pits for mud changeover. CONJ~~Dr6NrlA~) T~Gl[rHOLe MANHRS WORKED I ACCIDENT TYPE 386.00 None ACCIDENT DESCRIPTION: ) MARATHON.·C)ILGGMPANY Pagetbf2 Daily ·..D ril Ii ngRepor1 Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 20.0 4,370 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 KB TVD I DFS I DOL I RPT # DATE 4,194 18 26 26 17-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY W,ELL COST I CUM WELL COST 60.0000 I I I LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) @ 4,336 (ft) 3.500 (in) @ 10,140 (ft) 16.32 124 HR FORECAST Change over to new Flopro mud. TFNB. Drill ahead. RIG PHONE 907-283-1312 COUNTY/OTHER Kenai Perform LOT to 16.3 ppg EMW. Trip for new BHA. TIH. Clean I LAST SAFETY MTG 2/13/2003 SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/15/2003 1/23/2003 I LAST RIG INSPECTION SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESGRIPTlqN 06:00 07:30 1.50 4,350 4,350 AF CSGIN1 TRIP PU & RIH w/8-1/2" bit & BHA. 07:30 15:00 7.50 4,350 4,350 AF CSGIN1 TRIP PU 4" DP & TIH to 4230' MD. 15:00 16:00 1.00 4,350 4,350 AF CSGIN1 TEST RU & test 9-5/8" casing to 3350 psi surface pressure for 30 minutes, ok. 16:00 17:00 1.00 4,350 4,350 AF CSGIN1 DRILL TIH, tag float collar @ 4249' MD. Drill float collar & wash to 4306' MD. Suspect green cement. 17:00 17:30 0.50 4,350 4,350 AF CSGIN1 CIRC Circulate B/U. 100% green cement & contaminated mud. 17:30 19:30 2.00 4,350 4,370 AF CSGIN1 DRILL Wash cement to float shoe at 4334' MD. Drill shoe to 4336' MD. Wash to bottom at 4350' MD. Drill 20' of new formation to 4370' MD. (ART - 2 hrs) 19:30 20:30 1.00 4,370 4,370 AF CSGIN1 CIRC Circulate B/U. 9.85 ppg MW in/out. 20:30 21:30 1.00 4,370 4,370 AF CSGIN1 TEST Perform LOT wI 9.85 ppg mud & 1410 psi surface pressure. 16.3 ppg EMW LOT. 21:30 01:30 4.00 4,370 4,370 AF DRLPR TRIP POOH to change BHA. 01:30 03:00 1.50 4,370 4,370 AF DRLPR TRIP LD 8-1/2" bit. MU new 6-1/8" bit, 4-3/4" motor/MWD BHA. Loac & test MWD. 03:00 05:30 2.50 4,370 4,370 AF DRLPR TRIP TIH to 4336' MD. 05:30 06:00 0.50 4,370 4,370 AF DRLPR CLEAN Clean pill pit, mix spacer for mud changeover. COMMENTS BHI ran incorrect PDC bit from planned bit program. After mud changeover will trip for correct bit. DENSITY(ppg) I FV PVIYP 53 12/25 9.85 GELS 12/23 I PP I WUHTHP 12.61 ECD10.00IMUDDATAI DAILYCOST I Fcrr.SOL OIW %Sand/MBT Ph/pM Pf/Mf 3.017.0 I 0,50/10,0 11.701 812.00 Cl/Ca 28,500 I I CUM COST 101878.00 CaCI2(wt%; H2S LIME ES 6RPM BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 13/1 8.500 STC MS681 ER6059 16/16/16///111/ 4,350.0 2/16/2003 O-O-NO-A-E- I-NO-BHA 14/1 6.125 Hughes PDC 7102176 15/15/15/1/11/1 4,370.0 2/17/2003 0-0------ BIT 1 RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 13 11 8/10 70 I 75 279 650 203 2.00 20.0 10.00 2.00 20.0 10.00 Printed: 3/12/2003 2:45:45 PM ) c ... ~F{ DE·'TIA~AMl'HØ~ØII-."~~M~ANY TG HTHOlE Da~~p~::!~R:n~~Ørt IGL 124 HR PROGTMD 282.00 20.0 4,370 ) WELL NAME ABALONE 1 IKB 21.0 ITVD I DFS I DOL 4,194 18 26 RPT # I DATE 26 17 -Feb-2003 BIT I RUN 14/1 WOB I RPM / GPM 279 PRESS 650 PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP BHA NO. LENGTH 14 564.87 BHA DESCRIPTION BHA I EFFWT. PICK UP SLACK OF1 ROT WT. TORQUE (¡axlmin) I BHA HRSJARHRS I MWD HRS MTR HRS Iss HRS Polycrystalline Diamond Bit, Navidrill M1XL AKa 1.00 deg. , Intergral Blade Stabilizer, MWD Tool, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (11) NO, MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP fHYDRAULlCDATA STROKE (in) LlNE.R (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 8.000 4.000 110 139.31 650 278.62 8.000 4.000 110 139.31 650 278.62 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS AVG. BKGRD: MAX, DRL: 4 15 POB @ 06:00: NO. HOURS 4 48.00 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNELDATA NO, HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 10.00 4.00 LAST BOP TEST: 2/15/2003 SIZE (in) 10 (in) SHOETEST(ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) TV[)(ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ibltt) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 2/22/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:45:45 PM ) G . N,t:lDE":rIA~ARÞÆHØNiøILøqr.1.MN¥ BI-:GHTHOlE Då~~~;:~~ti;I1~!:.órt I GL 124 HR PROG TMD 21.0 282.00 546.0 4,916 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ) Pagelof2 907-283-1312 COUNTY/OTHER Kenai TVD I DFS I DOL I RPT # DATE 4,774 19 27 27 18-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL C~OST I CUM WELL COST 60.0000 I I I LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) (ã2 4,336 (ft) 3.500 (in) (ã2 10,140 (ft) 16.32 124 HR FORECAST Drill ahead 6-1/8" production Interval WELL NAME ABALONE 1 SUPERVISOR Steven Lambe FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS POOH to Shoe to CIO Wash pipe rubber OPERATION COMMENTS Trip in hole wI 6-1/8" PDC. Change out to new mud. Trip for correct Bit. Drill ahead 6-1/8" production interval from 4370' to 4916'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 414.00 None 2/13/2003 2/15/2003 1/23/2003 N ACCIDENT DESCRIPTION: KB SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 09:30 3.50 4,370 4,370 AF DRLPR CLEAN Finished Cleaning Pill pit & Trip tank while building new mud 09:30 11:00 1.50 4,370 4,370 AF DRLPR CIRC Displace hole to new mud & condition. Pump slug to POOH 11:00 13:30 2.50 4,370 4,370 TA DRLPR TRIP DOTH Trip to CO bit. BHI DO picked up wrong Bit. Down time attributed to Baker Hughs Inteq. 13:30 14:30 1.00 4,370 4,370 TA DRLPR TRIP DOTH CO Christensen 6-1/8" HCM406 Bit with Smith 6-1/8" M50VYPX jetted w/6 10's. TFA = .46" 14:30 17:00 2.50 4,370 4,370 TA DRLPR TRIP DOTH Trip in to shoe. 17:00 18:00 1.00 4,370 4,370 AF DRLPR RIG Service Rig. Check Drill line. 18:00 19:00 1.00 4,370 4,432 AF DRLPR DRILL Drill ahead OH wI 2 pumps. 19:00 00:00 5.00 4,432 4,675 AF DRLPR DRILL Drill ahead OH w/3 pumps @ 80 spm/each. 3rd Pump running smooth. . Surveying every 3rd stand. (18:00-24:00 ART 4, AST 0) 00:00 05:45 5.75 4,675 4,916 AF DRLPR DRILL Drilled OH wI 3 pumps. BHA starting to walk to the right. Last survey 266 degree. (ART 5.7, AST 0) 05:45 06:00 0.25 4,916 4,916 AF DRLPR TRIP Wiper trip to shoe to C/O Wash pipe Rubber. Hole in good condition COMMENTS Trip in hole wI 6-1/8" PDC. Change out to new mud. Trip for correct Bit. Drill ahead 6-1/8" production interval from 4370' to 4916'. DENSITY(ppg) I 9.40 I PP I IECDI9.96MUD DATAl DAILY COST I 31455.00 I CUM COST 133333.00 FV PVNP GELS WUHTHP FCrr.SOL Ofw %Sand/MBT Ph/pM Pf/Mf CJlCa CaCI2(wt%: H2S LIME ES 6RPM 49 9/25 15/19 7.6/ 1.0/7.5 I 0.25/5.0 9.701 0.3/1.6 34,000 1120 BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 14/1 6.125 Hughes PDC 7102176 15/15/151111I11 4,370.0 2/17/2003 0-0------ 15/1 6.125 Smith PDC JS9630 10/10/10/10/10/1011I1 4,370.0 2/17/2003 0-1-NO-A-X-0-NO-PR BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 14/1 I I 15/1 517 75 / 78 300 1,200 368 9.70 546.0 56.29 9.70 546.0 56.29 Printed: 3/12/2003 2:45:48 PM ) c . ,;Fl'!)'e,\tIAlMA~mHøN~'þ;~øMPANY l"'GHTHOlE Da~~p~::J~t7;n~~ort WEll NAME I KB I Gl 124 HR PROG I TMD ABALONE 1 21.0 282.00 546.0 4,916 ) !TVD DFS IDOL IRPT# I DATE 4,774 19 27 27 18-Feb-2003 BHA NO. LENGTH 15 564.87 BHA DESCRIPTION BHA EFF WT. PICK UP SLACK OFF ROT WT. TORQUE (maximin) BHA HRS JAR HRS ·1 MWD HRS I MTR HRS SS HRS o 115,000 68,000 80,000 7,000 I 4,000 .' STC M50VYPX, 4-3/4" MACH 1XL wi 1.0 AKO , String Stabalizer, MWD Tool, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Cross Over, DAILY JARS, Cross Over, HeavyWeight Drill Pipe (11), 4" 14PPF S-135 DP NO, 1 2 3 MAKE OF PUMP PUMP/HYDRAULIC DATA STROKE (ín) LINER (in) SPM Q (gpm) 8.000 4.000 80 100.00 8.000 4.000 80 100.00 8.000 4.000 80 98.18 PRESS. (psi) TOTAL Q 1,200 298.18 1,200 298.18 1,200 298.18 KILL SPM I. PRESSURE 60 350 60 340 60 360 OILWELL OILWELL OILWELL AVG, CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 12 53 AVG. BKGRD: MAX, DRL: SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM E/W CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM E/W CUM DOGLEG 4,371 1.20 152.40 4,229.16 782.79 -776.20 -103.17 1.81 4,625 0.90 181.60 4,483.13 786.42 -780.07 -102.00 0.23 4,434 0.90 153.10 4,292.15 783.72 -777.23 -102.64 0.48 CPMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY SERVICE 18 216.00 Epoch Well Services 2 30.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 S&R Enterprises POB@06:00: NO. HOURS 4 48.00 2 18.00 1 4.00 1 2.00 LAST BOP TEST: 2/15/2003 SIZE (in) 10 (in)· SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 2/22/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:45:48 PM ) ~... .NFfQEXY'AIJpÅRÄTHON OILCOMPAN>f ""¡:G·. · · ~~ HOLEDa~~p~:I:~t~:n~:Or1 ~ ,., . .. . .. WELL NAME KB I GL 124 HR PROG TMD TVD ABALONE 1 21.0 . 282.00 850.0 5,766 5,624 SUPERVISOR RIG NAME & NO. AUTH MD WBS Steven Lambe GLACIER DRILLING 1 FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STAT E/P ROV Alaska CURRENT STATUS / MTS Drilling 6-1/8" Open Hole OPERATION COMMENTS Repaired Top Drive. Drilled OH to 5,766'. Wiper trip @ 5,430' - Good Hole. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 434.00 None 2/13/2003 2/15/2003 2/13/2003 ACCIDENT DESCRIPTION: ) Page .tÖf2 907-283-1312 COUNTY/OTHER Kenai I DFS I DOL I RPT # DATE 20 28 28 19-Feb-2003 SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 ~~.;~OO NRI IDAILYW~LL~OST JCUM~EL~COST _ I LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) ~ 4,336 (ft) 3.500 (in) ~ 10,140 (ft) 16.32 124 HR FORECAST Drill to 5,900'. Wiper Trip new hole, Drill ahead. ',- I LAST RIG INSPECTION 1/10/2003 SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 08:00 2.00 4,919 4,916 TA DRLPR RIG TOPS Repair Top Drive Wash Pipe Rubber 08:00 09:00 1.00 4,916 4,916 AF DRLPR DRILL Ream back to bottom 4367 - 4916 09:00 19:00 10.00 4,916 5,430 AF DRLPR DRILL Drill 6-1/8" hole. ART = 9.5 hrs, AST = 0 hrs. 19:00 20:00 1.00 5,430 5,430 AF DRLPR CIRC Circulate Bottoms up 20:00 20:45 0.75 5,430 5,430 AF DRLPR TRIP Wiper Trip up to 4850'. Slight OP in New Hole. Old OK. TI H freely to 5430. Clean bottom. 20:45 06:00 9.25 5,430 5,766 AF DRLPR DRILL Drill 6-1/8" hole. ART = 8 hrs, AST = 0 hours. COMMENTS Hole Conditions good on connections DENSITY(ppg) I FV PVIYP 47 10/28 9.45 GELS 16/20 Ippl WllHTHP I ECD9.92IMUDDATA DAILYCOST 7559.00 Fcrr.SOL OIW %Sand/MBT Ph/pM Pf/Mf CI/Ca 1.017.5 I 0.25/5.5 9.0010.4 0.111.3 33,800/40 I CUM COST 140892.00 ÇaCI2(wt%;H2S LIME ES6RPM BITS MANUF. TYPE SERIAL NO. JETS OR TFÄ DEPTH IN.· DATE IN I-O-D·L-B~G-O-R Smith PDC JS9630 10/10/10/10/10/10/111 4,370.0 2/17/2003 0-1-NO-A-X-0-NO-PR WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 110 300 1,250 370 17.50 850.0 48.57 27.20 1,396.0 51.32 BIT/RUN SIZE 15/1 6.125 BIT I RUN 15/1 BHA NO. I LENGTH 15 564.87 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HR5 I MWD HR5 I MTR HR5 155 HR5 o 120,000 75,000 95,000 6,000 I 8,000 STC M50VYPX, 4-3/4" MACH 1XL w/1.0 AKa, String Stabalizer, MWD Tool, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Cross Over, DAILY JARS, Cross Over, Heavy Weight Drill Pipe (11), 4" 14PPF S-135 DP NO. 1 2 3 MAKE OF PUMP OILWELL OILWELL 01 L WELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 8.000 4.000 80 100.00 8.000 4.000 80 100.00 8.000 4.000 80 98.18 PRESS, (psi) TOTAL Q 1 ,250 298.18 1,250 298.18 1,250 298.18 KILL SPM I PRESSURE 60 390 60 380 60 400 Printed: 3/12/2003 2:45:51 PM ) CîDrG. ···fJºEj'rIAb,A~'tHON.OII-OÔMPANY ( ; ·1-' ¡HOLE [)ailY[)rilli~gRøpòrt E>eploitatlon Gas IGL \24 HR PROGITMD 282.00 850.0 5,766 ) Page2of2 WELL NAME ABALONE 1 IKB 21.0 ITVD IDFS IDOL 5,624 20 28 IRPT# ¡DATE 28 19-Feb-2003 AVG. CONN: MAX, CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 11 48 AVG. BKGRD: MAX. DRL: MD 4,810 4,997 5,182 INCL 0.80 0.60 0.50 AZIMUTH 266.00 249.80 219.20 TVD VS 4,668.11 788.15 4,855.10 788.92 5,040.09 790.09 SURVEYDATA N/S CUM EIW CUM DOGLEG MD INCL -781.61 -103.33 0.62 5,370 0.60 -782.04 -105.55 0.15 5,558 0.50 -783.00 -106.97 0.17 5,747 0.90 AZIMUTH 150.00 59.60 104.30 TVD VS N/S CUM EIW CUM DOGLEG 5,228.08 791.57 -784.49 -107.00 0.34 5,416.08 791.81 -784.92 -105.80 0.42 5,605.06 791.42 -784.87 -103.65 0.34 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY SERVICE 20 240.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 Wildflower POB @ 06:00:· 1.6 . NO. HOURS 4 48.00 2 18.00 1 4.00 1 4.00 LAST BOP TEST: 2/15/2003 SIZE (in) 10 (in). SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASINGiSUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) . TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 2/22/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:45:51 PM ) CQ N. r~ft)~t\jlIA~ARAl'HoNøILcøM;fÅNY L I G~'T HOLE ÐailyPrillingRepOrt Exploitation ·Gas I GL 124 HR PROG TMD 21.0 282.00 861.0 6,627 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR Steven Lambe FIELD NAME WILDCAT-FOR UNNAMED FIELD STAT ElPROV Alaska CURRENT STATUS / MTS Drilling ahead 6-1/8" hole OPERATION COMMENTS Drilled to 5934, Circ & Short trip to shoe, Service Rig, Drill ahead to 6627 SAFETY SUMMARY MANHRS WORKED \ACCIDENT TYPE \ LAST SAFETY MTG IBOP PSI TEST \ LAST STOP CARD AUDIT 436.00 None 2/13/2003 2/15/2003 2/13/2003 ACCIDENT DESCRIPTION: BIT/RUN SIZE MANUF. TYPE SERIAL NO. 15/1 6.125 Smith PDC JS9630 BIT / RUN WOB RPM GPM PRESS 15/1 5110 75 I 80 300 1 ,400 SAFETY MTG TOPICS: FROM TO HRS 06:00 10:00 4.00 10:00 12:00 2.00 12:00 13:00 1.00 13:00 16:30 3.50 16:30 17:30 1.00 17:30 06:00 12.50 DENSITY(ppg) 9.60 FV PVNP GELS 47 8/29 18/24 FROM 5,766 5,934 5,934 5,934 5,934 5,934 Ipp I WUHTHP 8.01 ) Page 1 of2 KB TVD I DFS I DOL I RPT # DATE 6,485 21 29 29 20-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 I DAILY WELL COST I CUM WELL COST I NEXT CASING 1 LEAKOFF 3.500 (in) ~ 10,140 (ft) 16.32 MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) ~ 4,336 (ft) 124 HR FORECAST Drill ahead, Trip for Bit NRI \ ~EGULATORY INSP? \ LAST RIG INSPECTION 1/10/2003 TO SUB 5,934 AF 5,934 AF 5,934 AF 5,934 TA 5,934 AF 6,627 AF OPERATIONS SUMMARY PHASE OP TRBL DRLPR DRILL DRLPR CIRC DRLPR TRIP DRLPR RIG DRLPR TRIP DRLPR DRILL TOPS DESCRIPTION Drill 6-1/8". ART = 3.5 hrs, AST= 0 hrs Circulate hole clean for WT. Wiper Trip to shoe. Hole clean wi minimal OP Service Top drive & pumps, cIa compensator. Trip in Hole. No drag / Clean bottom. Drill 6-118". ART = 11.5 hours, AST = 0 Hrs IECD 110.11IMUDDATAI DAILYCaST I 7219.00 FCn-.SOL. OIW %Sand/MBT Ph/pM Pf/Mf CIICa 1.0/8.0 I 0.25/5.5 9.50/0.5 0.5/1.7 31,000/40 I CÙMCÓST 148111.00 CaCI2(wt%; .... H2S LIME ES 6RPM BITS JETS OR TFA 10/10/10/10/10/101/11 DEPTH IN DATE IN 4,370.0 2/17/2003 I~O-D-L-B-G-O-R 0-1-NO-A-X-0-NO-PR P BIT 368 HRS 15.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 861.0 57.40 42.20 2,257.0 53.48 BHA NO. I LENGTH 15 564.87 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 10,000 130,000 80,000 100,000 9,000 I 5,000 STC M50VYPX , 4-3/4" MACH 1XL w/1.0 AKa, String Stabalizer , MWD Tool, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Cross Over, DAILY JARS, Cross Over, Heavy Weight Drill Pipe (11), 4" 14PPF S-135 DP NO. 1 2 3 OILWELL OILWELL OILWELL AVG. CONN: MAX. CONN: MAKE OF PUMP PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 8.000 4.000 80 100.00 8.000 4.000 100 100.00 8.000 PRESS. (psi) TOTAL Q 1,400 200.00 1,400 200.00 200.00 KILL SPM / PRESSURE 60 1,400 60 430 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 24 17 AVG. BKGRD: MAX. DRL: Printed: 3/12/2003 2:45:54 PM ) cq· \1 f'r.D~'\J'AlMARA,."ØNØIL..·~~"PANY r~G¡\jrHOlE·' Da~~:::!~t7~n~eis°rt WELL NAME I KB I GL \24 HR PROG I TMD ABALONE 1 21.0 282.00 861.0 6,627 ') TVD I DFS 6,485 21 IDOL IRPT# ¡DATE 29 29 20-Feb-2003 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EfW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM E/W CUM DOGLEG 5,874 0.20 70.90 5,732.06 791.41 -785.05 -102.47 0.58 6,245 0.40 88.80 6,103.05 ~ 790.38 -784.45 -99.64 0.12 6,059 0.60 75.80 5,917.05 790.88 -784.70 -101.23 0.22 6,431 0.70 335.90 6,289.04 789.31 -783.40 -99.45 0.50 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq Epoch Well Services SERVICE PERSONNELDATA NO. HOURS COMPANY SERVICE 19 228.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 1 24.00 Weaver Brothers (WBI) 2 24.00 PES 2 48.00 Smith International 4 48.00 POB @ 06:00: 18 NO. HOURS 2 24.00 2 4.00 1 12.00 LAST BOP TEST: 2/15/2003 SIZE (in) ID (in) SHOE TEST(ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING$UMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 2/22/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:45:54 PM CO f\J I':,~ De~r'IA¥RATHON OIL COMPANY ... rG L',-, 1.iOl"LJ Daily Drilling Report ~ ~ n .! I, E Exploitation Gas WELL NAME I GL \24 HR PROG TMD ABALONE 1 21.0 282.00 694.0 7,321 SUPERVISOR RIG NAME & NO. AUTH MD Steven Lambe GLACIER DRILLING 1 FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS 1 MTS Drilling Ahead 6-1/8" OPERATION COMMENTS Drilled 6-118" 6627' to 7321'. ) ) TVD I DFS I DOL I RPT # DATE 7,179 22 30 30 21-Feb-2003 WBS SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 MOC WI NRI I DAI,L Y, WELL COST I CUM WELL COST 60.0000 I I LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) @ 4,336 (ft) 3.500 (in) @ 10,140 (ft) 16.32 124 HR FORECAST Drill ahead 6-1/8", Possible Bit trip & BOP test 907-283-1312 COUNTY/OTHER Kenai Clean wiper trips @ 6677' & 7230' SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 463.00 None 2/20/2003 2/15/2003 2/13/2003 ACCIDENT DESCRIPTION: I LAST RIG INSPECTION 1/10/2003 SAFETY MTG TOPICS: Safety Pyramid, 3rd Pump addition FROM 06:00 07:00 08:30 09:30 00:00 01:00 02:30 TO HRS 07:00 1.00 08:30 1.50 09:30 1.00 00:00 14.50 01:00 1.00 02:30 1.50 06:00 3.50 OENSITY(ppg) I FV pVfYP 46 9/27 FROM 6,627 6,677 6,677 6,677 7,230 7,230 7,230 9.40 GELS 18/24 TO SUB 6,677 AF 6,677 AF 6,677 AF 7,230 AF 7,230 AF 7,230 AF 7,321 AF Ipp WLlHnlp 8.01 OPERATIONS SUMMARY PHASE OP TRBL DRLPR DRILL DRLPR CIRC DRLPR TRIP DRLPR DRILL DRLPR CIRC DRLPR TRIP DRLPR DRILL DESCRIPTION Drill 6-1/8" F 6627 to 6677'. ART = 1 Hr, AST =0 Hrs Circulate hole clean (2 BU) Wiper trip 5934' - 6677'. Hole good. Drilled 6-1/8" F6677' to 7230'. ART=13 Hrs, AST = 0 Circulate and Condition Hole Wiper Trip 6677 - 7230. Hole good. Drill 6-1/8" from 7230' to 7321'. ART = 3 hrs, AST = 0 hrs. ECD 9.96 MÛD DATAl DAILYCÖST 8846.00 FCIT.SOL OIW %Sand/MBT Ph/PM Pf/Mf Cl/Ca 1.017.5 / 0.25/5.0 9.20/0.3 0.2/1.4 30,000 140 ICUMCOST 156957.00 CaCI2(wt%: · H2S LIME ES 6RPM BIT/RUN SIZE 15/1 6.125 TYPE PDC BIT I RUN 15/1 MANUF. Smith WOB /10 RPM GPM 300 SERIAL NO. JS9630 BITS JETS ORTFA 10/10/10/10/10/101/1/ I-O-D-L-B-G-O-R 0-1-NO-A-X-0-NO-PR DEPTH IN DATEIN 4,370.0 2/17/2003 PRESS 1,400 P BIT 368 HRS 13.00 24Hr DlST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 694.0 53.38 55.20 2,951.0 53.46 BHA NO. I LENGTH 15 564.87 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF~ ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS o 160,000 85,000 I 115,000 I STC M50VYPX , 4-3/4" MACH 1XL w/1.0 AKO , String Stabalizer , MWD Tool, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Cross Over , DAILY JARS, Cross Over, Heavy Weight Drill Pipe (11),4" 14PPF S-135 DP PUMP 1 HYDRAULIC DATA NO. MAKE OF PUMP STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 1 OILWELL 8.000 4.000 80 100.00 1,400 298.18 60 430 2 OILWELL 8.000 4.000 80 100.00 1,400 298.18 60 440 3 01 L WELL 8.000 4.000 80 98.18 1 ,400 298.18 60 440 MUD GAS UNITS 27.1 AVG. CONN: AVG. TRIP: AVG. BKGRD: 18 MAX. CONN: MAX. TRIP: MAX. DRL: 21 Printed: 3/12/2003 2:45:57 PM C'P:lmte: ) , t!'GH¥H~I."L:~~:~,~~~:~!!~y Exploitation Gas IGL 124 HR PROGTMD 282.00 694.0 7,321 ) WELL NAME ABALONE 1 IKB 21.0 TVD IDFS IDOL RPT# I DATE 7,179 22 30 30 21-Feb-2003 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EJW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM E/WCUM DOGLEG 6,617 0.80 359.10 6,475.02 787.08 -781,06 -99.94 0.17 6,990 1.10 0.20 6,847.97 781,81 -775.41 -101.96 0.37 6,804 1.00 321.90 6,662.00 784.68 -778.47 -100.96 0.32 7,178 1.20 325.00 7,035.94 778.62 -771.99 -103.08 0.37 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO, HOURS COMPANY SERVICE . 19 247.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 3 36.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 Smith International POB @ 06:0Q: NO. HOURS 4 48.00 2 24.00 12.00 LAST BOP TEST: 2/15/2003 SIZE (in) 10 (in) SHOE TEST(ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (tt) TVD (tt) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ib/tt) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 2/22/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:45:57 PM WELL NAME ABALONE 1 SUPERVISOR Steven Lambe FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Tripping in Hole w/4-3/4 x 6-1/8" New Smith Bit OPERATION COMMENTS Drilled 6-1/8" f 7321' to 7508', Trip for Bit, BOP test, Tripping In. SAFETY SUMMARY MANHRS WORKED ¡ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT 408.00 None 2/20/2003 2/22/2003 2/20/2003 ACCIDENT DESCRIPTION: ") CI!~~'f~~'r~~;;::~~:ni~::NY I GL 124 HR PROG TMD 21.0 282.00 187.0 7,508 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ) Page1of2 907-283-1312 COUNTY/OTHER Kenai I DFS I DOL I RPT # DATE 7,336 23 31 31 22-Feb-2003 WBS SAPIWBS COST DX.02.07227 .CAP .DRL 2,695,000 MOCWI NRI IDAIL.LLCOST ~CU~ìJ 60.0000 I LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) (ã¿ 4,336 (ft) 3.500 (in) (ã¿ 10,140 (ft) 16.32 \24 HR FORECAST Trip to shoe, Slip & Cut drill Line, Drill ahead TVD KB I ~EGULATORY INSP? I LAST RIG INSPECTION 1/10/2003 SAFETY MTG TOPICS: OPERATION5SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 16:30 10.50 7,321 7,508 AF DRLPR DRILL Drill 6-1/8" from 7321' to 7508 (187'). ART= 9.5 hrs, AST = 0 hrs 16:30 18:00 1.50 7,508 7,508 AF DRLPR CIRC Circulate and Condition Hole for Bit Trip 18:00 23:30 5.50 7,508 7,508 AF DRLPR TRIP Trip out for Bit Change (ROP) 23:30 00:00 0.50 7,508 7,508 AF DRLPR TEST Pull Wear Ring 00:00 03:30 3.50 7,508 7,508 AF DRLPR TEST Test upper Rams, lower rams, blind rams, inside kill line valve, choke manifold valves 1-12, dart valve, upper TO check valve, HCR valve, manual choke line valve 250 psi & 3,500 psi. Test annular to 3,000 psi. 03:30 04:00 0.50 7,508 7,508 AF DRLPR TEST Install Wear Ring 04:00 05:30 1.50 7,508 7,508 AF DRLPR TRIP PU Smith 4-3/4 Pilot, 4-3/4" x 6-1/8" Concentric opener, New 4-3/4" motor, & MWD. 05:30 06:00 0.50 7,508 7,508 AF DRLPR TRIP Trip in Hole DEN~ITY(ppg) 9.40 I PP ECD 9.97 MUDDATAI DAILY COST I 6636.00 I C.LJM COST 163593.00 FV PVIYP GELS WUHTHP FCrr.SOL OIW %Sand/MBT Ph/pM Pf/Mf CI/Ca CaCI2(wt%: H2S LIME ES 6RPM 46 9/28 17/21 8.0/ 1.0/7.5 I 0.25/5.0 9.8010.5 0.4/1.6 30,000/40 BIT / RUN 15/1 16/1 BITS MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-Q-R Smith PDC JS9630 10/10/10/10/10/101/11 4,370.0 2/17/2003 0-1-NO-A-X-0-NO-PR Smith PDC JS9784 10/10/10/10/10/10/101/1 7,508.0 2/22/2003 0-1-WT-T-X-IN-NO-PR WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP /10 35 I 75 300 1,400 368 64.70 3,138.0 48.50 I I 298 1 ,400 BIT/RUN SIZE 15/1 6.125 16/1 4.750 BHA NO. I LENGTH 16 566.34 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I S8 HRS 4-3/4" Smith MDT285 PDC , 6-1/8" Smith SH078PX PDC ,4-3/4" Mach1 XL (.8 AKO) , String Stabalizer (6") , MWD Tool, Hang-Off Sub, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4), 3-1/2" IF B x HT-38 P , Daily Jar. HT-38 B x 3-1/2" IF P . Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 Printed: 3/12/2003 2:46:00 PM c.... ............. .. ..~...·.f.'rn. ".' f.....E... ." I. ".... .·..1.·.· ...A'.. .... ,.)1.·. ........... T:HT HOtEL! MARA'I'HÒNQILCòMPANY \KB 21.0 ) Page2·.·.of2 WELL NAME ABALONE 1 Dally···Orilling· .R~port Exploitation Gas GL \24 HR PROGTMD 282.00 187.0 7,508 TVD I DFS I DOL 7,336 23 31 IRPT# I DATE 31 22-Feb-2003 NO. 1 2 3 MAKE OF PUMP PUMPIHYDRAULlCDATA STROKE (in) LlNER(in) SPM Q(gpm) 8.000 4.000 80 100.00 8.000 4.000 80 100.00 8.000 4.000 80 98.18 PRESS. (psi) TOTAL Q 1,400 298.18 1,400 298.18 1,400 298.18 KILL SPM I PRESSURE 60 440 60 400 . 60 440.· OILWELL OILWELL OILWELL AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 17 48 AVG. BKGRD: MAX. DRL: MD 7,366 INCL 1.60 AZIMUTH 339.50 SURVEY DATA TVD VS N/S CUM EfW CUM DOGLEG MD INCL 7,223.88 774.91 -767.92 -105.13 0.28 7,448 1.90 AZIMUTH 327.90 TVD VS N/S CUM EJW CUM DOGLEG 7.305.84 772.89 -765.70 -106.25 0.56 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL· DATA NO. HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 Smith International POB@06:00: NO. HOURS 4 48.00 2 18.00 18.00 LAST BOP TEST: 2/22/2003 SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft)·· TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST(psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:00 PM C..,~..f .' 1: NflAt, fIGHT HOLE WELL NAME ABALONE 1 SUPERVISOR Steven Lambe FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENTSTATUS/MTS Drilling ahead @ 8116' OPERATION COMMENTS Trip in with new bit, slip & cut drill line, Drilled 4-3/4" x 6-1/8" hole from 7508' to 8116'. SAFETY··SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT 407.00 None 2/20/2003 2/22/2003 2/20/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM 06:00 07:30 09:00 11:00 TO HRS 07:30 1.50 09:00 1.50 11 :00 2.00 06:00 19.00 FROM 7,508 7,508 7,508 7,508 ") MARATHØNe>lL..CQM·PANY PagEr f.of2 Dai·..IY.··...Dri·I.I.·in·9.·.·.R~port Exploitation· Gas I GL 124 HR PROG TMD 21.0 282.00 608.0 8,116 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 KB TVD I DFS I DOL I RPT # DATE 7,973 24 32 32 23-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST 60.0000 L ~ ~, y I LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) @ 4,336 (ft) 3.500 (in) @ 10,140 (ft) 16.32 \24 HR FORECAST Drill ahead wI planned short trip @ 24 hours. RIG PHONE 907-283-1312 COUNTY/OTHER Kenai I ~EGULATORY INSP? I LAST RIG INSPECTION 1/10/2003 TO SUB 7,508 AF 7,508 AF 7,508 AF 8,116 AF OPERATIONS SUMMARY PHASE OP TRBL DRLPR TRIP DRLPR RIG DRLPR TRIP DRLPR DRILL DESCRIPTION Trip in with new bit to 4245'. Slip and Cut 100' Drill Line. Inspect brakes. OK Trip in to 7508. Establish Circ & Fan Bottom. Drill 4-3/4" by 6-1/8" OH from 7508' to 8116'. ART= 14.5 hrs, AST = 0 Hrs. COMMENTS Centrifuge Mud Back from 9.6+ to 9.4 in 4 hours. DENSITY(ppg). i. FV PVIYP 47 8/30 Ippl WUHTHP 7.6/ 9.40 GELS 18/23 ECD9.981 MUDDATADAIL'(COST· 5209.00 FCfT.SOL OIW %Sand/MBT PhlpM PflMf CIfCa 1.0/7.5 / 0.2515.2 9.60/0.2 0.111.5 29,500 140 ¡CUM COST. 168802.00 CaCI2(wt%; H2S LIME ES ·6RPM BITS IVIANUF. TYPE SERIAL NO: JËT$ ORTFA DEPTH IN DATE IN I-O-D-L-B-G-O-R Smith PDC JS9784 10/10/10/10/10/10/10111 7,508.0 2/22/2003 0-1-WT-T-X-IN-NO-PR WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/7 80 / 80 300 1 ,400 270 14.50 608.0 41.93 14.50 608.0 41.93 BITIRUN SIZE 16/1 4.750 BIT 1 RUN 16/1 BHA IEFFWT. \PICKUP ISLACKOF~ROTWT. ·TORQUE(maxtmin> IBHAHRS IJARHRS MWDHRS IMTRHRS ISS HRS o 170,000 98,000 I 125,000 / 4-3/4" Smith MDT285 PDC , 6-1/8" Smith SH078PX PDC , 4-3/4" Mach1 XL (.8 AKO) , String Stabalizer (6") , MWD Tool, Hang-Off Sub, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4),3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 BHA NO. \ LENGTH 16 566.34 BHA DESCRIPTION NO. 1 2 3 MAKE OF PUMP OILWELL OILWELL OILWELL AVG. CONN: MAX. CONN: PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 8.000 4.000 80 100.00 8.000 4.000 80 100.00 8.000 4.000 80 98.18 PRESS. (psi) TOTAL Q 1,400 298.18 1,400 298.18 1,400 298.18 KILL SPM 1 PRESSURE 60 540 60 510 60 500 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 17 65 64 AVG. BKGRD: MAX. DRL: Printed: 3/12/2003 2:46:02 PM ) .. .'PfE;\lr'AtAr{ATHQNQíL~~MP~~Y T~GfîT f10lE I Da~~p~;::=t7:n~fs0rt IGL 124 HR PROGTMD 282.00 608.0 8,116 '" ) WELL NAME ABALONE 1 IKB 21.0 ITVD DFS IDOL RPT# 1 DATE 7,973 24 32 32 23-Feb-2003 MD 7,678 7,866 INCL 2.10 2.80 AZIMUTH 340.50 343.70 SURVEY DATA TVD VS N/S.CUM E/W CUM DOGLEG MD INCL 7,535.71 766.32 -758.50 -109.69 0.21 8,051 3.40 7,723.53 759.14 -750.84 -112.12 0.38 AZIMUTH 339.80 TVD VS N/S CUM EIW CUM DOGLEG 7,908.26 . 750.26"-741.36 ''':~115.29 . 0'.34 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNELDATA NO. HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 Smith International POB @ 06:00: NO. HOURS 4 48.00 1 4.00 1 13.00 18.00 LAST BOP TEST: 2/22/2003 SIZE (in) ID(in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING$UMMARY LAST CASING TEST: 2/16/2003 MAX SICP MQ(ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (I bitt) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:02 PM ') N. ¡ Da \lTIAL;ð;RATH0N 01l C0MPANY rrGh'T HOl. E DailyDr!lIi~g Report Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 497.0 8,613 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR Steven Lambe FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Drilling ahead 6-1/8" (á2 8613' OPERATION COMMENTS Drilled 6~1/8" production interval from 8116' to 8613'. MANHRS WORKED I ACCIDENT TYPE 397.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 12:30 6.50 FROM 8,116 12:30 13:30 1.00 13:30 14:30 1.00 14:30 06:00 15.50 8,272 8,272 8,272 ) KB TVD I DFS I DOL I RPT # DATE 8,469 25 33 33 24-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 M~~.~~OO NRI \ DAIL Y~ WELL COST tM WELL COST [f" I LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) (á2 4,336 (ft) 3.500 (in) @ 10,140 (ft) 16.32 124 HR FORECAST Drill ahead 6-1/8" with planned short trip 907-283-1312 COUNTY/OTHER Kenai I LAST SAFETY MTG 2/20/2003 SAFETYSUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT \ RNEGULATORY INSP7 2/22/2003 2/20/2003 I LAST RIG INSPECTION 1/10/2003 TO SUB 8,272 AF OPERATIONS SUMMARY PHASE OP TRBL DRLPR DRILL 8,272 AF 8,272 AF 8,613 AF DRLPR CIRC DRLPR TRIP DRLPR DRILL DESCRIPTION Drilled 6-1/8" hole from 8116' to 8272'. ART = 5.5 hrs, AST = 0 hrs Circulate bottoms up. Wiper trip new hole, 7490' to 8272. Hole in good condition Drilled 6-1/8" hole from 8272' to 8613'. ART = 13.5 hrs, AST = C hrs COMMENTS Started survey per stand with well angle above 3 degree's. DENSlrY(ppg) I FV PVIYP 49 8/34 I PPI WUHTHP 7.8/ 9.45 GELS 18/27 I ECDI10.07 MUD DATAl. DAILYCOSr I 8345.00 Fcrr.SOL OIW %Sand/MBT Ph/pM Pf/Mf CIICa 1.0/7.5 / /5.0 9.90/0.6 0.4/1.6 29,250/40 I CUM COST 177147.00 CaCI2(vvt%: .H2S LIME ES 6RPM BITS MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I·O·D·L·B.;G~O~R Smith PDC JS9784 10/10/10/10/10/10/101/1 7,508.0 2/22/2003 0-1-WT-T-X-IN-NO-PR WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 3/8 282 1 ,400 240 13.50 497.0 36.81 28.00 1,105.0 39.46 BIT/RUN SIZE 16/1 4.750 BIT I RUN 16/1 BHA I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS MTR HRS I SS HRS 10,000 175,000 95,000 130,000 / 4-3/4" Smith MDT285 PDC , 6-1/8" Smith SH078PX PDC ,4-3/4" Mach1 XL (.8 AKa) , String Stabalizer (6") , MWD Tool, Hang-Off Sub, HT-38 B X 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4),3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11), 4" HT -38 S-135 BHA NO. I LENGTH 16 566.34 BHA DESCRIPTION PUMP I HYDRAULIC DATA NO. MAKE OF PUMP STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 1 OILWELL 8.000 4.000 76 94.00 1 ,400 281.27 60 590 2 OILWELL 8.000 4.000 76 94.00 1,400 281.27 60 620 3 OILWELL 8.000 4.000 76 93.27 1 ,400 281.27 60 580 Printed: 3/12/2003 2:46:05 PM ~.NFP · eN ~tÀlJ l. .íGHri"'OlEMARJ\TM~N¡~lt~øMrANY Dally Drilli ng Report Exploitation Gas IGL 124 HR PROGITMD 282.00 497.0 8,613 ) Page 2öf2 WELL NAME ABALONE 1 IKB 21.0 ITVD IDFS IDOL 8,469 25 33 IRPT# I DATE 33 24-Feb-2003 AVG. CONN: MAX. CONN: MUD.GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 17 65 64 AVG, BKGRD: MAX, DRL: SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM E/W CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM E1W CUM DOGLEG 8,115 3.30 337.00 7,972.15 747.05 -737.88 -116.66 0.30 8,304 3.60 344.00 8,160.80 736.68 -726.87 -119.88 0.45 8,175 3.30 341.60 8,032.05 744.05 -734.65 -117.88 0.44 8,367 4.10 347.50 8,223.66 732.79 -722.77 -120.91 0.88 8,241 3.70 348.20 8,097.93 740.37 -730.77 -118.92 0.86 8,429 4.10 348.90 8,285.50 728.65 -718.44 -121.82 0.16 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 Smith International POB@ 06:00: NO. HOURS 4 48.00 1 4.00 1 9.00 12.00 LAST BOP TEST: 2/22/2003 SIZE (in) 10. (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAXSICP MD(ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ibltt) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST(psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:05 PM ) C.w F.. .JJ..I~:IAh~~:r~Ø~Ø'l- CØMF9~N¥ l IGH r,.'-OlE Ða~~p~:::=f7;n~!s°rt I GL 124 HR PROG TMD 21.0 282.00 239.0 8,852 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR Steven Lambe FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS I MTS Drilling ahead 6-/8" (á) 8852' feet OPERATION COMMENTS Drilled 8,613 - 8,772'. Trip for bit. Drilled 8772' - 8852' MANHRS WORKED I ACCIDENT TYPE 397.00 None ACCIDENT DESCRIPTION: ) Pagè1···.· óf· 2 KB I DFS I DOL I RPT # DATE 26 34 34 25-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST TVD 8,708 WBS 907-283-1312 COUNTYIOTHER Kenai DX02.07227.CAP.DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 9.625 (in) (á) 4,336 (ft) 3.500 (in) (á) 10,140 (ft) 124 HR FORECAST Drill ahead 6-1/8" Production Interval LEAKOFF 16.32 I LAST SAFETY MTG 2/20/2003 SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/22/2003 2/20/2003 I LAST RIG INSPECTION 1/10/2003 SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 14:30 8.50 8,613 8,772 AF DRLPR DRILL Drilled 6-1/8" OH from 8613' to 8772'. ART =7.5 hrs, AST = 0 hrs. 14:30 15:30 1.00 8,772 8,772 AF DRLPR CIRC Circulate BU for Bit trip. 15:30 18:30 3.00 8,772 8,772 AF DRLPR TRIP POOH to shoe. 25 K OP @ 7770'. 18:30 19:00 0.50 8,772 8,772 T A DRLPR RIG TOPS Removed Top Drive Actuator Valve for repair. 19:00 22:00 3.00 8,772 8,772 AF DRLPR TRIP POOH to Surface 22:00 22:30 0.50 8,772 8,772 TA DRLPR RIG TOPS Installed repaired TO Actuator valve 22:30 23:00 0.50 8,772 8,772 AF DRLPR TRIP C/O Bits to HCM406, 6-1/8" PDC. 23:00 03:00 4.00 8,772 8,772 AF DRLPR TRIP RIH with New bit. 03:00 03:30 0.50 8,772 8,772 AF DRLPR DRILL Wash/Ream 8675' to 8772'. Fan bottom w/ new bit. 03:30 06:00 2.50 8,772 8,852 AF DRLPR DRILL Drill 6-1/8" from 8,772 to 8852'. ART = 2 hours, AST = 0 hrs. COMMENTS EPOCH equipment failure. Manually recording data DENSITY(ppg) I FV PVIYP 48 8/30 BIT/RUN SIZE 16/1 4.750 17 /1 6.125 BIT / RUN 16/1 17 /1 BHA NO. I LENGTH 17 564.90 BHA DESCRIPTION 9.40 GELS 17/21 Ipp I WUHTHP 1.0/ I ECD 9.98 MUDDATA DAILYCOST I 3091.00 Fcrr.SOL OIW %SandlMBT Ph/pM Pf/Mf CIICa 1.0/7.5 I /5.2 9.8010.5 0.311.6 28,600/60 I CUM COST 180238.00 CaCI2('Nt%: H2S LIME ES 6RPM BITS MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN -O-D-L-B-G-Q-R Smith PDC JS9784 10/10/10/10/10/10/10111 7,508.0 2/22/2003 0-1-WT - T -X-I N-NO-PR Hughes HCM406 7102176 15/15/15111/11I 8,772.0 2/24/2003 1-1-WT-N-D- I-CT-LOG WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/9 275 1 ,400 227 7.50 159.0 21.20 35.50 1,264.0 35.61 1/9 279 1,500 251 2.00 80.0 40.00 2.00 80.0 40.00 BHA I EFF WT. I PICK UP I SLACK OF~ ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS o 180,000 100,000 I 135,000 9,000/ 11,000 Hughes HCM406 , 4-3/4" Mach1 XL (.8 AKO) , String Stabalizer (6") , MWD Tool, Hang-Off Sub, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4), 3-1/2" IF B x HT-38 P , ~Ëda\ìËD P , Heavy Weight Drill Pipe - 11 MAY 13 2003 Alaska Œ¡ (S¡ Gas Cons. commIiJR Anchorage Printed: 311212003 2:46:08 PM \~) ') T'rG····.·.·iFt~~_\- -,rlALARATH<:>NØi.¡: C6MPJ\NY ... .¡ ··.··.11 i ·~OlE Daily D tilli rig Rêport Exploitation Gas \KB GL 124 HR PROGITMD 21.0 282.00 239.0 8,852 Page 2Òf2 WELL NAME ABALONE 1 TVD IDFS IDOL IRPT# DATE 8,708 26 34 34 25-Feb-2003 BHA BHADESCRIPTION (11), 4" HT -38 S..:135 NO, 1 2 3 MAKE OF PUMP PUMP IHYDRAULlCDATA STROKE (in) UNER(in) SPM Q(gpm) 8.000 4.000 77 93.00 8.000 4.000 74 93.00 8.000 4.000 74 90.82 . ... OILWELL OILWELL OILWELL PRESS. (psi) TOTALQ 1,500 276.82 1,500 276.82 1,500 276.82 KILL SPM I PRESSURE 60 590 60 580 60 600 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 17 65 64 AVG. BKGRD: MAX. DRL: SURVEY DATA MD INCL AZIMUTH TVD VS N/SCUM EIW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 8,489 4.30 349.60 8,345.34 724.51 -714.12 -122.64 0.34 8,678 4.30 350.00 8,533.82 711.41 -700.39 -125.62 0.22 8,553 4.30 344.70 8,409.16 720.06 -709.44 -123.70 0.57 8,717 4.50 347.20 8,572.70 708.61 -697.45 -126.21 0.75 8,612 4.20 348.60 8,468.00 716.02 -705.19 -124.71 0.52 8,738 4.10 346.50 8,593.64 707.15 -695.92 -126.57 1.92 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY SERVICE 17 209.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 Smith International POB@ 06:00: NO. HOURS 4 48.00 1 2.00 1 12.00 6.00 LAST BOP TEST: 2/22/2003 SIZE (in) ID(in) SHOETEST(ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WI (Ibltt) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:08 PM ) C.,. ,l\tJ; ¡DJ .Nr'AlM~RÄTHØN qlLCOMPANV lIG.JLfTH· .. ··0···· .··l·····.···.E. .. Daily......···D.· r!ln~g. R~P....ort . . .... ... Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 725.0 9,577 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE ) Pagetof2 TVD 9,426 WBS I DFS I DOL I RPT # DATE 27 35 35 26-Feb-2003 SAPIWBS COST 2,695,000 CUM WELL COST WELL NAME ABALONE 1 SUPERVISOR Steven Lambe FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drilling ahead 6-1/8" @ 9577' OPERATION COMMENTS Drilled 6-1/8" production f 8852' to 9577'. KB 907-283-1312 COUNTY/OTHER Kenai DX02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 9.625 (in) @ 4,336 (ft) 3.500 (in) @ 10,140 (ft) 124 HR FORECAST TD well, Trip & Start LWD logging program MANHRS WORKED I ACCIDENT TYPE 397.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: I LAST SAFETY MTG 2/20/2003 SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/22/2003 2/20/2003 FROM TO HRS 06:00 06:00 24.00 TO SUB 9,577 AF OPERATIONS SUMMARY PHASE OP TRBL DRLPR DRILL DESCRIPTION Drill 6-1/8" production Interval from 8852' to 9577'. ART = 15.5 hours, AST = 4.5 hrs. FROM 8,852 COMMENTS EPOCH functional @ 11 :30. Will land directionally 45' inside 200' radius target with current build. LEAKOFF 16.32 I LAST RIG INSPECTION 1/10/2003 DENSITY(ppg) 9.55 F'P I IECD 110.17.MUD DATAl DAILYCOSr 4468.00 I CUM COST 184706.00 FV PVfYP GELS WUHTHP FCfT.SOL OIW %Sand/MBT Ph/pM Pf/Mf Cl/Ca CaCI2(wt%: H2S LIME ES 6RPM 46 8/33 18/22 7.71 1.017.5 / 16.0 9.50/0.3 0.2/1.7 28,800 /80 BIT/RUN SIZE 17/1 6.125 BITS MANUF. TYPE SERIAL NO. JETS OR TFÁ . . D.EPTHIN DATE IN Hughes HCM406 7102176 15/15/1511/1/// 8,772.0 2/24/2003 WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS 2/8 75 I 75 300 1,700 297 20.00 725.0 36.25 22.00 BIT I RUN 17/1 I-O-D-L-B-G.-O-R 1-1-WT-N-D- I-CT-LOG CUM DEPTH CUM ROP 805.0 36.59 BHA IEFFWT. PICKUP SLACKOF1ROTWT. TORQUE(maxlmin) BHAHRS JARHRS MWDHRSIMTRHRS ISSHRS o 185,000 105,000 145,000 / Hughes HCM406 , 4-3/4" Mach1 XL (.8 AKO) , String Stabalizer (6") , MWD Tool, Hang-Off Sub, HT-38 B X 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4), 3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 BHA NO. I LENGTH 17 564.90 BHA DESCRIPTION NO. 1 2 3 MAKE OF PUMP PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 8.000 4.000 80 100.00 8.000 4.000 80 100.00 8.000 4.000 80 98.18 PRESS. (psi) TOTAL Q 1,700 298.18 1,700 298.18 1,700 298.18 OILWELL OILWELL OILWELL AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: 69 KILL SPM 1 PRESSURE 60 530 60 520 60 540 UNITS 27.1 28 227 Printed: 3/12/2003 2:46:11 PM )) CQ NF!i·. ......rs.~~.7IAt~J)(T~C)NOI~i~~MPJ)(NY 1 IGHTuo·· ·l.·.··.E· Dail.YD.....·..f.ill.in9.......iR. e.p.ort . ... n. .. ·.c Exploitation Gas IGL 124 HR PROGITMD 282.00 725.0 9,577 Páge 20f 2 WELL NAME ABALONE 1 IKB 21.0 TVD IDFS IDOL IRPT# I DATE 9,426 27 35 35 26-Feb-2003 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 8,800 4.50 350.00 8,655.47 702.81 -691.37 -127.51 0.77 9,113 4.40 342.60 8,967.41 ..679.28' -666.53 -133.96 q\\\48 . 8,863 4.70 344.70 8,718.26 698.12 -686.45 -128.62 0.75 9,175 4.70 340.20 9,029.21 674.93 -661.87 -135.54 0.57 8,927 5.10 348.20 8,782.03 693.07 -681 . 13 -129.89 0.78 9,237 4.50 334.50 9,091.01 670.70 -657.29 -137.44 0.80 8,988 5.20 345.40 8,842.78 688.00 -675.80 -131.15 0.44 9,300 5.00 337.00 9,153.80 666.33 -652.53 -139.58 0.86 9,050 4.10 341.90 8,904.58 683.45 -670.98 -132.54 1.83 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 48.00 Halliburton Sperry Sun POB @·06:00: NO. HOURS 4 48.00 1 2.00 1 12.00 1 3.00 2 8.00 LAST BOP TEST: 2/22/2003 SIZE (in) ID(in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9,625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD(ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:11 PM O.V r[)E;\J·¡·lAf~RATHON OIL COMPANY T i'GH THOLl=. Da~rÞ~::~~~:n~ts°rt I GL \24 HR PROG TMD 21.0 282.00 463.0 10,040 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR R. C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Drilling ahead @2 10040'. OPERATION COMMENTS Drill F/9577' to 9922'. CBU. ) ) KB 1 DFS I DOL I RPT # DATE 9,890 28 36 36 27-Feb-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 I DAILY WELL COST I CUM WELL COST I NEXT CASING I LEAKOFF 3.500 (in) @2 10,140 (ft) 16.32 TVD MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) @2 4,336 (ft) 124 HR FORECAST Drill ahead. NRI POOH to 8522'. RIH P/U 18jnts DP. Drill F/9922' to 10040'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 420.00 None 2/27/2003 2/22/2003 2/20/2003 ACCIDENT DESCRIPTION: I LAST RIG INSPECTION 2/23/2003 SAFETY MTG TOPICS: Adjusting brakes and new pump room. FROM 06:00 19:00 21:00 22:30 00:00 TO HRS 19:00 13.00 21 :00 2.00 22:30 1.50 00:00 1.50 06:00 6.00 FROM 9,577 9,922 9,922 9,922 9,922 DENSITY(ppg) . FV PVIYP 45 9/29 Ippl W1.JHTHP 7.61 9.45 GELS 16120 TO SUB 9,922 AF 9,922 AF 9,922 AF 9,922 AF 10,040 AF OPERATIONS.SUMMARY PHASE· OP TRBL DRLPR DRILL DRLPR CIRC DRLPR TRIP DRLPR TRIP DRLPR DRILL DESCRIPTION Drill and survey F/9577' to 9922'(ART=11.32, AST=Ohrs). CBU X2. Pump dry job. POOH to 8522'(hole slick). RIH to 9922' P/U 18jnts 4" DP. Drill and survey F/9922' to 10040'(ART= 5hrs, AST=Ohrs). ECD10.07IMUDDATAIDAILYCOST I 3726.00 FCn.SOL OIW %Sand/MBT Ph/prill Pt/l\llfCI/tâ 2.0/8.0 192 /6.0 9.3010.3 0.311.6 27,000 160 I CUM COST': 188432.00 CaCI2(V'it%: H2$ LIME ES 6RPM 16 BITS MANUF.· . TYPE SERIAL NO, JETSQR TFA DEPTH IN· DATEIN I·O~D·VB·G·O·R Hughes HCM406 7102176 15/15/151111111 8,772.0 2/24/2003 1-1-WT-N-D- I-CT-LOG WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/6 70 I 70 300 2,100 295 16.32 463.0 28.37 38.32 1,268.0 33.09 BIT/RUN SIZE 17/16.125 BIT / RUN 17 11 BHA I EFF WT. I PICK UP I SLACK OF1ROT WT. ITORQUE (maximin) I·BHA HRS I JAR HRS I MWD HRSI MTR HRS I SS HRS 13,000 200,000 110,000 145,000 12,000/9,000 Hughes HCM406 ,4-3/4" Mach1 XL (.8 AKa) , String Stabalizer (6") , MWD Tool, Hang-Off Sub, HT-38 B X 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4),3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 8-135 BHANO, I LENGTH 17 564.90 BHA DESCRIPTION NO. 1 2 3 MAKE OF PUMP OILWELL OILWELL OILWELL AVG. CONN: MAX. CONN: PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 8.000 4.000 82 100.64 8.000 4.000 82 100.64 8.000 4.000 82 100.64 PRESS. (psi) TOTAL Q 2,100 301.92 2,100 301.92 2,100 301.92 KILL SPM / PRESSURE 60 640 60 620 60 630 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 27.1 5 107 28 AVG. BKGRD: MAX. DRL: Printed: 3/12/2003 2:46:14 PM ~r:1 TIGHT ) _¡V71A'lRA'THeN elL CeMPANY ,'OLE Daily Drilling Report ,~ Exploitation Gas J IKB IGL 124 HR PROGTMD 21.0 282.00 463.0 10,040 ) Page 20f 2 WELL NAME ABALONE 1 TVD I DFS I DOL I RPT # I DATE 9,890 28 36 36 27-Feb-2003 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 9,363 5.30 333.10 9,216.54 661.65 -647.41 -141.97 0.73 9,672 6.40 341.20 9,523.90: 634.33 -617.92 -153.51 0.18 9,424 5.40 333.80 9,277.28 657.02 -642.32 -144.51 0.20 9,735 6.30 342.60 9,586.51 628.13 -611.30 -155.68 0.29 9,486 5.50 338.00 9,339.00 652.09 -636.95 -146.91 0.66 9,799 6.50 343.00 9,650.11 621.73 -604.49 -157.79 0.32 9,548 6.20 341.20 9,400.67 646.58 -631.02 -149.10 1.25 9,862 6.70 343.30 9,712.70 615.21 -597.55 -159.89 0.32 9,610 6.50 341.60 9,462.29 640.50 -624.52 -151.29 0.49 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes I nteq SERVICE PERSONNEL DATA NO. HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Halliburton Sperry Sun 2 48.00 POB @ 06:00: NO. HOURS 4 48.00 1 12.00 1 12.00 2 24.00 LAST BOP TEST: 2/22/2003 SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) TVD. (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST(psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:14 PM ) [:Nr,Al!¡«AA:1'HON ···Olt.··¢'<;>MPA~Y HOlEDª~~p~J:!l~~n7:S°rt ... I GL 124 HR PROG TMD 21.0 282.00 305.0 10,345 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE N;r::, rIGH t WELL NAME ABALONE 1 SUPERVISOR R. C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STAT EIP ROV Alaska CURRENT STATUS 1 MTS Drilling ahead. OPERATION COMMENTS Drill F/10040 to 10345'. MANHRS WORKED I ACCIDENT TYPE 420.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: General safety. FROM TO HRS 06:00 14:00 8.00 14:00 06:00 16.00 FROM 10,040 10,152 DENSITY(ppg) I FV PVNP 44 1 0/29 9.45 GELS 15/18 II'P ·1 WUHTHp 7.81 ) Page tof2 KB TVD I DFS I DOL I RPT # DATE 10,192 29 37 37 28-Feb-2003 WBS SAPIWBS COST 2,695,000 CUM WELL COST 907-283-1312 COUNTY/OTHER Kenai DX.02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 9.625 (in) (ã2 4,336 (ft) 3.500 (in) (ã2 10,140 (ft) 124 HR FORECAST Drill ahead. POOH PIU LWD tools. I LAST SAFETY MTG 2/27/2003 SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/22/2003 2/20/2003 I LAST RIG INSPECTION 2/23/2003 TO SUB 10,152 AF 10,345 CS OPERATIONS SUMMARY PHASE OP TRBL DRLPR DRI LL DRLPR DRILL DESCRIPTION Dir drill and survey F/10040' to 10152'(ART=7.28hrs AST=Ohrs). Dir drill and survey F/10152' to 10345'(ART=14.58hrs AST=Ohrs). ËCD10.11 MUDDATAIDÄILYCOST 1 8037.00 FCIT.SOL OM %Sand/MBT Ph/pl\II Pf/Mf CIICa 2.0/8.0 192 /6.0 9.1010.2 0.2/1.5 28,000 160 I CUM COST 196469.00 CaCI2(Wt%;1-i2S LIME .. ES 6RPM 16 BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETSORTFA DEPTH IN··.DATEJN I-O-D~L-B-G"O-R 17/1 6.125 Hughes HCM406 7102176 15/15/15//11111 8,772.0 2/24/2003 1-1-WT-N-D- I-CT-LOG BIT I RUN WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CU M ROP 17 11 2/10 70 I 80 295 2,100 282 21.86 305.0 13.95 60.18 1,573.0 26.14 BHA EFFWT. ¡PICKUP ISLACKOF1ROTWT. \TORQUE(maxlmin) IBHAHRS JARHRS MWDHRSI.MTRHRS ISS HRS 13,000 200,000 115,000 150,000 120,000 1 10,000 Hughes HCM406 , 4-3/4" Mach1 XL (.8 AKO) , String Stabalizer (6") , MWD Tool, Hang-Off Sub, HT-38 B X 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4), 3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 BHANO. I LENGTH 17 564.90 BHA DESCRIPTION PUMP 1 HYDRAULIC DATA NO. MAKE OF PUMP STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM . r PRESSURE 1 OILWELL 8.000 4.000 80 98.18 2,100 294.54 60 620 2 OILWELL 8.000 4.000 80 98.18 2,100 294.54 60 610 3 OILWELL 8.000 4.000 80 98.18 2,100 294.54 60 610 MUD GAS UNITS 0 AVG. CONN: AVG. TRIP: AVG. BKGRD: 5 MAX. CONN: MAX. TRIP: MAX. DRL: 30 MD 9,920 AZIMUTH 340.50 SURVEY DATA TVD VS N/S CUM EIW CUM DOGLEG MD INCL 9,770.29 609.14 -591.08 -162.00 0.59 9,982 7.40 TVD VS N/S CUM EJW CUM DOGLEG 9,831.82 602.32 -583.79 -164.38 1.12 INCL 6.80 AZIMUTH 343.30 Printed: 3/12/2003 2:46:17 PM ) c .. .....J6 \1T'AtMÄ~TH()N O!L ÇOM~Þ.NY ~~t~Ar "01{ 2::0 ~G::::~:I~~I~;~~:~~'345· ') page 20f 2 TVD IDFS IDOL IRPT# I DATE 10,192 29 37 37 28-Feb-2003 MD 10,045 10,106 INCL 7.30 7.50 AZIMUTH 340.20 341.60 . SURVEY DATA TVD VS N/S CUM E/W CUM DOGLEG MD INCL 9,894.30 595.16 -576.14 -166.90 0.65 10,169 7.80 9,954.79 588.23 -568.72 -169.47 0.44 10,231 7.90 AZIMUTH TVD VS N/S CUM E/W CUM DOGLEG 340.20 1 0,017.2~ 580.83 -560.79 -172.21 0.,;i6 340.20 10,078.65 573.41 -552.83 -175.08 0.16 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO, HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Halliburton Sperry Sun 2 48.00 POB @ 06:00: NO. HOURS 4 48.00 1 12.00 1 12.00 2 24.00 LAST BOP TEST: 2/22/2003 SIZE (in)ID(in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (tt) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ib/tt) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:17 PM ) ) k1 t:; DE \"'" MARATHON OIL C0MPANY r .\, J .. .', : fAL Daily Drilling Report WELLNlßHT HOli ' GLEXPloitatl:~:::STMD TVD ABALONE 1 21.0 I 282.00 11.0 10,356 10,203 SUPERVISOR RIG NAME & NO. AUTH MD WBS R C Lawson GLACIER DRILLING 1 FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STAT E/P ROV Alaska CURRENT STATUS I MTS Inspect Compound box. OPERATION COMMENTS Drill F/10345' to 10356'. CBU. POOH. Rig repair. POOH. Rig repair. POOH. Inspect compound box. POOH. LID directional tools. P/U LWD tools. RIH to CSG shoe. Inspect compound box. PagE:}lof 2 MOCWI 907 -283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) @ 4,336 (ft) 124 HR FORECAST Log LWD. NRI I DFS I DOL I RPT # DATE 30 38 38 01-Mar-2003 SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 I DAILY WELL COST I CUM WELL COST I I NEXT CASING I LEAKOFF 3.500 (in) @ 10,140 (ft) 16.32 SAFETY·SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 396.00 None 2/27/2003 2/22/2003 2/28/2003 2/23/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Radioactive source handling. OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION. 06:00 07:30 1.50 10,345 10,356 CS DRLPR DRILL Drill and survey F/10345' to 10356'(ART=1.5hrs AST=Ohrs). 07:30 10:00 2.50 10,356 10,356 AF DRLPR CIRC CBUX2. Pump Dry job. 10:00 14:00 4.00 10,356 10,356 AF DRLPR TRIP POOH(SLM) to 6326'. 14:00 16:00 2.00 10,356 10,356 TA DRLPR RIG SHST Compound box for drawworks overheating. Cooling pumps malfunctioned. Connect external cooling pump. 16:00 17:00 1.00 10,356 10,356 AF DRLPR TRIP Cont. POOH(SLM) to CSG shoe. 17:00 19:30 2.50 10,356 10,356 TA DRLPR RIG SHST Repair cooling pumps on compound box. 19:30 20:30 1.00 10,356 10,356 AF DRLPR TRIP Cont. POOH(SLM) to 2110'. 20:30 21:30 1.00 10,356 10,356 TA DRLPR RIG SHST Repair fitting on compound box. 21:30 22:30 1.00 10,356 10,356 AF DRLPR TRIP Cont. POOH(SLM). 22:30 23:00 0.50 10,356 10,356 TA DRLPR RIG SHST Inspect compound box. 23:00 00:00 1.00 10,356 10,356 AF DRLPR TRIP POOH. LID motor and MWD. No correction on SLM. 00:00 01:00 1.00 10,356 10,356 AF EVALPR MwdLwd Clean rig floor and prepare to P/U LWD tools. 01:00 03:00 2.00 10,356 10,356 AF EV ALPR MwdLwd PIU Halliburton LWD tools. Safety meeting prior to installing radioactive sources. Install sources in LWD tools. 03:00 05:00 2.00 10,356 10,356 AF EVALPR TRIP RIH W/LWD to CSG shoe. 05:00 06:00 1.00 10,356 10,356 TA EVALPR RIG SHST Drain oil and inspect gears in compound box. DENSITY(ppg) FV PVIYP 45 10/29 9.50 GELS 14/18 I PP I WUHTHP 7.81 ECDI10.11!MUD DATAl DAILY COST I 2975.00 FCfT.SOL OIW %Sand/MBT Ph/pM Pf/Mf CIICa 2.0/8.0 192 0.25/6.0 9.5010.4 0.312.2 27,000/60 I CUM COST 199444.00 CaCI2(wt%; H2S LIME ES 6RPM 14 BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 17 11 6.125 Hughes HCM406 7102176 15/15/1511/1111 8,772.0 2/24/2003 1-1-WT-N-D- I-CT-LOG 18 IRR 1 6.125 Hughes HCM406 7102176 15/15/151111111 10,356.0 3/1/2003 1-1-WT-N-D- I-CT-BHA BIT / RUN WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 17 11 2/10 70 I 80 290 2,100 273 1.45 11.0 7.59 61.63 1,584.0 25.70 181 RR1 I I 295 2,100 Printed: 3/12/2003 2:46:20 PM ) ) I N~JA····· ····.··l· MARATHONOIL.CGMPANY IL~~r H0i4KB:1.0 Dally Dril ling RepoH Exploitation. Gas IGL 124 HR PROGITMD 282.00 11.0 10,356 Page 2pf 2 TVD I DFS I DOL I RPT # I DATE 10,203 30 38 38 01-Mar-2003 BHA EFFWT.PICK UP SLACK OF1ROT WT. TORQUE(~ax/min) BHAHRSJAR HRS, I MWD HRS MTR HRS SS HRS Hughes HCM406 , 3 1/2" Reg X 3 1/2" IF BS , LWD GR-RES , LWD Den-Neut , LWD Sonic, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4), 3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 BHA NO. LENGTH 18 575.96 BHA DESCRIPTION NO, 1 2 3 MAKEOFPUMP PUMP! HYDRAULIC DATA STROKE (in) LlNE~ (in) SPM Q (gpm) 8.000 4.000 80 98.18 8.000 4.000 80 98.18 8.000 4.000 80 98.18 PRESS. (psi) TOTAL Q 2,100 294.54 2,100 294.54 2,100 294.54 KILL SPM ,. PRESSURE 60 620 60 610 60 610 OILWELL OILWELL OILWELL AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: UNITS COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Baker Hughes Inteq SERVICE PERSONNEL DATA NO. .HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Halliburton Sperry Sun 2 36.00 LAST BOP TEST: 2/22/2003 SIZE (in) ID(in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD(ft) TVD(ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (lblft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 14.51 16.32 o 5 22 POB @ 06:00:. NO. HOURS 4 36.00 1 12.00 1 12.00 2 24.00 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:20 PM ) ) MARATHON OIL COMPANY f ;~!i ~ H T H ~I'~1~' ~G:~2::::~:~I~~~~::~~'356 SUPERVISOR RIG NAME & NO. AUTH MD R.C. Lawson GLACIER DRILLING 1 FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS I MTS Logging LWD. OPERATION COMMENTS Rig repair. Log LWD F/4316' to 6563'. TVD I DFS 10,203 31 WBS Pagel of2 I DOL I RPT # DATE 39 39 02-Mar-2003 SAPIWBS COST 2,695,000 CUM WELL COST MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) ~ 4,336 (ft) 124 HR FORECAST Log LWD. DX.02.07227 .CAP .DRL I DAILY WELL COST I NEXT CASING 3.500 (in) ~ 10,140 (ft) NRI MANHRS WORKED I ACCIDENT TYPE 352.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: SAFETY SUMMARY ¡BOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/22/2003 2/28/2003 I LAST SAFETY MTG 2/27/2003 LEAKOFF 16.32 I LAST RIG INSPECTION 2/23/2003 FROM 10,356 10,356 TO SUB 10,356 TA 10,356 AF OPERATIONS SUMMARY PHASE OP TRBL DESCRIPTION EV ALPR RIG SHST inspect gears, assemble compound box and fill with clean oil. EVALPR LOG Log LWD F/4416' to 6563'. FROM TO HRS 06:00 10:00 4.00 10:00 06:00 20.00 DENSITY(ppg) I FV PVIYP 42 10/25 Ippl WUHTHP 7.61 I ECD9.97IMUD DATAl DAILY COST I 2975.00 Fcrr.SOL OIW %Sand/MBT Ph/pM Pf/Mf CIICa 2.0/8.0 192 /6.0 9.40/0.2 0.112.5 25,500/60 ¡CUM COST 202419.00 CaCl2(wto,to: H2S LIME ES 6RPM 14 9.40 GEL.S 14/17 BIT/RUN SIZE 18/RR1 6.125 MANUF, TYPE SERIAL NO, Hughes HCM406 7102176 WOB RPM GPM PRESS / / 198 704 BITS JETS·OR TFA 15/15/151111I11 DEPTH IN. DATE IN 10,356.0 3/1/2003 I-O-D~L-B-G·O·R 1-1-WT-N-D-I-CT-BHA BIT / RUN 181 RR1 PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP BHA EFFWT. ¡PICKUP \SLACKOF1ROTWT. I TORQUE·(maxlm¡n) BHAHRS ··\JARHRS· MWDHRSIMTRHRS SS HRS o 110 100 100 17,000 Hughes HCM406 , 3 1/2" Reg X 31/2" IF BS , LWD GR-RES , LWD Den-Neut, LWD Sonic, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4), 3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 BHANG. ·\LENGTH 18 575.96 BHA DESCRIPTION NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 4.000 85 104.32 700 197.59 8.000 4.000 76 93.27 704 197.59 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Gate Guard 1 24.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent SERVICE KILL SPM / PRESSURE 60 300 60 290 UNITS o 5 POB @ 06:00: NO. HOURS 2 24.00 2 24.00 1 12.00 Printed: 3/12/2003 2:46:23 PM ) ) G . 'iIDeN:IA~~RATH~N;QìLGOMÞ~NY Tf ,Jî r·H 0 l E Da~~Þ~:::~ti~n~fs°rt WELL NAME I KB I GL 124 HR PROG I TMD I TVD I DFS I DOL ABALONE 1 21.0 282.00 10,356 10,203 31 39 COMPANY R&K Industrial SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 16.00 Halliburton Sperry Sun SERVICE IRPT# I DATE 39 02-Mar-2003 POB @ 06:00: NO. HOURS 2 24.00·' LAST BOP TEST: 2/22/2003 SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAXSICP MD (ft) TVD(ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:23 PM O·NFf.D.E 1\ ItIAlARA1"HØNÓlkCØMPANY ~·~···G· ··H't.H·IO· ··LE···· ..... ... ' Da~~p~.:::~t7;n~:S°rt '.' II- ~ '... ~.~ WELL NAME KB I GL 124 HR PROG TMD ABALONE 1 21.0 282.00 10,356 SUPERVISOR RIG NAME & NO. AUTH MD R.C. Lawson GLACIER DRILLING 1 FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENTSTATUS/MTS Log LWD. OPERATION COMMENTS LWD F/6563' to 6940'. ') ) TVD I DFS I DOL I RPT # DATE 10,203 32 40 40 03-Mar-2003 WBS SAPIWBS COST DX.02.07227.CAP.DRL 2,695,000 I DAILY WELL ~OST I CUM WELL COST I NEXT CASING I LEAKOFF 3.500 (in) ~ 10,140 (ft) 16.32 MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) @ 4,336 (ft) 124 HR FORECAST Log LWD. POOH. NRI Rig repair.LWD F/6940' to 7125'. Rig repair. LWD F/7125' to 9000'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT ¡ RNEGULATORY INSP? 344.00 None 2/27/2003 2/22/2003 2/28/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 10:00 4.00 10:00 11:00 1.00 11 :00 12:30 1.50 12:30 13:30 1.00 13:30 06:00 16.50 DENSITY(ppg) I FV PVIYP 42 9125 BIT/RUN SIZE 18/RR1 6.125 BIT / RUN 18 I RR1 SHANO. I LENGTH 18 575.96 SHA DESCRIPTION I LAST RIG INSPECTION 2/23/2003 OPERATIONS SUMMARY FROM TO SUB PHASE OP TRBL DESCRIPTION 10,356 10,356 AF EV ALPR LOG LWD F/6563' to 6940'. 10,356 10,356 TA EVALPR RIG TOPS Repair TDS grabber. 10,356 10,356 AF EV ALPR LOG LWD F/6940' to 7125'. 10,356 10,356 TA EVALPR RIG TOPS Repair TDS grabber. 10,356 10,356 AF EV ALPR LOG LWD F/7125' to 9000'. 9.45 GELS 13/16 Ippl WUHTHP 7.81 IECD 19.97 >I\IIUD.DATADÄ'LY COST I 6162.00 FCfT;SOL O/w %Sanc:fflviBT Ph/pM Pf/Mf CI/Ca 2.0/8.0 192 /6.0 9.3010.1 0.112.6 24,500/80 I CUMCOST 208581.00 ~aCI2(wt%: _ H2$ LIME ES 6RPM 13 MANUF. TYPE SERIAL NO. Hughes HCM406 7102176 WOB RPM GPM PRESS I I 209 968 BITS JETS OR TFA 15/15/151111111 I·O·D~L~B·G~O·R 1-1-WT-N-D- I-CT-BHA DEPTHINOATE IN 10,356.0 3/1/2003 P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP BHA EFFWT. ¡.PICKUP \SLACKOF1ROTWT. ·\TORQUE(maxlm¡n) SHAHRS \JARHRS ·IMWDHRSMTRHRS SS HRS o 165,000 105,000 135,000 9,000/7,000 Hughes HCM406 , 3 1/2" Reg X 3 1/2" IF BS , LWD GR-RES , LWD Den-Neut , LWD Sonic, HT-38 B X 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4),3-1/2" IF B x HT-38 P , Daily Jar. HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 4.000 85 104.32 968 208.64 8.000 4.000 85 104.32 968 208.64 NO. MAKE OF PUMP 1 OILWELL 2 OILWELL AVG. CONN: MAX. CONN: KILL SPM / PRESSURE 60 435 60 430 MUD GAS AVG. TRIP: MAX. TRIP: UNITS o 5 AVG. BKGRD: MAX. DRL: Printed: 3/12/2003 2:46:26 PM ') ') C. N f. E \/J;IAl.MA~::.~::~~~:::::NY ~~l~Hr HO~ 21.0 IGLE::::ital:~:::iTM:O'356 TVD IDFS IDOL 10,203 32 40 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard PERSONNEL DATA NO. HOURS COMPANY SERVICE 17 204.00 Epoch Well Services 1 24.00 M-I Drilling Fluids Cent 1 24.00 R&K Industrial 2 24.00 Halliburton Sperry Sun SERVICE LAST BOP TEST: 2/22/2003 SIZE (in) ID(in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) TVD(ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ibltt) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 14.51 16.32 Page20f2 RPT # I DATE 40 03-Mar-2003 POB@ 06:00: NO. HOURS 2 24.(0 1 12.00 1 8.00 2 24.00 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:26 PM 'C ..... N' ..JDr:t\rIAtAaAtH~NØII2CØMPAN" fiG···· ALITuO· ... ... ·l· ··'E· ... .... ...,.... j DailyDrHlingReport "I ,. n.:. Ft,····.' Exploit¡¡tionGas I GL 124 HR PROG TMD 21.0 282.00 10,356 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS 1 MTS BOP test. OPERATION COMMENTS LWD F/9000'to 10356'. CBU. POOH. Test BOPE. ') ') Page t()f2 KB TVD IDFS IDOL 10,203 33 41 WBS I RPT # DATE 41 04-Mar-2003 SAPIWBS COST 2,695,000 CUM WELL COST RIG PHONE DX.02.07227.CAP.DRL I DAILY WELL COST I NEXT CASING 3.500 (in) @ 10,140 (ft) LEAKOFF 16.32 MOCWI 907-283-1312 60.0000 COUNTYIOTHER I LAST CASING Kenai 9.625 (in) @ 4,336 (ft) 124 HR FORECAST BOP test. Rig work. NRI SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/22/2003 2/28/2003 I LAST RIG INSPECTION 2/23/2003 MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 345.00 None 3/4/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Radioactive sources. FRo.M TO. HRS 06:00 18:00 12.00 18:00 20:00 2.00 20:00 02:00 6.00 02:00 04:00 2.00 FRo.M 10,356 10,356 10,356 10,356 04:00 06:00 2.00 10,356 DEN$lrv(ppg) FV PVNP 43 9/26 I PPI WUHTHP 7.61 9.45 GELS 13116 TO. SUB 10,356 AF 10,356 AF 10,356 AF 10,356 AF OPERATIONS SUMMARY PHASEo.P TRBL EV ALPR LOG EVALPR CIRC EV ALPR TRIP EVALPR TRIP DESCRIPTION 10,356 AF EV ALPR TEST LWD F/9000' to 10356'. CBU w/300GPM. Flow check. Pump dry job. LID single. POOH. Safety meeting prior to pulling radioactive sources. Pull radioacvtive sources from LWD. Down load data from LWD memory. LID LWD B/O bit. Pull wear bushing. Run test plug. Test BOPE. IECD I 9.97 MUDDÄTAI>DAILYCo.STI 6470.00 FCIT.So.L o.lW %SandIMBT Ph/pM pt/Mf CIICa 2.0/8.0 192 /6.0 9.5010.3 0.312.8 23,000/80 I CUM.COST 215051.00 CaCI2(wt%: H2S LlM.E ES 6RPM 13 BITS JETSo.R TFA 15/15/151111I11 BIT/RUN SIZE 18/RR1 6.125 l~o.·D-L·B-G-O-R 1-1-WT-N-D- I-CT-BHA MANUF. TYPE SERIAL NO.. Hughes HCM406 7102176 Wo.B RPM GPM PRESS I 209 1,100 BIT / RUN 18 I RR1 P BIT 24Hr DIST 24Hr Ro.P CUM HRS CUM DEPTH CUM Ro.P HRS BHA EFFWT. PICKUP ISLACKOF~ROTWT. TORQUE(maxlmin) IBHAHRS IJARHRS MWDHRSIMTRHRS ISS.HRS o 205,000 115,000 I 150,000 I 10,000 Hughes HCM406 , 3 1/2" Reg X 3 1/2" IF BS , LWD GR-RES , LWD Den-Neut , LWD Sonic, HT-38 B X 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4), 3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 BHANO. I LENGTH 18 575.96 BHA DESCRIPTION NO.. 1 2 MAKE o.F PUMP OILWELL OILWELL AVG. Co.NN: MAX. Co.NN: PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 4.000 85 104.32 1,100 8.000 4.000 85 104.32 1,100 To.TAL Q 208.64 208.64 KILL SPM / PRESSURE 60 435 60 430 MUD GAS AVG. TRIP: MAX. TRIP: UNITS o 5 AVG. BKGRD: MAX. DRL: Printed: 311212003 2:46:29 PM ) IC. ..N I DS,V1IAr:ARA~HO~~ILØOM+NY ~···!·.··.G. ... ··H. ··1 .-' ...0····· ...'f.. .... ........ .. DaIIYDrl.I...hng.......Re.>p..ort L'I' ~,..,( t .... ..', Exploitation Gas WELL NAME KB I GL 124 HR PROG I TMD ABALONE 1 21.0 282.00 10,356 COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard Epoch Well Services SERVICE LAST BOP TEST: 2/22/2003 SIZE(in) ID(in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 14.51 9.625 8.835 16.32 ') ITVD IDFS IDOL 10,203 33 41 PERSONNEL DA"FA NO. HOURS COMPANY SERVICE 17 204.00 M-I Drilling Fluids Cent.¡¡ 1 24.00 R&K Industrial 1 24.00 Halliburton Sperry Sun 2 24.00 S&R Enterprises 2 24.00 CASING SUMMARY LAST CASING TEST: 2/16/2003 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 Page 2 of 2 RPT# ¡DATE 41 04-Mar-2003 POB@ 06:00: NO. HOURS 1 12.00 1 8.00 2 24.00 1 1.00 3/1/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:29 PM ) ....... .F j DE 1\ '·rIÂt~~A1~ØNØIl-ØØM~t\N~ T ~G···· .. ·H·····TU..·... 1...0·. ·..·l· ..........r=.Dai.JY.Dr....illi.·..~....g. R......e.p()('t ;.. .. .. ::..... .. n ..1: ExploltabonGas I GL 124 HR PROG TMD 21.0 282.00 10,356 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS C/O to long bales. OPERATION COMMENTS Test BOPE. UD jars. KB C) Page1Öf2 TVD I DFS 10,203 34 WBS IDOL 42 I RPT # DATE 42 05-Mar-2003 SAPIWBS COST 2,695,000 CUM WELL COST 907 -283-1312 COUNTY/OTHER Kenai DX.02.07227 .CAP .DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 9.625 (in) @ 4,336 (ft) 3.500 (in) @ 10,140 (ft) 124 HR FORECAST Set retainer pump cement. Run completion assy. LEAKOFF 16.32 Service and repair rig. UD HWDP. Clean rig floor. Strap and caliper retainer. RIH wI retainer. cIa to long bales. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 330.00 None 3/4/2003 3/5/2003 2/28/2003 N 2/23/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 06:00 08:00 2.00 TO SUB 10,356 AF OPERATIONS SUMMARY PHASE OP TRBL EV ALPR TEST FROM 10,356 08:00 08:30 0.50 08:30 10:30 2.00 10:30 12:00 1.50 12:00 00:00 12.00 10,356 10,356 10,356 10,356 10,356 AF 10,356 AF 10,356 AF 10,356 AF EVALPR EQUIP EV ALPR WAIT EVALPR WAIT EV ALPR WAIT 00:00 01:30 1.50 10,356 10,356 AF PLUGAB WAIT 01:30 02:30 1.00 10,356 10,356 AF PLUGAB WAIT 02:30 03:00 0.50 10,356 10,356 AF PLUGAB PKRPLG 03:00 05:30 2.50 10,356 10,356 AF PLUGAB PKRPLG 05:30 06:00 0.50 10,356 10,356 AF PLUGAB WAIT DENSITY(ppg) FV PVNP 42 10/21 I PP I WUHTHP 9.81 I ECD 19.991 MUD DATAl DAILY COST I 1314.00 Fcrr.SOL OIW %Sand/MBT Ph/pM Pf/Mf Cl/Ca 2.0/8.0 192 /6.0 9.5010.2 0.3/2.8 22,500/80 I CUM COST 216365.00 CaCI2(wt%; H2S LIME ES 6RPM 11 9.50 GELS 11/14 DESCRIPTION Test upper variable rams, lower pipe rams, blind rams, choke and kill line valves to 250psi/3500psi 5min. Test 1-12 CMV, upper and lower TDS valves, TIW and IBOP valves to 250psi/3500psi 5min. Perform accumulator test. Pull test plug and set wear bushing. UD 4 3/4" Jars. Slip and cut drill line. Service TDS and rig. C/O solenoid #1 carrier motor. Repair spring and adjust kick rollers, inspect linkage, remove guards and tighten loose brake pad nuts. Remove oil pump from compound box, rebuild d-works drum clutch. Clean top drive, rig floor and carrier. Remove TDS service line tarp and clean lines and tarp. Install service line tarp. Clean out sub legs. Weld pad eye to bottom snub post. Clean drip pans under rocking board rig floor. C/O grabber switch. Remove disc brakes guard and clean. Change oil and oil filters #3 mud pump. UD 15 JNTS 4" HWDP. Steam clean rig floor. M/U 9 5/8" Baker retainer. RIH w/9 5/8" Baker retainer and cement stinger to 4283'. C/O to long bales. BHA BHA1 ~o. I LE~G;2H I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS BHA DESCRIPTION 95/8" Baker cement retainer, X/O 3 1/2" IF-B X 2 7/8" EUE-P ,X/a 3 1/2" IF-P X HT-38-B ,4" 14PPF HT-38 DP Printed: 3/12/2003 2:46:31 PM ) CP·Nfl~l tiGHT HOLE WELL NAME ABALONE 1 AVG. CONN: MAX. CONN: COMPANY Inlet Drilling Alaska Marathon M-I Drilling Fluids Gate Guard SERVICE LAST BOP TEST: 3/5/2003 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 IKB 21.0 ) MARAl7HØNOIEG0MPANY Dai lyDrilnn.~....·.~epørt . Expl.oitation .Gas IGL 282.00 24HRPROGITMD ITVD DFS IDOL IRPT# ¡DATE 10,356 10,203 34 42 42 05-Mar-2003 MUD GAS AVG. TRIP: MAX. TRIP: PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Epoch Well Services 1 24.00 Halliburton Sperry Sun 1 24.00 Baker Oil Tools 2 24.00 BJ Services CASING SUMMARY LAST CASING TEST: 2/16/2003 MAXSICP MD(ft) TVD (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 1,486 (psi) @ 9.50 (ppg) 4,336 4,194 AVG. BKGRD: MAX. ÓRL: SERVICE NEXT BOP TEST: VVT (lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 UNITS o 5 POB @06:00: NO. HOURS 2 24.00 2 18.00 1 4.00 4 8.00 3/12/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:31 PM ) ÇQ'!~IA~~~~~ØPlØILQ~~~~~Y TIG(~1 HOLE ... [)ai~y[)rillin~.~eport Exploitation Gas I GL 124 HR PROG TMD 21.0 282.00 10,356 RIG NAME & NO. AUTH MD GLACIER DRILLING 1 WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Pulled retainer assembly out of hole. OPERATION COMMENTS Set 9 5/8" retainer. Perform squeeze below retainer and leave 50' of cement above retainer. KB ) TVD I DFS I DOL 10,203 35 43 WBS I RPT # DATE 43A 06-Mar-2003 SAPIWBS COST 2,695,000 CUM WELL COST 907-283-1312 COUNTY/OTHER Kenai DX.02.07227 .CAP. DRL MOC WI NRI I DAILY WELL COST 60.0000 I LAST CASING I NEXT CASING 9.625 (in) @ 4,336 (ft) (in) @ 0 (ft) 124 HR FORECAST Displace well to water and run GBL. RIG PHONE I ACCIDENT TYPE 204.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: High Pressure lines. SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 3/4/2003 N LEAKOFF 16.32 POOH UD DP. (End of drilling event.) FROM TO fiRS FROM TO SUB 06:00 07:00 1.00 10,356 10,356 AF 07:00 08:00 1.00 10,356 10,356 AF 08:00 09:00 1.00 10,356 4,283 AF OPERATIONS SUMMARY PHASE OP TRBL PLUGAB PKRPLG PLUGAB WAIT PLUGAB PKRPLG 09:00 09:30 0.50 4,283 4,283 AF PLUGAB PKRPLG 09:30 10:30 1.00 4,283 4,283 AF PLUGAB CEMT 10:30 11:30 1.00 4,283 4,233 AF PLUGAB CEMT 11:30 12:00 0.50 12:00 12:30 0.50 12:30 14:30 2.00 4,233 4,233 4,233 14:30 17:00 2.50 4,233 DENSITY(ppg) 8.34 l PP l FV PVNP GELS WLlHTHP I I 4,233 AF PLUGAB CEMT 4,233 AF 4,233 AF PLUGAB CIRC PLUGAB CIRC 4,233 AF PLUGAB TRIP DESCRIPTION Cont. CIO to long bales. While waiting on final orders prepare floor for squeeze job. Set 9 5/8" Baker retainer @ 4283'. Safety meeting prior to cement job. With stinger in retainer test 9 5/8" X DP annulus to 2500psi/5min. Bleed off pressure. Sting out of retainer. Pump 2bbls ahead and test cement lines to 4000psi. Replace low torque valve on end of cement hose. Test lines to 4000psi. Test CSG to 2500psi/5min. Displace DP with 40bbls fresh water. Sting into retainer. Establish injectivity of 4bbl/min 1850psi. Mix and pump 75sxs class"G" cement w/0.2%CD-32, 0.1 %R-3, 0.2%SMS, and 1 ghs FP-6L to yield 15bbls 15.8ppg slurry. Displace w/1bbl water and 39bbls 9.5ppg mud. Top of cement estimated to be at 4233'. Bottom of cement estimated to be at 4436'. Sting out of retainer and leave 5bbls cement on top of retainer. POOH to 4190'. Reverse two DP volumes. No cement to surface. Blow down BJ lines and cement lines. C/O to short bales. Mix and pump dry job. Blow down eirc. lines and choke manifold lines. POOH UD DP. UD Baker running tool. Clean mud pits. tECD FCIT.SOL I ¡MUD DATAl DAILY COST OIW %Sand/MBT Ph/pM Pf/Mf I I I 1668.00 CI/Ca I CUM COST 218033.00 CaCI2(wt%: H2S LIME ES 6RPM ¡=<ECEI\iE[) r.IiJ~ V 1 -='.J i) r :{ hi 'í ! .J ~~;.j1),.' i\Jaa-k12 G~: ~ G&~ C:.;.~·~~. ~.';~;mT~~~T! ¡~'~ìl~~ Printed: 3/12/2003 2:46:34 PM ) COI'4·f·'D.:,~r'.TH~~.·..~lkØØMÞAN* rIG.' .... u,...1II! ···H.·..·.. ··0.····. ·..·.··.l··· . ··e···· ..tJàily.....D....r.....~...Ii~...9...............R...e.......p.........o. rt l , _ .. ..... . Exploltabon Gas I KB GL 124 HR PROGTMD 21.0 282.00 10,356 ') Page··2 . ö.f.2 WELL NAME ABALONE 1 rVD IDFS IDOL RPT# I DATE 10,203 35 43 43A 06-Mar-2003 BHA NO. LENGTH 19 8.02 BHA DESCRIPTION BHA EFF ~T. PICK UP I SLACK OFF ROT WT. TORQUE (jaxlmin) BHA HRS _JAR HR~, I MWD HRS I MTR H~S .BS H~~ 95/8" Baker cement retainer, X/O 3 1/2" IF-B X 27/8" EUE-P , X/O 3 1/2" IF-P X HT-38-B ,4" 14PPF HT-38 DP COMPANY Inlet Drilling Alaska Marathon R&K Industrial Epoch Well Services M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 94.00 Weaver Brothers (WBI) 1 11.00 Lynden Transport 4 17.00 Baker Oil Tools 2 11.00 BJ Services 1 11.00 SERVICE POB @ 06:00: NO, HOURS 1 5.00 1 1.00 1 6.00 4 48.00 LAST BOP TEST: 3/4/2003 SIZE (in) ID (in) . SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 14.51 16.32 CASING SUMMARY LAST CASING TEST: 3/6/2003 MAX SICP MD (ft) ND (ft) (psi) @ (ppg) 170 170 600 (psi) @ 9.00 (ppg) 2,208 2,097 3,556 (psi) @ (ppg) 4,336 4,194 NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 K-55 40.00 L-80 3/11/2003 BURST (psi) 3,060 3,450 5,750 Printed: 3/12/2003 2:46:34 PM CQ\''JIALN)r······ ... ... ·.··.··i 1,': ì4-'1: ... . 'A~l'HØN>ØIL.COMP~NY ... ilGb r ·HOlE>ailYCorr¡PletiønRepOH Exploitation· -Gas IGL 21.0 282.00 RIG NAME & NO. GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS I MTS Displace well to fresh water. OPERATION COMMENTS RIH w/8.5" bit and 9 5/8"CSG scraper. \24 HR PROG TMD TVD I DFSO 10,356 10,203 AUTH MD WBS 10,166 MOCWI 907-283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) ~ 4,336 (ft) 124 HR FORECAST Run completion. KB MANHRS WORKED I ACCIDENT TYPE \ LAST SAFETY MTG 177.00 None 3/5/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: High Pressure lines. FROM 17:00 19:00 21:30 02:00 03:00 FROM 4,233 4,233 4,233 4,233 4,233 TO 19:00 21:30 02:00 03:00 06:00 HRS 2.00 2.50 4.50 1.00 3.00 PE~SITY'{Ppg)· f=V PVIYP / ppl WL)HTHP / 8.34 GELS / TO SUB 4,233 AF 4,233 AF 4,233 AF 4,233 AF 4,233 AF Ecb FCf1";SOL / ') \DO\ NRI DX.02.07227.CAP.CMP I DAILY WELL COST \ NEXT CASING (in) ~ 0 (ft) SAFETYSU M MARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 3/4/2003 OPERATIONS· SUMMARY PHASE OP TRBL WBPR TRIP WBPR FLUID WBPR TRIP WBPR TEST WBPR FLUID Pagel.of~ IRPT # DATE 43B 06-Mar-2003 SAPIWBS COST 1,465,000 CUM WELL COST LEAKOFF 16.32 \ LAST RIG INSPECTION DESCRIPTION RIH w/4" DP 1500'. POOH UD DP. Clean mud pits. Cont. clean mud pits. Load trailers. RIH w/9 5/8" CSG scraper to 4200'. Test CSG to 1500psi 30min. Displace well to fresh water. I MI.JDDATÀIDAIL'(COsrl OIW oJoSand/MBT Ph/pM Pf/Mf I / I 1971.00 CIICå !CUMCOST 1971.00 CaCI~{wt%: H2S LIME ES 6RPM BITS JETS OR TFA BIT/RUN 19 /RR 1 DEPTH IN DATE IN 4,233.0 3/5/2003 BIT I RUN WOB I-O-D-L~B-G-O~R 0-0------ RPM GPM I PRESS I P BIT HRS I 24Hr DIST 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BHA NO, ·1 LENGTH 20 499.81 BHA DESCRIPTION BHA . IEFFWT. !PICKUP ISLACKOF1ROTWT. \TORQUE(maxlmin) IBHA HRS ¡JAR HRS MWDHRS IMTR HRS .\SSHRS o 90,000 65,000 I Tri-Cone Bit, 95/8" CSG Scraper, Bit Sub, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4),3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe -11 (11),4" HT-38 S-135 NO. MAKE OF PUMP 1 OILWELL 2 OILWELL COMPANY Inlet Drilling Alaska Marathon R&K Industrial Epoch Well Services PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM / PRESSURE 8.000 4.000 110 135.00 600 282.27 8.000 4.000 120 147.27 600 282.27 SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 111.00 M-I Drilling Fluids 1 13.00 Weaver Brothers (WBI) 4 20.00 Lynden Transport 2 13.00 SERVICE p~s @ 06:00: NO. HOURS 1 13.00 1 5.00 1 2.00 Printed: 3/12/2003 3:02:51 PM ) C~~.~·'.)ENtJAl " IGHT HOLE WELL NAME ABALONE 1 MARATHONQILCGMPANY Daily Completion Report Exploitation.. Gas I GL 124 HR PROG I TMD I TVD I DFSO 282.00 10,356 10,203 Page 2 of2 IKB 21.0 DOL1 I RPT # I DATE 43B 06-Mar-2003 LAST BOP TEST: 3/4/2003 SIZE(in) 10 (in) SHOE TEST (ppg) 9.625 8.835 16.32 CASING SUMMARY LAST CASING TEST: 3/6/2003 MAX SICP MD (ft) TVO (ft) 3,556 (psi) @ (ppg) 4,336 4,194 NEXT BOP TEST: WT (lb/ft) GRADE 40.00 L-80 3/11/2003 BURST (psi) 5,750 Printed: 3/12/2003 3:02:51 PM CO.' . . ....... ........ .............\) ... .~F ¡ [JfNrIAlMARATHØNØí~$~MPA~Y rIG .'iTHO.·· ..... ... ·l· ··.··.E. ....Daily cornP..·..le. tiO.·..·.n..R...e. port Exploitation- Gas IGL 21.0 282.00 RIG NAME & NO. GLACIER DRILLING 1 RIG PHONE WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS N/D BOPE. OPERATION COMMENTS Displace well to fresh water. Scrape well twice 4200' to 2200'. BOPE. ) \24 HR PROG TMD TVD I DFSO \ DOL2 I RPT # DATE 10,356 10,203 44 07-Mar-2003 AUTH MD WBS SAPIWBS COST 10,166 DX.02.07227.CAP.CMP 1,465,000 MOC WI NRI I DAILY WELL COST I CUM WELL COST 907-283-1312 60.0000 ..-r- COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Kenai 9.625 (in) @ 4,336 (ft) (in) @ 0 (ft) 16.32 \24 HR FORECAST N/D BOPE. N/U tree. Test tree. RID rig. KB POOH UD DP and tools. Run cement evaluation logs. Run completion. N/D SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 3/4/2003 MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 307.00 None 3/5/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Electric line hazards. FROM 06:00 06:30 07:30 10:30 12:00 FROM 4,233 4,233 4,233 4,233 4,233 TO 06:30 07:30 10:30 12:00 14:00 HRS 0.50 1.00 3.00 1.50 2.00 I LAST RIG INSPECTION TO SUB 4,233 AF 4,233 AF 4,233 AF 4,233 AF 4,233 AF OPERATIONS SUMMARY PHASE OP TRB.L DESCRIPTION WBPR MUD Displace well to fresh water. WBPR TRIP POOH to 2200' with scraper and bit. WBPR TRIP RIH to 4200'. POOH to 2200'. RIH to 4200'. WBPR MUD Mix 6%KCL w/CRW-132 inhibitor. WBPR MUD Displace well to 6% KCL w/CRW-132 inhibitor. Blow down lines. 14:00 18:30 4.50 4,233 4,233 AF WBPR TRIP POOH UD DP. UD 9 5/8" scraper and 8.5" bit. 18:30 21:30 3.00 4,233 4,233 AF OTHER LOG RlU Schlumberger EL. Safety Meeting prior to EL operations. 21:30 01:00 3.50 4,233 4,233 AF OTHER LOG RIH w/CBL-USIT-GR log. Run log F/4200' to 1200'. POOH. RID Schlumberger. 01:00 01:30 0.50 4,233 4,233 AF RCMP PLRNRP Pull wear bushing. RlU to run 4 1/2" TBG. 01:30 03:30 2.00 4,233 4,233 AF RCMP PLRNRP Run 2-JTS 41/2" 12.6ppf L-80 tbg and land Vetco hanger(TBG bottom @ 107'RKB). TWC in hanger. B/O and UD landing joint. 03:30 06:00 2.50 4,233 4,233 AF RCMP NUND N/D BOPE. DENSITY(ppg) 8.60 I PP I IECD I MUD DATAl DAILYCOST 4713.00 I CUM COST 6684.00 FV PV/YP GELS WUHTHP FCfT.SOL O/w %Sand/MBT Ph/pM Pf/Mf CIICa CaCI2(wt%: H2S LIME ES 6RPM I I I I I I I BIT/RUN SIZE 19/RR1 8.500 MANUF. STC BIT I RUN WOB TYPE SERIAL NO. MS681 ER6059 RPM GPM I PRESS I BITS JETS OR TFA P BIT HRS DEPTH IN· DATE IN I·O·D·L·B-G·Q·R 4,233.0 3/5/2003 0-0----- I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BHA NO. \ LENGTH 20 499.81 BHA DESCRIPTION BHA \EFF WT. \PICK UP \ SLACK OF~ROT WT. !TORQUE (maximin) \BHA HRS \JAR HRS \MWD HRS IMTR HRS \SS HRS o 90,000 65,000 I 75,000 I Tri-Cone Bit, 9 5/8" CSG Scraper, Bit Sub, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 4 (4),3-1/2" IF B x HT-38 P , Daily Jar, HT-38 B x 3-1/2" IF P , Heavy Weight Drill Pipe - 11 (11),4" HT-38 S-135 Printed: 3/12/2003 3:02:53 PM ) ) 010..·... \It= I JE'NrlAlMARATHON GIL POMÞANY tG!"~T HOt..· ···.·e·· . Daily Completion Report Exploitation· -Gas \KB IGL 24 HR PROGTMD ITVD jDFS 21.0 282.00 10,356 10,203 0 Page 2 of 2 WELL NAME ABALONE 1 I DOL2 RPT# I DATE 44 07-Mar-2003 NO, MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTALQ KILL SPM I PRESSURE 8.000 4.000 110 135.00 500 270.00 8.000 4.000 110 135.00 500 270.00 COMPANY Inlet Drilling Alaska Marathon R&K Industrial M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Weaver Brothers (WBI) 1 24.00 Lynden Transport 4 36.00 ABB Vetco Gray 1 24.00 SERVICE POB @ 06:00: NO. HOURS 1 10.00 1 3.00 1 6.00 LAST BOP TEST: 3/4/2003 SIZE (in) ID (in) SHOE TEST (ppg) 9.625 8.835 16.32 CASING SUMMARY LAST CASING TEST: 3/6/2003 MAX SICP MD (ft) . TVD(ft) 3,556 (psi) @ (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ib/ft) GRADE 40.00 L-80 3/11/2003 BURST (psi) 5,750 Printed: 3/12/2003 3:02:53 PM c ,... N~'D· .. ... .) .... ?)'- i .ENl'IALARA17HÖNOILG0MPANV t I.GhT HO.lEDailYGOmPletionRepOrt ~ Exploitation ..Gas IGL 21.0 282.00 RIG NAME & NO. GLACIER DRILLING 1 WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TE/PROV Alaska CURRENT STATUS / MTS RID rig. OPERATION COMMENTS N/D BOPE. Install x-mas tree and test to 5000psi. RID rig. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT 372.00 None 3/5/2003 3/4/2003 ACCIDENT DESCRIPTION: LAST BOP TEST: 3/4/2003 SIZE (in) ID (in) SHOE TEST (ppg) 9.625 8.835 16.32 SAFETY MTG TOPICS: FROM TO HRS 06:00 08:30 2.50 08:30 12:00 3.50 FROM 4,233 4,233 12:00 00:00 12.00 4,233 00:00 06:00 6.00 4,233 DENSITY(ppg) FV PVNP I 8.60 GELS I I PP I WUHTHP I COMPANY Inlet Drilling Alaska Marathon R&K Industrial ) Page tof 1 124 HR PROG TMD TVD I DFSO 10,356 10,203 AUTH MD WBS 10,166 MOCWI 907 -283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) @ 4,336 (ft) \24 HR FORECAST RID rig. I RPT # DATE 45 08-Mar-2003 SAPIWBS COST 1,465,000 CUM WELL COST KB IDO~ RIG PHONE DX.02.07227.CAP.CMP I DAILY WELL COST \ NEXT CASING (in) @ 0 (ft) LEAKOFF 16.32 NRI I~EGULATORYINSP? I LAST RIG INSPECTION TO SUB 4,233 AF 4,233 AF OPERATIONS SUMMARY PHASE OP TRBL XMBO NUND XMBO NUND . DESCRIPTION 4,233 AF RDMO RIG NID BOPE. Install x-mas tree. Test tree void to 5000psi. Test tree to 5000psiw/50-50 methanol-water. Pull TWC. Set BPV. RID rig floor. Load out trailers to be moved. Move loads of drilling tools to Beaver Creek. Move rig office, mud loggers unit, and centrifuge unit to Beaver Creek. RID top drive and torque tube. RID rotary motor. RID Geronimc line and derrick board. 4,233 AF RDMO RIG ¡ECD Fcrr.SOL I I MUD DATAl DAILY.COSTI OIW "IoSand/MBT Ph/pM Pf/Mf I I I 0.00 CI/Ca I··CUMCOST 6684.00 CaCI2(wt%: ... H2S LIME ES 6RPM SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Weaver Brothers (WBI) 1 24.00 ABB Vetco Gray 4 36.00 Alaska Petroleum Contra POB@ 06:00: NO. HOURS 4 48.00 1 12.00 4 48.00 SERVICE CASING SUMMARY LAST CASING TEST: 3/6/2003 MAX SICP MD (ft) TVD (tt) 3,556 (psi) @ (ppg) 4,336 4,194 NEXT BOP TEST: WT (I bItt) GRADE 40.00 L-80 3/11/2003 BURST (psi) 5,750 Printed: 3/12/2003 3:02:56 PM ') C. .,N,r::JOEf [rlAt II'G;~r HOLE WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS RID rig. OPERATION COMMENTS RID rig. MANHRS WORKED I ACCIDENT TYPE 350.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Rig move. FROM TO HRS 06:00 12:00 6.00 FROM 4,233 12:00 00:00 12.00 4,233 00:00 06:00 6.00 4,233 DENSITY(ppg) FV PVNP I pþ I WUHTHP I 8.60 GELS I COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) LAST BOP TEST: 3/4/2003 SIZE (in) ID (in) SHOE TEST (ppg) 9.625 8.835 16.32 ') MARATHON. c)lL ØOMPANY Page JÖf1 Daily Com pletion Report Exploitation- Gas IGL 21.0 282.00 RIG NAME & NO. GLACIER DRILLING 1 RIG PHONE 124 HR PROG TMD TVD I DFSO 10,356 10,203 AUTH MD WBS 10,166 MOCWI 907 -283-1312 60.0000 COUNTY/OTHER I LAST CASING Kenai 9.625 (in) (éQ 4,336 (ft) 124 HR FORECAST Complete RID rig. IDO~ RPT# DATE 46 09-Mar-2003 SAPIWBS COST 1,465,000 CUM WELL COST KB NRI DX.02.07227.CAP.CMP I DAILY WELL COST I NEXT CASING (in) @ 0 (tt) LEAKOFF 16.32 I LAST SAFETY MTG 3/8/2003 SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 3/4/2003 I LAST RIG INSPECTION TO SUB 4,233 AF OPERATIONS SUMMARY PHASE OP TRBL RDMO RIG 4,233 AF RIG DESCRIPTION Winterize test pump. Fold up stabbing board. RID electric lines to console. RID trip tank. RID Beaver slide and cat walk. Scope down derrick. Tie up service lines. PJSM. RID electric, water and air. RID and load out dog houses. RID and load out fuel tank. UD derrick. RID carrier(tie-rod bent on carrier getting off of ramp). Split pits and RID outriggers. Remove derrick dog house. Cont. RID outriggers and load out. Move carrier. Scope down sub and prep for road. RDMO 4,233 AF RDMO RIG ECD FCIT.SOL I !MUDDATAIDAILYCOST OIW %Sand/MBT Ph/pM pf/Mf I I I 0.00 CIICa [CUMCOST 6684.00 CaCI2(wt%: H2$ LIME ES 6RPIVI SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 204.00 Alaska Petroleum Contra 1 24.00 Bill Hill 4 48.00 S&R Enterprises SERVICE POB@06:00: Nq. HOURS 4 48.00 2 24.00 2 2.00 CASING SUMMARY LAST CASING TEST: 3/6/2003 MAX SICP MD (ft) TVD (tt) 3,556 (psi) @ (ppg) 4,336 4,194 NEXT BOP TEST: WT (Ibltt) GRADE 40.00 L-80 3/11/2003 BURST (psi) 5,750 Printed: 3/12/2003 3:02:59 PM ') CO\ ::~DE,\JTIAl Ti.GHTHOLE ) MARATHON OIL.· COMPANY Page1of1 KB Daily Completion Report Exploitation -Gas IGL 21.0 282.00 RIG NAME & NO. GLACIER DRILLING 1 I DOL5 IRPT# DATE 47 10-Mar-2003 SAPIWBS COST 1,465,000 CUM WELL COST WELL NAME ABALONE 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATEIPROV Alaska CURRENT STATUS I MTS Rig released to BC-6 @ 1200 hrs 3/09/2003. OPERATION COMMENTS RID rig. \24 HR PROG TMD TVD I DFSO 10,356 10,203 AUTH MD WBS 10,166 MOCWI 907 -283-1312 60.0000 COUNTYIOTHER I LAST CASING Kenai 9.625 (in) @ 4,336 (ft) 124 HR FORECAST NRI DX.02.07227.CAP.CMP I DAILY WELL COST I NEXT CASING (in) @ 0 (ft) LEAKOFF 16.32 RIG PHONE MANHRS WORKED I ACCIDENT TYPE 170.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: I LAST SAFETY MTG 3/8/2003 SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 3/4/2003 I LAST RIG INSPECTION FROM TO HRS 06:00 12:00 6.00 FROM 4,233 TO SUB 4,233 AF OPERATIONS SUMMARY PHASE OP TRBL RDMO RIG DESCRIPTION RID change house, camp gen house, mech shop, welding shop and load out same. Move pits, boiler house and rig gen off matting boards and prep to be moved. Rig released to BC-6 @ 1200hrs 03/09/2003. OENSlrY(ppg) I 8.60 I PP I IECO IMUDDATAIOAILYCOST I 0.00 I CUMCOST 8352.00 FV PVIYP GELS WUHTHP FCIT,SOL OIW %SarìdIMBT Ph/pM Pf/Mf CIICa CaCI2(wt%: H2S LIME ES 6RPM / / I / I I / / COMPANY Inlet Drilling Alaska Marathon Weaver Brothers (WBI) SERVICE PERSONNEL DATA NO. HOURS COMPANY 17 102.00 Alaska Petroleum Contra 1 6.00 S&R Enterprises 5 30.00 R&K Industrial SERVICE POB @ 06:00: NO. HOURS 4 24.00 2 2.00 1 6.00 LAST BOP TEST: 3/4/2003 SIZE (in) 10 (in) SHOE TEST (ppg) 9.625 8.835 16.32 CASING SUMMARY LAST CASING TEST: 3/6/2003 MAX SICP MD (ft) TVD (ft) 3,556 (psi) @ (ppg) 4,336 4,194 NEXT BOP TEST: WT (lb/ft) GRADE 40.00 L-80 3/11/2003 BURST (psi) 5,750 Printed: 3/12/2003 3:03:01 PM ) MARATHON Oil COMPANY ALASKA REGION DRilLING REPORT SUMMARY ) Alaska Business Unit/Kenai Abalone #1 J-Od- - \ C1--~ 23-Jan-2003 RDMO Glacier Rig 1 to Abalone #1 location, 24-Jan-2003 MIRU drilling rig. 25-Jan-2003 MIRU drilling rig, 26-Jan-2003 MIRU drilling rig, 27 -Jan-2003 MIRU drilling rig, 28-Jan-2003 RU drilling rig, Clean out 20" to 65' and drill pilot hole to 145'. Prep to PU hammer. 29-Jan-2003 RU hammer. Weld on additional 20" conductor. 30-Jan-2003 Drive 20" casing, Weld on starting head. LID 20" hammer. Install floor plates and rotary table, Adjust torque tube. 31-Jan-2003 Install torque tube turnbuckles, M/U standpipe manifold, N/U 21 1/4" Diverter system, P/U 4" DP. M/U BHA. Clean out CSG to 170', Cannot drill through shoe. POOH. C/O bit attempt to drill out shoe, POOH, Service rig while wait on 17 1/2" mill. 1-Feb-2003 Attempt to drill out of 20" CSG shoe. Drill 12 1/4" hole F/170' -175', Mill out CSG shoe with 17.5" mill. Drill F/175' to 462", 2-Feb-2003 Drill F/462' to 980', 3-Feb-2003 Drill F/980' to 1007', CBU, POOH, C/O bit and MWD. RIH, W/R F/883' to 1007', Drill F/1007' to 1675', 4-Feb-2003 Drill 1675' to 2165', Pumped LCM as needed, 5-Feb-2003 Drill F/2165' to 2210', CBU, Spot LCM pills, POOH (SLM), BHA. RIH to 2127', W/R F/2127' to 2210'. CBU and cut MW F/9,3 ppg to 9,2 ppg, Pump LCM pills, 6-Feb-2003 POOH, BHA, Ran 13 3/8" casing, 7 -Feb-2003 RI H w/cement stinger. Perform cement job. POOH wI cement stinger. Wait on cement. Run 1 1/4" hydril tubing in 20" x 13 3/8" annulus, Perform top job, N/D diverter, ) ) 8-Feb-2003 Cut 133/8" CSG, N/D 21 1/4" diverter, Install and test 13 5/8" Vetco sliplock wellhead, Empty and clean pits, N/U 13 5/8" 5M BOPE. Test BOPE, 9-Feb-2003 Test BOPE. Install standpipe for third mud pump, R/U centrifuge unit. P/U M. Motor and MWD, P/U 4" DP. RIH to 2065'. Test CSG to 1500 psi. Drill shoe track and shoe, CBU. 10-Feb-2003 Drill F/221 0' to 2230', Perform LOT to 14,5 ppg, Drill F/2230' to 3025'. 11-Feb-2003 Drill F/3025 to 3346', CBU, Wiper trip. Drill F/3346' to 3665', 12-Feb-2003 Drill F/3665' to 3900', CBU, RIH to 3158', 13-Feb-2003 RIH. Drill F/3900' to 4350' MD. CBU. POOH to shoe. 14-Feb-2003 RIH. C&C mud, POOH. Run open hole logs, RIH, C & C mud for casing, 15-Feb-2003 C & C mud, POOH, Run & cement 9 5/8" casing, 16-Feb-2003 Finish cementing casing. Installltest packott. Test BOPE. PU DP. MU BHA. RIH. 17 -Feb-2003 RI H . Test casing to 3350 psi. Drill shoe track & 20' of new hole to 4370'. Perform LOT to 16.3 ppg EMW. Trip for new BHA, Clean remaining pits for mud changeover. 18-Feb-2003 Displaced hole, Tripped for bit and BHA, Drilled 4370'-4916'. 19-Feb-2003 Drilled 4,916' to 5,766'. Wiper trip @ 5430'. 20-Feb-2003 Drilled 5,766' to 6,627', Wiper trip @ 5,934', 21-Feb-2003 Drilled 6627' to 7321', Wiper trips @ 6677' & 7230', 22-Feb-2003 Drilled 7321' to 7508', POOH for bit. BOPE test. RIH, 23-Feb-2003 Finished RIH. Drilled 7508' to 8116', 24-Feb-2003 Drilled 8116' to 8613', 25-Feb-03 Drilled 8613' - 8772', Bit trip, Drilled to 8852', 26-Feb-03 Drilled F/8852' to 9577', } ) 27-Feb-03 Drill F/957?' to 9922'. CBU, Wiper trip to 8522', RIH, Drill F/9922' to 10040'. 28-Feb-03 Drill F/10040' to 10345', 1-Mar-03 Drill F/10345' to 10356'. CBU, POOH to shoe, Rig repair, POOH. LID directional tools. P/U LWD tools, RIH to CSG shoe, Rig repair. 2-Mar-03 Rig repair. Log LWD F/4316' to 6563', 3-Mar-03 LWD F/6563' to 6940', Rig repair. LWD F/6940' to 7125'. Rig repair, L WD F 17125' to 9000'. 4-Mar-2003 LWD F/9000' to 10356'. CBU, POOH, Test BOPE, 5-Mar-2003 Test BOPE. LID jars. Service and repair rig, LID HWDP. Clean rig floor. Strap and caliper retainer. RI H wi retainer. C/O to long bales, 6-Mar-2003 Set 9 5/8" retainer. Perform squeeze below retainer and leave 50' of cement above retainer. POOH, LID DP, RIH w/8.5" bit and 9 5/8" CSG scraper. 7 -Mar-2003 Displace well to fresh water. Trip scraper twice 4200' to 2200', POOH LID DP and tools, Run cement evaluation logs, Run completion, N/D BOPE, 8-Mar-2003 N/D BOPE, Install x-mas tree and test to 5000 psi. RID rig. 9-Mar-2003 RID rig, 1 Q-Mar-2003 RID rig, Alaska '~ess Unit Marathon Oil Company P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 March 17, 2003 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon Abalone #1 ~ ~ ').. - l ~ q, CONFIDENTIAL )-0 1.3 ']. :L ~ ~- rì 0 0 Dear Howard: HAND DELIVERED -:tt:- 1 I à-. ~ The Abalone # 1 well samples listed below are included with this transmittal. This samples are CONFIDENTIAL. Box# Start End Depth Depth 1 2210 3160 2 3160 3950 3 3950 4700 4 4700 5550 5 5550 6100 6 6100 6700 7 6700 7150 8 7150 7600 9 7600 8100 10 8100 8600 11 8600 9150 12 9150 9600 13 9600 10000 14 10000 10356 Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address. T~~ you, 1ì~~ Kaynell Zeman Technical Assistant Received by: ~ 0 LL-J Date: (8 /v'1~ à ~ ':1 Enclosures Hand Delivered ) ~\' Fr!~ ) O:\EXCEL\Abandonsundry.XLS 1. ~Jç ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 250'FSL,300Q'FEL, Sec. 29, T2N, R12VV, S.M. At top of Productive Interval 496'FNL, 3109'FEL, Sec. 32, T2N, R12VV, S.M. At Effective Depth At Total Depth 287' FNL, 3181' FEL, Sec. 32, T2N, R12VV, S.M. 1"2." Present VVell Condition Summary Total Depth: measured 10356' true vertical 10203' Effective Depth: measured true vertical Casing S tru ctu ra I Conductor Surface Intermediate Production Liner Perforation Depth: Length 149' 2187' 4315' measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A Operation Shutdown Plugging Re-enter Suspended VVell Time Extension Stimulate Perforate Other 6. Datum Elevation (OF or KB) 266 KB feet Suspend Repair VVell Pull Tubing 5. Type of VVell: Development _ Exploratory ~ Stratigraphic Service Variance 7. Unit or Property Name Ninilchik 8. VVell Number Abalone #1 9. Permit Number 202-129 10. API Number 50-- 133-20517-00 11. Field/Pool Tyonek o feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured Depth True Vertical Depth 20" Driven 170' 170' 13 3/8" 1327 sx 2208' 2098' 95/8" 685 sx 4336' 4194' Abandon open hole with retainer set at 4283' md. Squeeze a volume of cement below retainer to fill to a depth of 4436' and place 50' of cement on top of retainer to a depth of 4233'. Detailed Operations Program BOP Sketch 13. Attachments Description Summary of Proposal 15. Status of VVell Classification as: 14. Estimated Date for Commencing Operation 3/5/03 16. If Proposal was Verbally Approved Tom Maunder 3/5/03 Name of Approver Date Approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~- - - - - --- Drilling Superintendent Signed P. K. Berga tJY /(/ ~ Title FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent Form Required 10- Y(J~...., o / ~Q \ \. c-a~~\<t ~ot/"' Approved by Order of the Commission / L.-{........ /Lì /lL-<:.e ~ .~" Commissioner Form 10·403 Rev. 06/15/88 / Oil Service Suspended Gas Date 315/2003 Approval No. 303-0~[š Date 3/s1ù~~ Suömit in Triplicate \\ ~~LJR Ô¡Cm , ~qnMS BFl Re: Abalone #1--PTD 202-129 ) ) Subject: Re: Abalone #1--PTD 202-129 Date: Wed, 05 Mar 200307:20:13 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Berga, Pete" <PKBerga@MarathonOil.com> CC: "Lambe, Steven S," <SSLambe@MarathonOil.com> Pete, This confirms our conversation of last night and a few moments ago, You indicate that there are no hydrocarbon bearing sands in the drilled interval below the 9-5/8" and plan to abandon that portion of the wellbore. Plans at present are to complete the well in the remaining cased hole section in order to evaluate sands there. 20 MC 25,112 (a) covers plugging of the uncased portion of the wellbore to isolate hydrocarbon, geo-pressure and/or freshwater. No hydrocarbon, geo-pressure or freshwater have been encountered in the wellbore below the 9-5/8" shoe, 20 MC 25,112 (f) requires that the fluid weight left between plugs be of sufficient density to exceed an encountered formation pressure. You have indicated that the mud weight presently in the hole is 9.5. Fluid of this weight should satisfy the requirement of (f), 20 MC 25,112 (b) requires that the cased and uncased portions of a well bore must be segregated. (b) (2) allows the setting of a retainer 50' - 100' above the casing shoe, pumping sufficient cement to fill the wellbore a minimum of 100' below the shoe and placing 50' of cement on top of the retainer. Your plans satisfy this requirement. 20 MC 25.112 (g) requires the retainer to be weight or pressure tested at your option. I do not have an Inspector available to witness the setting of the retainer. In the final well record, please describe how the retainer was tested, If any pressure chart is available (if that option is chosen), please include it. By copy of this email, you have approval to proceed with the operations as you propose. Please call with any questions. Tom Maunder, PE AOGCC "Berga, Pete" wrote: Tom- As per our phone conversation last night we are going to abandon the open hole of the well. Our Geologist has confirmed there are no hydrocarbon baring sands. The abondonment will consist of: the 9 5/8" shoe is at 4336'. Set retainer at +/- 4286'. Squeeze a volume of cement to fill the hole below the retainer to 4436' minimum. Place 50' on top of the retainer. Please email back approval. I'm fillling out the sundry and I can fax immediately and/or hand deliver once I'm finished. The rig has the retainer on depth waiting on word from me. Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 3/5/2003 11 :31 AM Re: Abalone #1 Intermediate Casing Set Depth ) ) Subject: Re: Abalone #1 Intermediate Casing Set Depth Date: Thu, 13 Feb 2003 17:20:45 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Lambe, Steven S." <SSLambe@MarathonOiLcom> CC: "Tank, W J (Will)" <WJTank@MarathonOiLcom> , "Berga, P K (Pete)" <PKBerga@MarathonOiLcom> ~- \ét--- ~ Steve, Thanks for the notice. According to the drilling information you developed, deepening was necessary to the formations coming in a little different than expected and you will be adjusting the cement volumes accordingly. Nothing further will be needed, Good luck with the pipe job. Tom Maunder, PE AOGCC "Lambe, Steven S." wrote: > Tom- > > Following up on our phone conversation, the Intermediate casing point of 4,250' Md (4,084' tvd) was extended to 4,350' MD (4,208 tvd). The casing seat was targeting the zone between the Upper and Lower beluga and was encountered slightly deeper as noted with the new Intermediate point. The cement volume will be adjusted accordingly. > > If you need any additional information, please contact me directly, > > All the best, > > Steven Lambe > Marathon Oil Company > 564-6332 --- --- -- --. --.- - ~ - . _ _ _m __ _ _ _. _ Tom Maunder <tom maunder@admin.state.ak.us> ' Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 2/13/2003 5:20 PM \' ) Alas ~siness Unit dOd.;/~ 9 Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 12,2002 Mr, Steve Davies Alaska Oil and Gas Conservation Commission 333 West ih Avenue, #100 Anchorage, AK 99501-3539 Re: Location Exception Application Marathon Oil Company: Abalone # 1 Well Section 32-2N-12W, S,M, Kenai Peninsula Borough, Alaska Dear Steve: In response to your conversation with Chris Gay, please accept the following revisions/clarifications for the Location Exception Application notification of parties. The four parties in question were not notified for the following reasons: Ian Hawkins -- Deceased James E, Hawkins -- Deceased Deborah Murphy -- Letter sent, no green card returned John Williamson -- Green card received, copy omitted from MaC's December 3,2002 letter, A copy of the card is enclosed, Please call me at 907-564-6428 if you have any questions, / "-...... ...~. Certified Mail No: 70020510000311102980 Enclosure cc: Central File R£C£\\Jt\) aE.C '\ 6 2.QQ'2 co{nt"f~\~'ÞìÙ I '\ & GaS Cons. _\G 0\ ~~(',"oraQe ) SENDER: COMPLETE THIS SECTION · Complete items 1, 2, and .3. Also· complete item 4 if Restricted Delivery is desired, · Print your name and address on the reverse so that we can return the card to you, . · Attach this card to the back of the mail piece, or on the front if space permits. 1. Article Addressed to: 1IIIIIIIIIIIIIIIIIIIIIIInlllllllllllllllllilfl John Williamson 2264 Knoll Circle Anchorage, AK 99501-5721. II I I' "" 'I II II II 1'.1 OCT 1 6 2002 - 2. Article Number (Transfer from service label) PS Form 3811 , August 2001 ) ./ COMPLETE THIS SECTION ON DELIVERY A.~gn.ure -~... .~~~ . X ~ . Aent. ~!Jðt ~ ~, Mece.....i.v;fbY !printad I";;n;e)'ì·/ ~.' Date of Delivery r//Ø'Jð~elw?I¡.., l(}'-'L¡-?--" D. Is d~ery address different fro"'~ 1? 0 Yes If YES, enter delivery address bf!16~ 0 No ..,/S~ 3. S~. ice Type. J?S Çertified Mail o Registered o Insured Mail ·0 Express Mail p#:Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 70·02 05·10 0003,· 1110 1495 102595-02-M-0835 Domestic Return ReCeipt ) ~~!Æ~E ~} !Æl!Æ~~«!Æ ~ AIßA.~KA. OIL AlWD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR S, S. Lambe Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AL 99519 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Abalone # 1 Marathon Oil Company Permit No: 202-129 Surface Location: 250' FSL, 3000' FEL, Sec. 29, T2N, RI2W, SM Bottomhole Location: 590' FNL, 3000' FEL, Sec, 32, T2N, RI2W, SM Dear Mr, Lambe: Enclosed is the approved application for permit to drill the above referenced exploration well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations untfl all other required permits and approvals have been issued, In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued, A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned, The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use, All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones, The permit is approved subject 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, Marathon Oil Company assumes the liability of any protest to the spacing exception that may occur, Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance, Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager), s~ ç;ganiel T. ~unt, Jr. Commiss·Îoner BY ORDER OF THE COMMISSION DATED this~1/'~ay of October, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ) " ) Alaska Business Unit ,.. , M MARATHON t f Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 June 7, 2002 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Attached is the Permit to Drill for Well Number Marathon NNA #1, and the accompanying schematics and procedure. Marathon NNA #1 has an anticipated spud date of 1-1-03, However, this well may be accelerated into Q4 of 2002. An Exception To Location permit is required and will be addressed separately. We ask for you to approve the attached 10-401 noting the Exception To Location permit is still required, If you would like any other information, please contact me at 564-6332 or sslam be@marathonoil,com. Sincerely, )/-;¿:J ______ Steven S, Lambe Drilling Engineer Enclosure bjv RECEIVED JUN '1 3 2002 Alaska Oil & Gas Cons. Comms.s~on . Anchorage ) S TAT E 0 F ALAS KA, I 0 N"",mo\d"''''''''''''",4-' OIAQGCCPTDR 1.". r.' ,_. ALAS, A OIL AND GAS CONSERVATION COMf\¡ 5 ,erct~ PERMIT TO DRILL 210 AAC 25.005 1a. Type of Work Drill[8J Re-EntryD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 250'FSL, 3000'FEL, Sec. 29, T2N, R12W, S.M. At top of Productive Interval 433' FNL, 3000' FEL, Sec. 32, T2N, R12W, S.M. Re-DrillD DeepenD At Total Depth 590'FNL, 3000'FEL, Sec. 32, T2N, R12W, S.M. 12. Distance to Nearest Property Line(unit boundary 483 feet 16. To be Completed for Deviated Well: Kickoff Depth 500 feet Maximum Hole Angle 18. Casing Program Size 13. Distance to Nearest Well -b '4 'Y\ Hole Casing Weight Driven 20" 133 .~ 13-3/8" 68 .~ 9-5/8" 40 7" 41/2" 12.6 Specifications Grade Coupling K-55 PE L-80 BTC L-80 BTC L-80 BTC 1b. Type of well. Explorato~ Stratigraphic TesD ServiceD Development GaG Single Zone[] 5. Datum Elevation (DF or KB) 10. Field and Pool 266 KB feet Wildcat 6. Property D':Si~ti~ t}(l.)/Jf"t/ ~4Z.. ~" 7. Unit or Property Name Ninilchik Development aiD Multiple Zon{8] 8. Well Number A A bo.\o.......« ~ .L ~ 9. Approximate Spud Date 01/01/03 14. Number of Acres in Property 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 15. Proposed Depth (MD and TVD) 4000 feet 10,166' MD/10,000' TVD feet 17. Anticipated Pressure 30 0 (see 20 AAC 25.035 (e) (2» 3322 psig at Total Depth (TVD) Setting Depth 10,000' Maximum Surface Top Bottom Quantity of Cement Length MD TVD MD TVD (including stage data) +/-140' 0' 0' +/-150' +/-150' 2200 0' 0' 2200 2069 975 sx 4250 0' 0' 4250 4084 680 sx 6166 4000 3834 10166 10,000' 706 sx \~'" \q ~'\" ~~~~ Ä... ~~ C,,:>~ ~ \ dOC):J I v'~ ~ \"\t ~ ,,^-CAA-<"'\-\-"O'l'\. ~~~":.-\t--Ç) -7~1è \)..,~\.'-~~~ \Cêc:.~~ ~ ~bCJ\.()l\~ L þ>.'Ðo.\ONi; ~ ~( The Marathon ~1 will be directionally drilled to an estimated total depth of 10166' md, 10,000' tvd from a new pad. An exception to location permit will be required and will be submitted at a later date, Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud Pit Drawing, Blow out Prevention Equipment drawings. 20. Attachments Filing Fee[K] Property PlaŒ) BOP Sketch[8J Drilling Fluid Prograª Time vs Depth PloD Refraction Analysi{] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge j). d---~iue Senior ~~~~~~~gineer Commission Use Only Permit Number API Number Approval Date ?--D2- -{ Zfi 50--/'33- 2P5"17-DD !O 'Î} Oq ~ ~rn'ronts Conditions of Approval Samples Required [K]Yes DNa Mud Log Required 00 Yes L~o- Hydrogen Sulfide Measures DYes ~NO Directional Survey Required ŒJYes DNo n 1\1 -! -" f)nnz . . D D D D ....vJ~ I J L\,jiJ Required Working Pressure for BOPE 2M 3M 5M 10M 15M Other: s,CjJO~ \ ~ V ~ ~ 'O~ \ ~ 'If;· \ ~Oô ~~ \ ~ Ù ~ -\-<e> ~C) "AIds~ & Gas Cons. Commission "'lJ;~Al SIGNCD CY by order of Anchorage /; Approved by ) :-:vlor Seamount . Commissioner the Commission Date 10 Q OL Form 10·401 Rev. 12-1-85 Su)mit in Triplicate Signed S. S. Lambe Diverter Sketct{8] Seabed RepoU Drilling Prograrr0 20 AAC 25.050 Requirement{] Date 6/10/2002 See Cover Letter ) ) DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: PAD: SLOT: Marathon NNA #1 Marathon NNA NA FIELD: WBS No.: TYPE: Wildcat NA Exploration Prepared by: S. S. Lambe API No.: NA REVISION NO.: 0 DATE: 6/6/2002 SURFACE LOCATION: 250' FSL,3000' FEL, Sec. 29,T2N, R12W,S,M, TARGET: Tyonek D-1 Sandstone 433' FNL, 3000' FEL, Sec. 32, T2N, R12W, S.M. (TVD = 2,300') BOTTOMHOLE LOCATION: 590' FNL, 3000' FEL, Sec. 32, T2N, R12W, S.M. (TVD = 10,000') KB ELEVATION: GL ELEVATION: 266 ft. mean S.L. 245 ft. mean S. L. I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling Upper Beluga Lower Beluga Tyonek 2,449 3,207 4,607 6,632 2,300 3,041 4,441 6,466 ", II. ESTIMATED FORMATION TOPS AND CONTENT: POTENTIAL FORMATION DEPTH(MD) DEPTH(TVD) CONTENT Sterling 2,449 2,300 gas/water Upper Beluga 3,207 3,041 gas/water Lower Beluga 4,607 4,441 gas/water Tyonek T-1 6,632 6,466 gas/water Tyonek T-2 7,432 7,266 gas/water Tyonek T-3 8,457 8,291 gas/water TD 10,166 10,000 gaslwater Page 1 Clam Gulch Drilling Prognosis,xls ) ) III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 21 1/4" X 2000 psi annular preventer and a 16" 0.0. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: 21 1/4" 2,000 psi flange top x 20" weld on bottom. CASING HEAD: 13518" 3000 psi top x 133/8" SLC bottom with base plate for 20", two 2" line pipe outlets, one 2" ball valve. (Multibowl System) CASING SPOOL: TUBING HEAD: 135/8" 5,000 psi top x 135/8" 3,000 psi bottom, 21/16" 5,000 psi studded outlets, one 21/16" 5,000 psi gate valve. CHRISTMAS TREE: 41/16" 5,000 psi x 135/8" 5,000 psi bottom, including two master valves, one flow tee, one wing valve, one swab valve, and one pnuematic actuated wing valve. Page 2 Clam Gulch Drilling Prognosis.xls ) ) IV. CASING PROGRAM: CASING DESCRIPTION DEPTH SET FROM TO HOLE TYPE SIZE WT, GRADE THREAD (MD) (MD/TVD) SIZE CONDUCTOR: 20" 133 ppf K-55 PE Surf +/- 140'/140' Driven SURFACE: 13 3/8" 68 ppf L-80 BTC Surf 2,200'/2,069' 17 1/2" INTERM 1: 95/8" 40 ppf L-80 BTC Surf 4,250'/4,084' 12 1/4" LINER: 4-1/2" 26 ppf L-80 H-521 4000 10,166'/10,000' 7" CASING DESIGN SETTING FRAC GRD FORM PRES DESIGN FACTORS SIZE WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP TENS COLL BU RST 13 3/8" 68 ppf L-80 2,069' 13.1 931 1,277 4.30 2.76 3.59 9 5/8" 40 ppf L-80 4,084' 15.5 1,838 2,185 3.13 1.57 2.02 4-1/2" 12.6 ppf L-80 10,000' 16,0 4,500 3,322 1.77 1.52 2.95 All tubulars are new. Page 3 Clam Gulch Drilling Prognosis.xls ') ~) V. CEMENTING PROGRAM SURFACE: 133/8" 2,200'/2,069' SLURRY: Class "G" + required additives, See cement prognosis. TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: SURFACE 12.0 ppg. 2.50 cu, fUsk 10,84 gal/sk 5:30 hrs:min 50 % in open hole. 975 sks, RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1, Remove thread protectors and visually inspect connections. 2. Make up float shoe and 1 shoe joint. Check float. Fill pipe until circulating. 3. M/U stab-in float collar. (seal-lock all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. MIU circulating head. Test lines, 6. Circulate until no gain in circulating efficiency is made. 7. Run inner cementing string with stabing sub and centralizer. Weatherford has false rotary and slips. 8. Pump spacer as follows: 50 bbl Mud Clean II @ 8.8 ppg 9, Mix and pump tail slurry. 10, Displace cement. Sting out. 11. Check floats. 12. POOH with inner string. WOC 13. N/D diverter. Weld on casing head and N/U blowout preventers. 14. Test BOPE. Run wear bushing. Page 4 Clam Gulch Drilling Prognosis.xls ) ') v. CEMENTING PROGRAM (continued) INTERM 1 95/8" @ 4,250'/4,084' LEAD SLURRY: Class "G" + required additives. See cement prognosis. TOP OF CEMENT: WEIGHT: YIELD: WATER REO,: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 3,000 ft, 12,0 ppg. 2,53 cu. ft./sk 10.63 gallsk hrs:min 30 % 180 sks. TAIL SLURRY: Class "G" + required additives. See cement prognosis, TOP OF CEMENT: WEIGHT: YIELD: WATER REO,: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 6,027 ft, 12,8 ppg, 1 .79 cu. ft./sk 5,80 gallsk hrs:min 30 % 500 sks, **Tail Cement across OH with Lead targeted 1000' rise in 13-3/8" by 9-518" annulus, RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections, 2. Make up float shoe and 2 shoe joints, Check float. Fill pipe until circulating. 3. MIU float collar. (seal-lock all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. MIU cementing head, install bottom plug and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: 30.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 1 Ibs/bbl Cello Flake + 20 Ibs/bbl Kol Seal + 30.8 Ibs/bbl Bentonite + 92 Ibs/bbl Barite, Bulk @ 10 ppg 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. Land mandrel hanger in multibowl. 12. Bump plug wI 500-1 ,000 psi over final circulating pressure. Check floats. 13. WOC Page 5 Clam Gulch Drilling Prognosis.xls ) ) v. CEMENTING PROGRAM (continued) LINER 4-1/2" @ 4,000' MD to 10,166'/10,000' SlU RRY : Class "G" + required additives. See cement prognosis. TOP OF CEMENT: WEIGHT: YIELD: WATER REO,: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 4,000 ft. 12.8 ppg. 1.79 cu. fUsk 5.74 gal/sk 4:30 hrs:min 30 % 706 sks, RUNNING AND CEMENTING DETAilS: ENSURE WEAR BUSHING IS REMOVED! 1, Remove thread protectors and visually inspect connections. 2. Make up float shoe and 4 shoe joints. Check float. Fill pipe until circulating. 3, M/U float collar. (seal-lock all connections to top of float collar) 4. Fill pipe until circulating. 5, Run remaining casing liner on 4" drillpipe. Circulate and condition well. 6. Set hydraulic liner hanger. M/U cementing head and test all lines. Establish rotation. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To Be issued At later date 9. Mix and pump slurry. Drop top plug. Attempt to rotate during entire cement job 10. Displace cement with water. 11. Bump plug wI a minimum of 500 psi over displacement pressure. Check floats. 12. Sting out of liner hanger, pull up 5 stands, reverse out cement. WOC, 13. Clean off and test liner top. Run polish mill. Run and set liner hanger packer hydraulically. Page 6 Clam Gulch Drilling Prognosis.xls ) ') VI. MUD PROGRAM MUD PROPERTIES DEPTH FROM TO TO WEIGHT PV WATER MUD (MD) (MD) (TVD) (ppg) (cp) LOSS TYPE 0' 2,200' 2,069' 8.8 - 9.2 10-15 8 - 12 Freshwater gel 2,200' 4,250' 4,084' 9.0 - 9.2 8 - 14 6-8 FLO PRO/KCL 4,250' 10,166' 10,000' 9.0. - 9.5 8 - 14 6-8 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van, Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. SURFACE: No logging is planned for this interval. INTERM 1: GR, PEX, SONIC, CMR - Evaluation of Sterling & UB LINER: GR, PEX, SONIC, CMR - Evaluation of Lower Beluga and Tyonek MUD LOGGING The well will be mud logged from surface to TD at 10,166' MD, CORING PROGRAM None Planned TESTING PROGRAM No open hole tests are planned for this well. Page 7 Clam Gulch Drilling Prognosis.xls ) ) VIII. OTHER INFORMATION DIRECTIONAL PLAN (FROM KB ELEV,) NORTH East VERT DESC MD TVD INCL AZIM COORD COORD SECTION MSL 265 265 0 0 0 0 0 KOP 500 500 0,0 180.0 0 0 0 build @ 3,0 deg/100ft Start Hold 1,500 1 ,455 30.0 180,0 -256 0 -256 Start Drop 1,898 1,800 30.0 180.0 -455 0 -455 drop @ 2,0 deg/100ft Start Hold 3,398 3,232 0.0 180.0 -839 0 -839 TOTAL DEPTH 10,166 10,000 0.0 0.0 -839 0 -839 POTENTIAL INTERFERENCE: None- First Well on new Pad, Page 8 Clam Gulch Drilling Prognosis.xls ) ') IX. DRILLING PROGRAM CONDUCTOR: Drive 20" conductor to +1-140 ft. RKB. Weld starting flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 21 1/4" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 17 1/2" hole to 2,200' MD/2,069' TVD per the directional plan. Run and cement 133/8" casing. wac. Cutoff 133/8" and 20". Connect 133/8" SLC by 135/8" 3M wellhead, N/U 135/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3,000 psi. Set wear bushing. Test surface casing to 1,500 psi. INTERMEDIATE 1: Drill out float equipment and make 20' of new hole. CBU, Test shoe to leak off. Estimated EMW is 13.1 ppg, Drill 12 1/4" directional hole to 4,250' MD/4,084' TVD as per directional plan. Condition hole as required. Log with Wireline as per program. Make wiper trip. Run and cement 9 5/8" casing. Land casing in multibowl head, WOC. Set wear bushing. Test casing to 2,500 psi. First Gas sands expected at 2,300' TVD. No abnormal pressures are expected. If the Sterling sands are analogous to the KGF, losses may occur and plan on fine/med CaC03 as required maintaining a low fluid loss in the mud system. Pipe centralization to be provided at a later date. PRODUCTION: Drill float equipment and 20' of new formation wi 7" bi-center bit. CBU. Test shoe to leak off. Estimated EMW 15,5 ppg. Drill ahead to TD @ 10,166' MD 110,000' TVD as per the program. Expect a formation change from the lower beluga to Tyonek @ +1- 6,500'. Maintain mud properties to ensure good hole cleaning. At TD, condition hole for logging, POOH and acquire wireline logs. Trip in and condition hole and mud for cementing. Trip out of hole laying down excess drill pipe, MU & RIH 4-1/2" liner on rotatable hanger, Set hanger and establish rotation. Cement with high compressive light weight cement as per program. WOC, RIH with polish mill and dress TaL. Set liner top packer and test. Clean out 4-1/2" liner. COMPLETION: Completion program to be issued after evaluation of the intermediate hole section (Sterling and UB). Page 9 Clam Gulch Drilling Prognosis.xls ) ) X, POTENTIAL HAZARDS Marathon NNA #1 To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house, The man on the break(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 2,450' MD/2,300' TVD to total depth of the well. These sands will run normal pressured. Lost circulation and differential sticking are potential across the Sterling. The fresh water gel and FLOPRO mud systems that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. No well interference hazards exist. XI. NOTES MASP CALCULATIONS: The maximum Anticipated Surface pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30%mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. Surface casing: 133/8" @ 2,069' TVD MASP = (FG + SF)*0.052*TVDs-(GG*TVDs) MASP = (13.1 ppg + 1.0 ppg) x ,052 x 2069' - (.115 x 2,069') MASP = 1,517 psi - 240 psi MASP = 1,277 psi. Intermediate casing: 9 5/8" @ 4,084' TVD MASP = ((PP*O,052*TVDtd)-(%mud*0.052*TVDtd)-(%Gas*GG*TVDtd)) MASP = (8.6*0.052*10,000)) -(.3*0.052*9.5*10,000)-(.7*.115*10,000) MASP = 4,472-1,482-805 MASP = 2,185 psi Production @ 10,000' TVD MASP =PP*0.052*TVDf-(GG*TVDf) MASP =8.6*0.052*10,000 - (.115*10,000) MASP =4,472 - 1,150 MASP = 3,322 psi Tubulars All tubulars are new. Page 1 0 Clam Gulch Drilling Prognosis.xls ') ') MARATHON Oil Company Clam Shell Pad ~ M"rlt.T~þ'l ¡JN4 .-1. CG#1 slot #1 Exploration Kenai Peninsula, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License Clam Gulch #1 Ver 1 prop5230 Date printed Date created Last revised 2-May-2002 2-May-2002 2-May-2002 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 242973.182,2278050.968,999.00000,N Slot location is n60 13 47.994,w151 24 8.116 Slot Grid coordinates are N 2278697.000, E 245101.000 Slot local coordinates are 691.48 N 2113.55 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ') MARATHON Oil Company PROP08AL LI8TING Page 1 Clam 8hell Pad,CG#l Your ref Clam Gulch #1 Ver 1 Exploration,Kenai Peninsula, Alaska Last revised : 2-May-2002 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 8 Depth Degrees Degrees Depth COORD I N ATE 8 Deg/100ft 8ect Easting Northing 0.00 0.00 180.00 0.00 O.OON O.OOE 0.00 0.00 245101.00 2278697.00 500.00 0.00 180.00 500.00 0.008 O.OOE 0.00 0.00 245101.00 2278697.00 600.00 3.00 180.00 599.95 2.628 O.OOE 3.00 2.62 245100.94 2278694.38 700.00 6.00 180.00 699.63 10.468 O.OOE 3.00 10.46 245100.78 2278686.54 800.00 9.00 180.00 798.77 23.518 O.OOE 3.00 23.51 245100.50 2278673.49 900.00 12.00 180.00 897.08 41.748 O.OOE 3.00 41.74 245100.11 2278655.28 1000.00 15.00 180.00 994.31 65.088 O.OOE 3.00 65.08 245099.61 2278631. 94 1100.00 18.00 180.00 1090.18 93.488 O.OOE 3.00 93.48 245099.00 2278603.55 1200.00 21.00 180.00 1184.43 126.858 O.OOE 3.00 126.85 245098.28 2278570.18 1300.00 24.00 180.00 1276.81 165.128 O.OOE 3.00 165.12 245097.46 2278531.93 1400.00 27.00 180.00 1367.06 208.168 O.OOE 3.00 208.16 245096.54 2278488.89 1500.00 30.00 180.00 1454.93 255.878 O.OOE 3.00 255.87 245095.52 2278441.19 1898.45 30.00 180.00 1800.00 455.108 O.OOE 0.00 455.10 245091.25 2278242.01 1998.45 28.00 180.00 1887.46 503.588 O.OOE 2.00 503.58 245090.21 2278193.55 2098.45 26.00 180.00 1976.55 548.988 O.OOE 2.00 548.98 245089.24 2278148.16 2198.45 24.00 180.00 2067.18 591.248 O.OOE 2.00 591.24 245088.34 2278105.91 2298.45 22.00 180.00 2159.23 630.318 O.OOE 2.00 630.31 245087.50 2278066.85 2398.45 20.00 180.00 2252.58 666.148 O.OOE 2.00 666.14 245086.73 2278031.03 2448.76 18.99 180.00 2300.00 682.938 O.OOE 2.00 682.93 245086.37 2278014.24 2498.45 18.00 180.00 2347.13 698.708 O.OOE 2.00 698.70 245086.04 2277998.48 2598.45 16.00 180.00 2442.75 727.938 O.OOE 2.00 727.93 245085.41 2277969.25 2698.45 14.00 180.00 2539.34 753.818 O.OOE 2.00 753.81 245084.85 2277943.38 2798.45 12.00 180.00 2636.77 776.318 O.OOE 2.00 776.31 245084.37 2277920.89 2898.45 10.00 180.00 2734.93 795.398 O.OOE 2.00 795.39 245083.96 2277901.82 2998.45 8.00 180.00 2833.69 811.038 O.OOE 2.00 811 . 03 245083.63 2277886.18 3098.45 6.00 180.00 2932.94 823.228 O.OOE 2.00 823.22 245083.37 2277873.99 3198.45 4.00 180.00 3032.56 831.938 O.OOE 2.00 831.93 245083.18 2277865.28 3206.92 3.83 180.00 3041 . 00 832.518 O.OOE 2.00 832.51 245083.17 2277864.70 3298.45 2.00 180.00 3132.41 837.168 O.OOE 2.00 837.16 245083.07 2277860.05 3398.45 0.00 180.00 3232.39 838.918 O.OOE 2.00 838.91 245083.03 2277858.30 3500.00 0.00 180.00 3333.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 4000.00 0.00 180.00 3833.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 4500.00 0.00 180.00 4333.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 5000.00 0.00 180.00 4833.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 5500.00 0.00 180.00 5333.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 6000.00 0.00 180.00 5833.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 6500.00 0.00 180.00 6333.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 6812.06 0.00 180.00 6646.00 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 7000.00 0.00 180.00 6833.94 838.91S O.OOE 0.00 838.91 245083.03 2277858.30 7500.00 0.00 180.00 7333.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 8000.00 0.00 180.00 7833.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 8500.00 0.00 180.00 8333.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 9000.00 0.00 180.00 8833.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 9500.00 0.00 180.00 9333.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 10000.00 0.00 180.00 9833.94 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 10166.06 0.00 180.00 10000.00 838.918 O.OOE 0.00 838.91 245083.03 2277858.30 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from Est RKB (Glacier 1) (265.00 Ft above mean sea level) . Bottom hole distance is 838.91 on az~uth 180.00 degrees from wellhead. Total Dogleg for wellpath is 60.00 degrees. Vertical section is from wellhead on az~uth 180.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ') MARATHON Oil Company Clam Shell Pad,CG#l Exploration,Kenai Peninsula, Alaska Comments in wellpath ------ ------ Me Rectangular Coords. TVD Comment ----------------------------------------------------------------------------------------------------------- ) PROPOSAL LISTING Page 2 Your ref Clam Gulch #1 Ver 1 Last revised: 2-May-2002 500.00 500.00 O.OOS O.OOE KOP 1500.00 1454.93 255.87S O.OOE End of Build/Turn 1898.45 1800.00 455.l0S O.OOE End of Hold 2448.76 2300.00 682.93S O.OOE Sterling Target 3206.92 3041.00 832.51S O.OOE Beluga Target 3398.45 3232.39 838.91S O.OOE End of Drop 6812.06 6646.00 838.91S O.OOE Tyonek Target 10166.06 10000.00 838.91S O.OOE TD Casing positions in string 'A' ----====== Top Me Top TVD Rectangular Coords. Bot Me Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OON O.OOE 10000.00 O.OOE 4200.00 O.OOE 2200.00 O.OOE 120.00 9833.94 4033.94 2068.59 120.00 838.91S 838.91S 591.86S O.OOS Target name T.V.D. Targets associated with this wellpath ---- ----- ---------------- Geographic Location O.OOE O.OOE O.OOE O.OOE Rectangular Coordinates 4 1/2 9 5/8 Casing 13 3/8 Casing 20 Conductor ----------------------------------------------------------------------------------------------------------- Revised CG#l Sterling Tgt - CG#l Beluga Tgt - 2 CG#l Tyonek Tgt - 2 CG#l TD Tgt - 2 May 2300.00 3041.00 6646.00 10000.00 800.00S 800.00S 800.00S 800.00S O.OOE O.OOE O.OOE O.OOE 2-May-2002 2-May-2002 2-May-2002 2-May-2002 ') ...................."................ Created by Sutherland For: S Lambe Date plotted: 2-May-2002 Plot R.r.,ence i. Clam CulCh '1 VBr 1. Coord1nates ore in reet reference slot * 1. Trult Vertical Deplhll ore refDrence Est RK8 (Glacier 1). .ill ...,.. INTEQ MARATHON Structure: Clam Shell Pad field: Exploration 600 - o ! 20 Conductor 0.00 KOP 3.00 9.00 15.00 21.00 ~6'.~~ End of Build/Turn 30.00 End of Hold ~~ 2~4~gO 13 3/8 Casing 20.00 2400 - Sterling Targel 16.00 12.00 8.00 4.00 0.00 End of Drop 600 - 1200 - DLS: 3.00 deg per 100 ft 1800 - DLS: 2.00 deg per 100 ft 3000 - Beluga Target ,-..., +- Q) 3600 - Q) I.- 5/8 Casing LL '--"" - 9 ..r: 4200 - +- Q.. Q) 0 4800 - 0 0 :;: 5400 - I- Q) > Q) 6000 - :J L l- I 6600 - Tyonek Target - V 7200 - 7800 - 8400 - 9000 - 9600 - 4 1/2 LL TD --+ 1 0200 - 1 0800 - M MARATHON .. "" <- We.1 (1..1): Eallf (le.l) -> - 100 - 150 - 200 - 250 - 300 - 350 (/) 0 - 400 C -+ ::r ,-..., of Hold - 450 -+. a End CD CD -+ '--"" - 500 I V - 550 - 600 ) ......................................... Oil Company Well: CG#1 Location: Kenai Peninsula, Alaska 100 50 End of Build/Turn a WELL PROFILE DATA ----- Po1flt ----- V. S.d Dov/100 500.00 0.00 180.00 !5OO,oo 0.00 0,00 0.00 End 01 B~d I.M,g;S -.2!15.1I? 1Ma.04~ ;O.oo -4~"10 0.00 ~.IO 0.00 End rI Hold "3911.4~ 323.2.311 1I3I.gl End 01 Drop .!...I?:..~..~..~!..!J.~.............~~~.~~~.............~:~.........!~:~......~~:~.......:~~:!~.............~:~~.........~:!~..............~~. 600 0 600 Vertical Section (feet) -> 1200 1800 2400 Azimuth 180.00 with reference 0.00 N. 0.00 E from slot # 1 Sterling Target 0 o 50 @ KOP 100 - 50 o - 50 - 650 -700 -750 - 800 - 850 - 900 - 950 ') ') MARATHON Oil Company Clam Shell Pad CG#l slot #1 Exploration Kenai Peninsula, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License Clam Gulch #1 Ver 1 prop5230 Date printed Date created Last revised 2-May-2002 2-May-2002 2-May-2002 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 242973.182,2278050.968,999.00000,N Slot location is n60 13 47.994,w151 24 8.116 Slot Grid coordinates are N 2278697.000, E 245101.000 Slot local coordinates are 691.48 N 2113.55 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ') ') MARATHON Oil Company PROPOSAL LISTING Page 1 Clam Shell Pad,CG#l Your ref Clam Gulch #1 Ver 1 Exploration,Kenai Peninsula, Alaska Last revised 2-May-2002 Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COO R D I N A T E S Deg/100ft Sect 0.00 0.00 180.00 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 180.00 500.00 0.00 S 0.00 E 0.00 0.00 KOP 600.00 3.00 180.00 599.95 2.62 S 0.00 E 3.00 2.62 700.00 6.00 180.00 699.63 10.46 S 0.00 E 3.00 10.46 800.00 9.00 180.00 798.77 23.51 S 0.00 E 3.00 23.51 900.00 12.00 180.00 897.08 41.74 S 0.00 E 3.00 41. 74 1000.00 15.00 180.00 994.31 65.08 S 0.00 E 3.00 65.08 1100.00 18.00 180.00 1090.18 93.48 S 0.00 E 3.00 93.48 1200.00 21.00 180.00 1184.43 126.85 S 0.00 E 3.00 126.85 1300.00 24.00 180.00 1276.81 165.12 S 0.00 E 3.00 165.12 1400.00 27.00 180.00 1367.06 208.16 S 0.00 E 3.00 208.16 1500.00 30.00 180.00 1454.93 255.87 S 0.00 E 3.00 255.87 End of Build/Turn 1898.45 30.00 180.00 1800.00 455.10 S 0.00 E 0.00 455.10 End of Hold 1998.45 28.00 180.00 1887.46 503.58 S 0.00 E 2.00 503.58 2098.45 26.00 180.00 1976.55 548.98 S 0.00 E 2.00 548.98 2198.45 24.00 180.00 2067.18 591.24 S 0.00 E 2.00 591.24 2298.45 22.00 180.00 2159.23 630.31 S 0.00 E 2.00 630.31 2398.45 20.00 180.00 2252.58 666.14 S 0.00 E 2.00 666.14 2448.76 18.99 180.00 2300.00 682.93 S 0.00 E 2.00 682.93 Sterling Target 2498.45 18.00 180.00 2347.13 698.70 S 0.00 E 2.00 698.70 2598.45 16.00 180.00 2442.75 727.93 S 0.00 E 2.00 727.93 2698.45 14.00 180.00 2539.34 753.81 S 0.00 E 2.00 753.81 2798.45 12.00 180.00 2636.77 776.31 S 0.00 E 2.00 776.31 2898.45 10.00 180.00 2734.93 795.39 S 0.00 E 2.00 795.39 2998.45 8.00 180.00 2833.69 811.03 S 0.00 E 2.00 811.03 3098.45 6.00 180.00 2932.94 823.22 S 0.00 E 2.00 823.22 3198.45 4.00 180.00 3032.56 831.93 S 0.00 E 2.00 831.93 3206.92 3.83 180.00 3041.00 832.51 S 0.00 E 2.00 832.51 Beluga Target 3298.45 2.00 180.00 3132.41 837.16 S 0.00 E 2.00 837.16 3398.45 0.00 180.00 3232.39 838.91 S 0.00 E 2.00 838.91 End of Drop 3500.00 0.00 180.00 3333.94 838.91 S 0.00 E 0.00 838.91 4000.00 0.00 180.00 3833.94 838.91 S 0.00 E 0.00 838.91 4500.00 0.00 180.00 4333.94 838.91 S 0.00 E 0.00 838.91 5000.00 0.00 180.00 4833.94 838.91 S 0.00 E 0.00 838.91 5500.00 0.00 180.00 5333.94 838.91 S 0.00 E 0.00 838.91 6000.00 0.00 180.00 5833.94 838.91 S 0.00 E 0.00 838.91 6500.00 0.00 180.00 6333.94 838.91 S 0.00 E 0.00 838.91 6812.06 0.00 180.00 6646.00 838.91 S 0.00 E 0.00 838.91 Tyonek Target 7000.00 0.00 180.00 6833.94 838.91 S 0.00 E 0.00 838.91 7500.00 0.00 180.00 7333.94 838.91 S 0.00 E 0.00 838.91 8000.00 0.00 180.00 7833.94 838.91 S 0.00 E 0.00 838.91 8500.00 0.00 180.00 8333.94 838.91 S 0.00 E 0.00 838.91 9000.00 0.00 180.00 8833.94 838.91 S 0.00 E 0.00 838.91 9500.00 0.00 180.00 9333.94 838.91 S 0.00 E 0.00 838.91 10000.00 0.00 180.00 9833.94 838.91 S 0.00 E 0.00 838.91 10166.06 0.00 180.00 10000.00 838.91 S 0.00 E 0.00 838.91 TD All data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from Est RKB (Glacier 1) (265.00 Ft above mean sea level) . Bottom hole distance is 838.91 on az~uth 180.00 degrees from wellhead. Total Dogleg for wellpath is 60.00 degrees. vertical section is from wellhead on az~uth 180.00 degrees. Calculation uses the min~um curvature method. Presented by Baker Hughes INTEQ ) MARATHON Oil Company Clam Shell Pad,CG#l Exploration,Kenai Peninsula, Alaska Comments in wellpath ------- MD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- TVD ) PROPOSAL LISTING Page 2 Your ref Clam Gulch #1 Ver 1 Last revised: 2-May-2002 500.00 500.00 0.00 S 0.00 E KOP 1500.00 1454.93 255.87 S 0.00 E End of Build/Turn 1898.45 1800.00 455.10 S 0.00 E End of Hold 2448.76 2300.00 682.93 S 0.00 E Sterling Target 3206.92 3041.00 832.51 S 0.00 E Beluga Target 3398.45 3232.39 838.91 S 0.00 E End of Drop 6812.06 6646.00 838.91 S 0.00 E Tyonek Target 10166.06 10000.00 838.91 S 0.00 E TD Casing positions in string 'A' ------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OON O.OOE 10000.00 O.OOE 4200.00 O.OOE 2200.00 O.OOE 120.00 9833.94 4033.94 2068.59 120.00 0.00 0.00 0.00 0.00 838.91S 838.91S 591. 86S 0.005 ===== ------- Targets associated with this wellpath Rectangular Coordinates Target name Geographic Location T.V.D. O.OOE O.OOE O.OOE O.OOE 4 1/2 9 5/8 Casing 13 3/8 Casing 20 Conductor ----------------------------------------------------------------------------------------------------------- Revised CG#l Sterling Tgt - CG#l Beluga Tgt - 2 CG#l Tyonek Tgt - 2 CG#l TD Tgt - 2 May 2300.00 3041. 00 6646.00 10000.00 800.005 800.00S 800.00S 800.00S O.OOE O.OOE O.OOE O.OOE 2-May-2002 2-May-2002 2-May-2002 2-May-2002 1203/4" 3M Diverter 1----.. I Diverter Spool C) ) Marathon Oil Marathon NNA # 1 Diverter "'> I I ...... ~ / \ I Flow line / I I '" , I I í 116" Automatic Hydraulic Valve ¡ \ :::0: 116" Diverter Line I Flow Nipple I 13 5/8" 5M Annular Preventer 13 5/8" 5M Double Ram Preventer 3 1/8" 5M Manually Operated Valves 13 5/8" 5M Single Ram Preventer ) Marathon Oil Marathon NNA # 1 BOP Stack ) I Flow Line I I I -----. . r ~ "> / I I I I ) < I Pipe Ram I I Blind Ram I 3 1/8" 5M Hydraulically Operated Valve < 1 .....1 ,¡ IChoke(J@[IXl t ........ I 1 < I Pipe Ram I ) I I, < 1 I í ) ~~ :~ IXlIXl)KiII I I I~:)/ 135/8" 5M Cross I ~ 3 1/8" 5M Manually Operated Valve ) ') Marathon Oil Marathon NNA #1 Choke Manifold ITo Gas Buster I To Blooey Line Bleed off Line to Shakers ~ t ~ \..-- J r-I ~ t I , CJ®[~ ~ J CJD[~I " ) ( ~ ( ~ :=\ ~_J ~ ø J®:JD[ 0 J®[~ " L-J I I 13" 5M Valves I Î r-1 2 9/16" 10M Swaco Hydraulically Operated Choke ~ I From BOP Stack 3 1/8" 5M Manually Adjustable Choke ~ S3'-it" 10ft..... mfA ío-_J' ~ ~ . I f , i :5.. Min'A1tR - ~ -j\ I ~....J: i ..... . - . a ala PILL PIT I I ~ I .W: I t- '<, I ;~: I ., e:I~ ~¡ - I I I I t I I I I l :3W 9l tH;UO Pi 5\1 9l. 11-600 PT . . -œ ~ . , ~ I I 1 r-----ï I I L________... I I I CENTRIFUGll I UNIT I I " I ..' X 10' I I . I I I I I I I I r I I I D1J4P I I 1 - I ¡ I (\ I I ....---, I ...." I 1"~i(JœJ[]Y'\ L____-J IIDEGASSER) " I , ,- I t I '-- .. f-----i ~-----~t r , 1.__.J U I 1 I I I r--' Q I r I' r I t I II I . r':tL 111 I ei '~I ß!: III I ~ I J tI II I c I I t 'I 1 1 ~ f I ~ II I :Ii:: i-I I III I Œ , U I I R 'I " I L_____J L..__ ___.J I r---;-----,.-ì I ., I IØP\.) ...,,) I I L. I I I o -46"1" ~- "- 12' x KCD!4Y 3' 14'-G' Ø"-O' 15 IP i 6 X '5 U· : ut I 75 HP 6 X :5 U· ; ui 7'5HP 6X5 U· 75 HP 6X5 U- ~ :...2 -, ~ .11 II' ar... l . . . 't 4F .4 !l .4 , .. I :J" { ~ATIII .. . t , .. I 4. ~. 118 1IDS{ ... . re \.. . ..,... c: .. till 11IIIIf ) '" J SURFACE USE PLAN FOR Marathon NNA # 1 Surface Location: SE 1/4 of SE 1/4, Sec. 29, T2S, R12W, S.M. 1. Existing Roads The Sterling Highway will be used for access to the Clam Gulch well site and is shown on the attached map. Clam Gulch, Alaska is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed A new pad and access road will be permitted, and constructed for this program. 3. Location of Existing Wells There are no existing wells in the near vicinity of the proposed pad location. 4. Location of Existing and/or Proposed Facilities No facilities are proposed at this time, however, a gravel drilling pad will be required. 5. Location of Water Supply A water well will be drilled from the pad to a point below any local potable drinking water sources as stipulated. 6. Construction Materials Gravel will be required for the drilling site and possibly the access road. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location, The cuttings and excess mud will be hauled to Pad 41-18 in the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176) . M:\Wells\Ninilchik\Clam Gulch\SU RFUSE.doc Su rface Use Plan Marathon NNA # 1 Page 2 ) ) b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them, Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose, Bottled water will be used for human consumption. Potable water will be obtained from the water well on the pad. S & R will collect and transport sanitary wastes to their ADEC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Reclamation of the pad, if required by the landowner, will occur after abandonment of all wells, 10. Surface Ownership The Ninilchik Native Association is the surface owner of the land at the Marathon NNA pad, 11. Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed M:\Wells\Ninilchik\Clam Gulch\SURFUSE.doc Su rface Use Plan Marathon NNA # 1 Page 3 ) ') herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U,S.C. 1001 for the filing of a false statement. Date: June 7,2002 r¿ _"~.~ / l . ... "",dU"~>:~>' . .................. """.'{.:~;' .~~~:""-"-':-r::~'~-/Ç --~-,~_.._...._._.__.~...... Senior Drilling Engineer Marathon 6il Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6332 Name & Title: M:\Wells\Ninilchik\Clam Gulch\SURFUSE.doc R14W R 13W T 1 S r MCG1 -¢- o . 3 I MILES STUCTURE TYONEK T2 CI = 500' / / / / / / MARATHON Oil COMPANY ALASKA REGION COOK INLET, ALASKA June 2002 o:freehandlninìlchìklninì_cgJoc.fh9 HI'.ILCHIK ---. , ~ T'.N~· ~ 1 ~~N· , + + .. <I- I+-I " , I .¡.' '" Sterl~ng I I Hghway . ~'lN~1'"W + + ;' ~ .. (. ..'-- ' I Tl£~~13W ......: .. ~ ..... . .. ..... ~ - , ':. 4 , Marathon Oil Company NNA 1 Location June 2002 ~ ) ) September 17, 2002 Mr, Ben Schoffmann Marathon Oil Company PO Box 196168 Anchorage, AK 99519-6168 DearMr, Schoffmann: SUBJECT: FINAL CONSISTENCY DETERMINATION Marathon Abalone No. 1 Well STATE I.D, AK 0208-060G The Division of Governmental Coordination (DGC) has completed the State's review of your project for consistency with the Alaska Coastal Management Program (ACMP) and has developed this determination based on reviewers' comments, The State concurs with your certification that the project is consistent with the ACMP with the conditions outlined later in this determination, Scope of Pro.iect Reviewed Marathon Oil Company proposes to drill the Marathon Abalone No, 1 during the first quarter of2003 from a surface location owned by the Ninilchik Native Association (NNA), The project will be in support of exploration for natural gas within the new Ninilchik Unit Operated by Marathon, The project is located in Clam Gulch, west of the intersection of the Sterling Highway and Blueberry Avenue, The well will be drilled with a water-based mud system and all drilling waste will disposed via a permitted Class II well at the Kenai Gas Field. No discharges of drilling waste will take place at the Abalone # 1. Marathon proposes to place a dual liner over the entire operational footprint for the drilling rig, diesel storage tank, and mud system, The dual liner is comprised of a 20 mil thick synthetic impermeable liner that is underlain by a felt liner that acts to cushion the surface liner and prevent punctures, Marathon will use a double-walled diesel storage tank that has an annulus capable of containing 110% of the volume of the inner tanle Marathon will attempt to place the diesel storage tank at least 100 feet away from the edge of the pad and will store adequate spill response equipment on site to handle accidental leaks or releases of oil~ gas, or other hazardous substances, The edges of the liner are bermed using timbers that create a 6- ) Mr. Ben Schoffmann Final Consistency Determination -2- ) September 17, 2002 State 1.0. AK 0208-060G inch freeboard, The total capacity of the lined area under the rig, diesel tank, and mud system is greater than the equivalent volume of 110% of the volume of the diesel tank, plus 12 inches of freeboard. Marathon has received an exemption for both the Proof of Financial Responsibility (FR) and Oil Discharge Prevention and Contingency Plan (C-Plan) Requirements from the Alaska Department of Environmental Conservation (ADEC). This approval is for exploration and development activities within the Ninilchik Unit since it has been determined that only natural gas will be encountered in the shallow stratigraphic intervals that are the focus of this exploration effort. If liquid hydrocarbons are encountered during exploration, Marathon will cease operations and obtain FR and C-Plan approvals from the ADEC, Marathon proposes to drill a new water well on the pad and intends to develop a deep aquifer to avoid affecting shallower aquifers that are utilized by private wells, Maximum water use by the operations drilling could be 42,000 gallons per day for a five-day period when the initial mud system is developed, Thereafter, maximum daily use would not exceed 21,000 gallons per day to maintain the mud system, Marathon has permitted a portable lift-station and holding tank that accompany the drilling rig camp for domestic wastewater, The wastewater generated is removed by a qualified contractor for disposal. The average maximum use rate for this purpose is approximately 500 gallons per day, No discharges of wastewater will take place nor will there be any discharges of mud or fluids used for drilling operations, Marathon conducted an archaeological investigation of the site and found no evidence of historic use within the area identified for the proposed pad and in the outlying areas surrounding the pad, The Corps of Engineers has determined that wetlands will not be crossed or filled as part of this project, therefore a Department of the Army permit is not required, The project description was changed in this final consistency determination to reflect the Corps of Engineers determination mentioned above. Two identically worded permit stipulations listed in the September 12 proposed consistency determination (#4 and # 14) were combined in this final consistency determination, The applicant and state agency reviewers concurred with these changes, Authorizations This final consistency determination, developed under 6 AAC 50, applies to the following State authorizations: Alaska Department of Natural Resources (DNR) Plan of Operations LOICI 02-19 Temporary Water Use Permit A2002-39 Consistency Determination Based on the review of your project by the Alaska Departments ofFish and Game and Natural Resources, and the Kenai Peninsula Borough Coastal District, the State concurs with your certification that the project is consistent with the ACMP with the following modifications, which will appear as stipulations on the Department of Natural Resources Plan of Operations authorization: ') Mr. Ben Schoffmann Final Consistency Determination -3- ) September 17, 2002 State 1.0. AK 0208-060G 1, Roads, pads and work areas must be kept clean, Putrescible waste stored outside must be enclosed in containers that prevent direct contact by wind, birds and animals. Garbage must be hauled away to a DEC approved disposal site. Industrial trash and materials must be stored in a manner that prevents transport by wind, 2, Trash, survey lath, roadway markers, and other debris associated with lessee activities that has accumulated on or along roads or drill pads shall be regularly picked up and properly disposed, 3, Equipment operation and material storage outside the planned footprint of roads, pads, and designated storage areas shall be minimized, Rationale: These measures are necessary to prevent accumulation of solid waste, to prevent the loss of and/or contamination of habitat, to protect lands from unauthorized solid waste disposal or burial and to ensure consistency with the statewide Habitats standard (6 AAC 80.130), Coastal Development standard (6 AAC 80.040), and the Kenai Peninsula Borough Coastal Management Program (KPBCM) enforceable policies 5.4, Habitat Protection; and 12.0, Fish and Wildlife Habitat. 4, Sediment and water quality control measures shall be placed and maintained at all worksites to maintain existing surface flow patterns and prevent introduction of sediments and other contaminants into the Clam Gulch Critical Habitat Area, 5, Surface drainage on the drill pad shall be maintained to direct runoff into a lined sump area away from the Clam Gulch Critical Habitat Area, 6, Spill response equipment and supplies shall be readily available on site to handle accidental leaks or spills of fuel or toxic materials, Rationale: These measures are necessary to protect surface habitats, prevent erosion, and to prevent an accidental hazardous substance discharge from contaminating marine and freshwater habitats in accordance with the Energy Facilities Standard (6 AAC 80.070) and the Habitats Standard (6 AAC 80.130) of the ACMP and the KPBCMP enforceable policies 5.2, Water Resources; 5.4, Habitat Protection; 12.0, Fish and Wildlife Habitat; and 13.2 (c) Storage of Petroleum and Petroleum Products. 7, Fuel and hazardous substances, Secondary containment shall be provided for fuel or hazardous substances, Secondary containment means an impermeable diked area or portable impermeable containment structure capable of containing no less than the equivalent of 11 ° percent of the volume of the largest independent container plus 12 inches of freeboard, Double-walled tanks do not qualify as secondary containment unless an exception is granted for a particular tank, Hazarcbus substances are defined under AS 46,03,826(5) as (a) an element or compound which, when it enters the atmosphere, water, or land, presents an imminent and substantial danger to the public health or welfare, including fish, animals, or vegetation; (b) oil; or (c) a substance defined as a hazardous substance under 42 U,S,C, 9601 (14), a. Container means any item that is used to hold fuel or hazardous substances, This includes tanks, drums, double-walled tanks, portable testing facilities, fuel tanks on small equipment such as light plants and generators, flow test holding tanks, slop oil tanks, bladders, and bags, Manifolded tanks ) Mr. Ben Schoffmann Final Consistency Determination -4- ) September 17, 2002 State 1.0. AK 0208-060G must be considered as single independent containers, Vehicles, including mobile seismic tanks, are not intended to be included under this definition, All independent fuel and hazardous substance containers shall be marked with the contents and the lessee or contractor's name using paint or a permanent label. (Note: The permittee is ultimately responsible for contractor's compliance with these Standard Conditions,) b, Secondary containment or a surface liner must be placed under all container or vehicle fuel tank inlet and outlet points, hose connections, and hose ends during fuel or hazardous substance transfers, Appropriate spill response equipment must be on hand during any transfer or handling of fuel or hazardous substances to respond to a spill of up to five gallons, Transfer operations shall be attended by trained personnel at all times, Vehicle refueling shall not occur within the annual floodplain, Surface liner means any safe, non-permeable container (e,g" drip pans, fold-a-tanks, etc,) designed to catch and hold fluids for the purpose of preventing spills, Surface liners should be of adequate size and volume to contain the worst-case spill that is likely to occur, c, Containers with a total capacity larger than 55 gallons which contain fuel or hazardous substances shall not be stored within 100 feet of a waterbody, d, Timbers used for freeboard on secondary containment shall be stabilized and joined between all timbers, and at all corners, and shall remain attached for the duration of the project. e, The perimeter berm for the pad shall be maintained for the duration of the described project. f. Fluid management of the secondary containment and the stormwater sump shall assure that no hazardous substances are discharged from the project site, g, Exceptions, After consultation with other resource agencies and affected coastal districts, the lessee may under unique or special circumstances obtain exceptions to this stipulation on a case-by-case basis. h, Spill notification, The lessee or permittee shall immediately notify ADNR (or the appropriate land manager) and ADEC by phone of any unauthorized discharges of oil to water, any discharge of hazardous substances (other than oil), and any discharge of oil greater than 55 gallons solely to land and outside an impermeable revetment. If a discharge of oil is greater than 10 gallons but less than 55 gallons, it must be reported within 48 hours by phone or fax, If a discharge is less than 10 gallons, it may be reported in writing on a monthly basis. If an unauthorized discharge greater than 55 gallons is made to a secondary containment, it must be reported within 48 hours by phone or fax, 1. All fires and explosions must also be reported, The ADNR 24 hour spill report number is (907) 451- 2678; the fax number is (907) 451-2751. ADNR and ADEC shall be supplied with all follow-up incident reports, The ADEC oil spill report number is (800) 478-9300, Rationale: These stipulations are necessary to protect the chemical characteristics of surface water and upland habitat that contribute to its ability to support life by reducing the escapement of fuel and foreign fluids, promoting early detection, and decreasing response time, assuring timely rehabilitation and ensuring consistency with the statewide Coastal Development standard (6 AAC 80.040), Habitats standard (6 AAC 80.130), (6 AAC 80.140), Air, Land, and Water Quality standard (6 AAC 80.130), and the KPBCMP Enforceable Policies 5.2 (a) Water Resources, 5.4, Habitat Protection, 12.0 Fish and TVildlife Habitat, 13.2 Storage of Petroleum and Petroleum Products. ) Mr. Ben Schoffmann Final Consistency Determination -5- ) September 17,2002 State 1.0. AK 0208-060G 8, The area within and along the road and pad may be cleared of timber, brush, stumps, and snags. Unless waived, logs greater than 4" in diameter which are not removed shall be disposed of as follows: a. Spruce: Logs shall be cut into 24-inch maximum length sections. Sections shall be scattered (not piled) in open areas of the right-of-way to permit rapid drying and prevent spruce bark beetle outbreak. Sections shall not be covered by slash, brush, or other residue, b. All other tree species: Logs shall be cut into 10-15 foot lengths and placed so they cannot roll. Tree sections shall not be piled on top of each other, c. Removal of brush, slash, and immature trees will be accomplished by any of the following three methods: (1) Spreading and scattering in the adjacent brush area without damaging other trees, (2) Chipping and scattering in such a way as to preclude their being washed into any watercourse, or . (3) Piling and burning in accordance with procedures and practices established by the DNR, Division of Forestry and the air quality regulations of the DEC, Rationale: This measure is necessary to prevent the spread of spruce bark beetles, provide for the use or proper disposal of wood, maintain compatibility between concurrent uses and to ensure consistency with the statewide Energy Facilities (6 AAC 80.070), Timber Harvest and Processing (6 AAC 80.100), and with KPBCMP Enforceable Policies 5.2 (a) Water Resources, 5,4, Habitat Protection, 12.0 Fish and Wildlife Habitat. 9, Rehabilitation shall be to the satisfaction of the Director, Abandoned gravel structures such as roads and pads shall maintain natural drainage patterns and not cause ponding or erosion, Rationale: This measure is necessary to eliminate maintenance of gravel structures when they are not longer useful and, to the extent practicable, return the disturbed area to a natural condition that is compatible with present and future land use and to ensure consistency with statewide Energy Facilities standard (6 AAC 80.070), Habitats standard (6 AAC 80.130), and the KP BCMP Enforceable Policies 5.2 ( a) Water Resources, 5.4, Habitat Protection, 12.0 Fish and Wildl?fe Habitat. 10, Surface drainage on the drill pad shall be maintained to direct runoff away from bluff and Cook Inlet marine waters, Rationale: Removal of vegetative cover and organic matter is likely to reduce the water holding capacity and increase the volume of runoff flowing toward the bluff This stipulation is necessary to prevent gully formation and reduce the potential for accelerated erosion and water quality impacts and to ensure consistency with the KP BCMP 3.1 Design and Siting Criteria, 3.3 Erosion, 3.4 Landslides, Mass Wasting, and Avalanche Hazards and the statewide Habitats standard (6 AAC 80.130) and the Air, Land, and Water Quality Standard (6 AAC 80.140). ) Mr. Ben Schoffmann Final Consistency Determination -6- ) September 17, 2002 State I. D. AK 0208-060G 11, When soils are disturbed, or where vegetative mats are damaged or destroyed in uplands, wetlands, or other habitats the applicant and its representatives are encouraged to accomplish immediate habitat restoration measures, Rationale: This stipulation is necessary for consistency with the KP BCMP Enforceable Policies 5.4, Habitat Protection and the statewide Habitats standard (6 AAC 80.130). 12, All waste generated during the project shall be removed and disposed of, This includes, but is not limited to, human waste, trash, garbage, litter, oil drums, petroleum/petroleum products, ashes from burned materials, and discarded equipment. The project location must be kept clean at all times, Rationale: This stipulation is necessary for consistency with the KP BCMP Enforceable Policies 5.4, Habitat Protection, 12.0 Fish and Wildlife Habitat Protection and the statewide Habitats standard (6 AAC 80.130). 13. Hazardous substances must be removed from the project site and properly managed, Debris (such as soils) contaminated with motor oils, solvents, or other chemicals may be classified as hazardous and shall be recovered from the sited and managed and disposed of. Rationale: This stipulation is necessary/òr consistency with the KP BCMP Enforceable Policies 5.2 (a) Water Resources; 5.4, Habitat Protection; 12.0, Fish and Wildlife Habitat; 13.2, Storage of Petroleum and Petroleum Products; and the statewide Air, Land, and Water Quality Standard (6 AAC 80.140). This final consistency determination represents a consensus reached between you as the project applicant and the reviewing agencies listed above, regarding the conditions necessary to ensure the proposed project is consistent with the ACMP, Most state permits should be issued within five days after the issuance of the final consistency determination, Other Concerns/Advisories Please be advised that although the State has found the project consistent with the ACMP, based on your project description and any modifications that appear as stipulations contained herein, you are still required to meet all applicable State and federal laws and regulations, Your consistency determination may include reference to specific laws and regulations, but this in no way precludes your responsibility to comply with other applicable laws and regulations, If changes to the approved project are proposed prior to or during its siting, construction, or operation, you are required to contact this office immediately to determine if further review and approval of the revised project is necessary, If the actual use differs from the approved use contained in the project description, the State may amend the State approvals listed in this consistency determination. If the proposed activities reveal cultural or paleontological resources, please stop any work that would disturb such resources and immediately contact the State Historic Preservation Office at (907-269-8720), This final consistency determination is a final administrative decision for the purposes of Alaska Apellate Rules 601-612, Any appeal from this decision to the superior court must be made within 30 days of the date of the determination, ) ') September 17, 2002 State 1.0. AK 0208-060G Mr. Ben Schoffmann Final Consistency Determination -7- If you have any questions regarding this process, please contact me at 257-1352 or Email nbrudie@jpo,doi,gov, Sincerely, Nina Brudie Project Review Coordinator ecc: Charles Underwood, Marathon Oil Company Matt Rader, ADNR DOG Patricia Bettis, ADNR DML W Mark Fink, ADFG Bob Blankenburg, ADEC Dave Casey, COE Dan Bevington, Jennifer Eskue, KPB Bob Shavelson, Cook Inlet Keeper ... 'I kjI ... ') ) Alaska Business Unit ~ , M MARATHON ~ Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 21 , 2002 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 RE: Well Re-Naming Dear Mr. Maunder: Marathon Oil Company requests the proposed well (10-401 dated June-7-2002) Marathon NNA #1 be re-named as Abalone #1, If you have any questions concerning this matter, please contact me at 564-6332. In addition, I have attached the MI mud program for the well. Please note the 8-1/2" production section in the mud program will be drilled as a 7" hole. Thank you. Sincerely, k?f clli~ t,'V) U)¡n.[}LLYL ~£~ Oc.tJoJ 200 ¿ Steven S, Lambe Drilling Engineer Enclosure 551 ORIGINAL 1''''1 \1:"" oi""" !'i'"" ~ ~~, ~ if'" D ,~,. I~ ~." ~ ~\ ì.' :1'"' ::.,. L \,. '1,'" ~ ~,,¡ ~"- l\i ¡r ,) '~) ?Ofi'i ,....~~i..)"...:1 - - ~ ,\,~~ 'I' ":-111., . j-I¡. .";,'" "i;',,: 1'r'Vr,¡-;, ".~ i-:',' r",:, ÞJaslŒ ~M &. \;.~:lb COl¡:!~. 1... ~.."'...~'"'.... ~'~: ::,', (:'"'.~ " . ) ') M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 Phone (907) 274-5564 Fax (907) 2709-6729 Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Steve Lambe Steve; Enclosed is the recommended drilling fluid program for Well Marathon NNA #1 to be drilled later this year, The following is a brief synopsis of the program, Overview: Marathon NNA #1 is an exploration well targeting the Lower Beluga and Tyonek formations, At T,D" 4-1/2" casing will be run and cemented in place, The well will be completed with KCl brine. Gel/Gelex spud mud will be used for the surface interval. Flo-Pro fluid will be used for the lower two intervals, Sized calcium carbonate will be used in the intermediate interval to bridge off the highly porous Ster- ling and Upper Beluga formations, Surface Interval: A standard fresh water Gel/Gelex spud mud will be used, Initial funnel viscosity should be in the 50 - 75 sec/qt range, Lower funnel viscosity to 45 - 60 sec/qt after gravel has been drilled, Lower fluid loss to < 10 cc' s API prior to running surface casing, Intermediate Interval: This interval will be drilled with a FloPro fluid with 20 PPB sized calcium carbonate. After drilling out the surface cement and 20 - 25 feet of new hole, the pits should be cleaned and the well displaced to the new fluid per the listed formula, Fluid loss should be maintained between 10 - 6 cc' s API, Mud weights should be kept as low as possible through aggressive use of solids control equipment. Fluid loss should be reduced to +1- 6 cc's prior to running casing, Production Interval: This interval will also be drilled with Flo- Pro fluid, Chloride concentrations should be maintained be- tween 25,000 & 30,000 PPM. Fluid loss should be maintained in the 6 - 8 cc's API with additions of DualFlo, Completion: This program assumes the well will be completed with 6% KCl brine. Tony Tykalsky Project Engineer M-I Drilling Fluids I . ) ) Interval Summary - 17 1/2" Hole Well Marathon NNA#l 0- 2200' I Drilling Fluid System Gel / Gelex Spud Mud Key Products MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / Polypac Su- preme SL / M - I Seal/Sodium Bicarbonate Solids Control Shale Shakers / Centrifuge Van ? Potential Problems Lost circulation, coal sloughing, Interval Drilling Fluid Properties Depth Mud Plastic Yield API Funnel Drill Interval Weight Viscosity Point Fluid Loss Viscosity Solids (ft) (pp~) (cp.) (lb.!lOOft2) (mJ/30min) (sec/qt) (% ) 0-700' 8,8 -9,0 10 - 12 30 - 40 NC/14 50 - 75 0-3% 700 - 2200' 9,0-9,2 12 - 15 20 - 30 8 -12 45 - 60 <6% · Treat drill water with Soda Ash to reduce hardness, · Build spud mud with 20 - 25 PPB M - I Gel · Lower funnel viscosity to 45 - 60 after gravel zone has been drilled, · Add Gelex as needed to maintain sufficient viscosity for hole cleaning. · Increase funnel viscosity if fill on connections begins to occur, · Reduce fluid loss with additions of Polypac Supreme SL prior to running surface casing, · Add 2 - 5 PPB ofM-I Seal Fine to mud system if seepage losses becomes a problem,. · Condition mud prior to cementing casing to reduce yield point and gel strengths, · Estimated volume usage for interval- 2745 barrels. · Communicate daily with in town Project Engineer regarding mud properties, hole condi- tions, proposed program changes. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ..,.. DRILLING , ~ FLUIDS , . ) ) Interval Summary - 12 1/4" hole Well Marathon NNA#1 2200- 4250' Drilling Fluid System Flo-Pro Key Products M-I Gel / Gelex / Caustic Soda / Safecarb F, M, C / Polypac Su- preme UL / M - I Bar / Ventrol 401 / Soltex / Flo Vis Solids Control Shale Shakers / Centrifuge Van Potential Problems Lost circulation in Sterling sands, coal sloughing, drill solids build- up, gas kick, tight hole conditions 1 Interval Drilling Flúid.·prôperties Depth Interval (ft) 2200 - 3000' 3000 - 4250' Yield Point (lb./l00ft2) 18 - 24 18 - 24 API Fluid Loss (ml/30min) 8 -10 8 -10 pH Drill Solids (0/0 ) <5% +/- 5% ·Mud Weight (ppg) +/- 9,2 9,2 - 9.4 Plastic Viscosity (cp.) 8 -12 10 - 14 9,0-9,5 9,0-9,5 · Isolate one pit with surface mud use this to drill out cement and 10 - 20 feet of new hole, · Clean other rig pits and build new Gel fluid using the following formula: · Drill water; .25 ppb Soda Ash; 21 ppb KCL; 2 ppb FloVis; 2 ppb DualFlo; 2 ppb Safecarb Fine; 18 ppb Safecarb Medium; Caustic Soda for pH of 9.0 - 9.5; .25 ppb Greencide 25G; Conqor 404 for 2000 ppm · Displace spud mud to Flo_Pro Fluid using a H20 spacer (15 - 25 bbls). Build additional vol- ume as needed, (See following sheets for bridging concentrations) · If running coals become a problem, treat with a 2 PPB addition of Ventrol 401 and Soltex, · Maintain low mud weight through aggressive use of solids control equipment. · Maintain proper bridging concentration during dilution and whole mud additions, · Estimated volume usage for interval - 1724 barrels. · Communicate daily with in town Project Engineer regarding mud properties, hole condi- tions, proposed program changes. M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~ DRILLING , ~ FLUIDS ". ~. ~ ) ) Interval Summary - 8 1/2" hole WellMarathonNNA#1 4tSO -10166' Drilling Fluid System Flo-Pro Fluid Key Products Flo- Vis / DualFlo / KCI / Greencide 25G / Safecarb F / Ventrol 40 I / SoItex / Conqor 404 / Caustic Soda / M - I Bar Solids Control Shale Shakers / DesiIter / Centrifuge Van Potential Problems Lost circulation, differential sticking, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling FIµid Properties Depth Mud ·Plastic LSRV MBT API Drill Interval Weight Viscosity 1 min ppb Fluid Loss pH Solids (ft) (ppg) (cp.) (lb./l00ft2 (ml/30min) (% ) ) 4250 -7500' 9,2-9,5 8 -12 40,000 +/- 7,5 <8 9.0-9,5 <5% 7500 - 10166' 9,2-9.5 10 - 14 40,000 < 7,5 6-8 9,0- 9,5 +/- 5% · Isolate one pit with surface mud use this to drill out cement and 10 - 20 feet of new hole, · Clean other rig pits and build new FloPro fluid using the following formula: · Drill water; .25 ppb Soda Ash; 21 ppb KCL; 2 ppb FloVis; 2 ppb DualFlo; 20 ppb Safecarb Fine; Caustic Soda for pH of 9.0 - 9.5; .25 ppb Greencide 25G; Conqor 404 for 2000 ppm · Displace intermediate hole fluid to new FloPro fluid using a H20 spacer (15 - 25 bbls), Build additional volume as needed, · If running coals become a problem, treat with a 2 PPB addition of Ventrol 401 and SoItex, · Be prepared to weight up with barite additions for well control (possible high gas pres- sure). · Estimated volume usage for interval- 1403 barrels, · Communicate daily with in town Project Engineer regarding mud properties, hole condi- tions, proposed program changes. ~ DRilliNG r ~ FLUIDS M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ) ) August 5, 2002 Mr, Steve Davies AOGCC VIA email RE: Marathon Abalone 1 Permit Application Surface Casing Depth Within Marathon's proposal to drill the above mentioned well, the surface casing setting point of 2,200'(' TVD) is designed to meet the AOGCC requirements under Title 20 AAC 25,030, AOGCC has requested under 20 AAC 25,030(c)(3) to quantify the total dissolved solids (TDS) of formation waters in the vicinity of the casing shoe ( 2,200 ft.), The following facts are understood regarding the casing depth of this proj ect and the protection of plausible drinking water: The surface casing will be set into the Tertiary Sterling formation (Figure 1). The drinking water in the area of the project and across the entire Kenai Peninsula is from Holocene glacial sand and gravel (Figure 1) which is higher quality (less than 1000 ppm TDS, Figures 1 & 2) than the water from the deeper Tertiary sandstones. The deepest water well in the area (Sec, 29 & 32 T2N R12W) is 338 feet in depth (Figure 3), while the deepest water well on the Southern Kenai Peninsula is less than 500' deep (Cook Inlet Areawide 1999 Oil and Gas Lease Sale Final Finding of the Director January 20, 1999, Chapter 5, Page 48,; Figure 4), The Tertiary section is a known hydrocarbon bearing interval that is not compatible with drinking water, The shallowest indication of possible hydrocarbon content is at 2,100' MD (Figure 1) in the Union Clam Gulch 1 well. TDS calculations (EP A approved Rw calculation using the Resistivity/ Porosity method for Rw's greater than 1,0 ohmm; Figure 2) for the sandstone intervals around the surface casing shoe range from 2000 ppm to 2500 ppm, Because the TDS is less than 10,000 ppm, these calculations represent an underestimate of TDS due to the effect of reduced influence of Sodium Chloride and the increase of other solids on a percentage basis, A water analysis of this water or one of similar origin and depth is not available to determine the concentration of other components that contribute to TDS, EP A criteria for exemption of an "underground source of drinking water" (40 C,F,R 146.4) can occur and applies in this case if "a freshwater aquifer.., is currently not serving as a source of drinking water and ",cannot be used in the future as a source of drinking water because ...it is at a depth which makes recovery of water for drinking water purposes economically or technologically impractical. Marathon Abalone 1 Permit Application Surface Casing Depth Page 1 ) ) Given the above infonnation, the surface casing depth proposed for the Ninilchik State 1 project is sufficient to protect any plausible and economic drinking water in the area even though the TDS for the Tertiary sandstone beds around the casing shoe calculate to less than 2000-2500 ppm, Your consideration of this infonnation and approval of the project are greatly appreciated, Please contact me if you have additional questions, Best regards, David L, Brimberry Senior Geologist CC: Charles Underwood, Marathon RES Steven Lambe, Marathon Drilling Attachment - Abalonel_TDS_rec_figures,ppt Marathon Abalone 1 Pennit Application Surface Casing Depth Page 2 ( Union Clam Gulch 1) August 2002 Rw ohmm TDS Depth TVD (Res.! Phi) ppm _~ q'º~"'''''~'_~,"_~'''~'_'~M~_'_'~ q_9___,_,~,~,~J_~,~", 6 º,£~"_ _M~P ~,~~X:,'" 4 º,,9_ 1780 1780 2.98 67 2000 2300 2300 2.2 (á) 72 F 2500 Figure 2 Marathon Abalone 1 Permit Application Calculated Total Dissolved Solids of Selected Sandstones in ') ) TOTAL COMPLETION OWNER SECTION DEPTH DATE T2N-R12W Grizzell 29 55 1980 Heames 29 88 1983 AK Div. Parks 29 107 1984 Cuseo 29 160 1964 Shear 32 153 ? - Wade 32 338 1996 Figure 3 Marathon Abalone 1 Permit Application DNR Registered Water Wells in Area of Project August 2002 ) ) FIGURE 5.2 ADNR 8196 Cook. Inlet Wellbore Schematic . , MOO' · . . ~; ~ . \~ . . '.."d' , . '~m' . . .}. . . ---------------- t ~.~~,;::k-F:;n-l¢lo~ ~~.~": ;-:.. ~;~~; .....;;.i.w ~..:. __;~~ ~ .. ".. Primary Oil ~_~~·:.:.:~·~:.~·~~.~.~C·~ Zones " . ." . ." . . .c. . . :'" . . ~.. . :,,' . ~em.~ock I0nl!:~tIOß.;. . . L ... I................ =~= =c? ='.~:: :$":: ~(# '; =.è:: · . . . . West Foreland . . .~. . ~ /-::>:-:~~:.:~.;::~.:~::~>:~".I ~ I · . . . . . . . . . . . . . . . . . . ·1 41 I · ". . c, . Cretaceous "'.... . ." . (J :(YY:?:k? l~il · ':.:.0' . ..). ,,::~. . ~. . '~:.::....' . . O:' -; ¡: f.I ~ t' ~ 4J ... ..:,;¡.f.'<;:....~:~.. . ~3. . .¡:.~~..l. ~/.'.' ~ ~.; ~~~f'~ i~~'~ ~~.;.~:~~ ~:~ ~~ ~~ ~,~~ ~~i~~ ~~ ~~~~= ... þ.... ........... .<.'.¡, . ...':<. . va"" . . ~I' . . I:~:,. . . . ~:\ . ~.:.. :"':':": ~ :..:":~;' :"'d':' ;;'__0':' ---------------- <:~ . t':'" . (:y.o. . ,,'¡,. . ...:~~ . . of.., . . ,I:. Gas Zones~ · ,;1' . (,~. . 1::),0" . ~a' , . "'::,~þ' . ~I '. . ~:I· . ..!::." . (.~ ~ ~ l,~ ' . i,~,~'..1 I 4, (1 ' ~(.~ · . . . . . II ~ . . " . . I . . . . . . ..'>. . . . . . . ~ . . . , . .~ Into ~ . t . ~ . . I . t . . '.) ¿ .~} . . .(~ . . ø. 't." . ~,' . tl' , . Po . . , 4:10 ~ . ".¡:w' ::I ,,,: . '. Be1ll.g' FOflII.lltloll·,: . .~: 0 .................... t'; .' -. - -... -....... -.. "t1. ; 11,\ . t')/-. , ...::¡. . ~ (.';':'''' . .,1. . ~!f . .,:~ . ~I>. . ....1.. , .~':,'r. . . \n' . r<;~' 2,100· ·..5~:~t·~f~~·~~~~~~~~~ Shallowest Underground'"" . h' . ',,' . . rj' . . :'" . ',d . Injection Disposal Well '.~'.' .:....,;... ".~'.','~'.'.'.:'. on Kenai Peninsula ~~·~~.~~·~.~~·.:~-à~·~'k.~ (!.:t. '~"·O":r.:,' '~,,". .\,...~ ..,................, . ---------------- - - -- -- ---- "",:;;.-'-0:. .,......'. . ';:!j. . "~. . . '1::1' ,~¡,'o' ,f)-,,",' .<t.1,'.·. '~~~.,' ,". 'r;;,,'.' .,I~I;·.· .' ,;.' St~ding·..~~~Úo·u·.·. '.,:.' r" ~ . t:'!' oj r,. . . oj<::, . ~ "Wt:J ' . ~ . . .,.".......,..,.".. . '9. " .~ . þ~ . P.. . ,c:;,., ~ . þ, . P. Geologío Key t\..... ................. .... CJ!'~~.~~o.merate 8.. Coal l......J ~~¢It-' - I: . .. . Geologic ]."" '..¿ t."> :,··¡'i. ~,~ :<J \""'.t.' Age · . v . l. ,\ . . .. , v, .,... ., » I:¡ . ..~, f .,:)'1. , /~'. . ,<:,'¡j-. . l>-. ,~\','t ~.. .................... r; · \.~ . . , Unc~n'al.l.dl\ted. . .'''. , Q 500'--.. .<'. . . .. tledlml\!l1u ..,... ~ 8 Maximum :;.. ..~,:... \,:'" .',·z·" "';'"" ,,:,~'''.<:' tJ ~ Water Well Depth ..:.'....,;,.....':-....:'.-...':'.'....;,':.. &.I!I (Southern Peninsulaè'...."'\'...;!:. :~.~.:"~..~.~. ~.~... ~ Packer ----4Iii11 . . . : ·¡T··-.... Oil·. Perforatìons _ ~.,ír.¡:::::=:, & _. . \;.?;:..L-....... Gas Cement --) w"..:::.,"w~ Slee: ~ lA.. Production~' Casing Wellbcn Not 10 Scale ·9.000' ·8000· : ·7000' ·6000· ·5000· II a = II: I. t;,. II' Iii Ii I: II i! (I 1/1 ¡II ;.1. Production tre- -Tubing t¡ Cement ,,,......,.,,,,)0- ·4000' Drilling Mud···········,» ·3000' Steel ·2000' -1000' Oil and Gas"",,· Produotion .~ Figure 4 Marathon Abalone 1 Permit Application Typical Cook Inlet Welbore Diagram from "Cook Inlet Areawide 1999 Oil and Gas Lease Sale, Final Finding of the Director January 20, 1999, Chapter 5, Page 48 " August 2002 ) ) ~··.';:,~~···'~.~~;!wX£~1:T!!r{T:f!2'~il~~j~~~~~~~L~z. Marat~~~o2~E~~T~any 0158 3 1~2: pOlL & GAS CONSERVATION COJ:1MISSION 333Westp 7th Ave Anchorage, Alaska 99501 6 /10/ 2002 MO DY YR ,-- MATCH AMOUNT IN . WOROS WITH NUMBERS 1$ 100.00 ')OID A.FTER 18G DAYS --. .c'-'- THE AMOUNT IN NUMBERS MUST MATCH THE AMOUNT IN WORDS One Hundred Dollars and No Cents DOLLARS; I NATIONAL BANK OF ALASKA ANCHORAGE, ALASKA ~~¡:rr=t=I!~t~~'T~Itl'CiJ';~;i:L:, ," Marathon Oil Company i' / /, /ì . By ~A¡ !:)/<{¿tLIIc¿/ NFl n¡<¡ZED SIGNi,TlJPf ~.~ ~~,~¡¢~>~:~_~~i-.~-->~-;i~?1~.~;. i~~ >~-'~. ~~~-~~!.~~-:Si, ,. _/ -.- " - - ~-_.""":_"-------~ - -' . - .. , _:'-'-':¿---'~--;- ~ ."- III 0 0 . 5 a ~ III I:. 2 5 2 0 0 OS? I: 0 . III 0 ? a 5 b g III NNft tF¡ R£CE\V£D > ...,. {"I'\{\'2 ., I'. \ ': ~ {.I'I' \' . ~\ , i J I.Í v vvi>¡ .' . m'S610n ~ 0'\ (1 ("è" ['f1n~. \.;01\\\ 1\ I AlaSKa h Ol \':w.;;) '..Iv. .... ~ AnchoraQe ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME¿,k¿ìLdt;! N/M 7'1 J (~"M-'.d) .-- /lba-/ðl1e #/ CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) /'/'" EXPLORATION ../ INJECTION WELL INJECTION WELL RED RILL ANNULAR DISPOSAL INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-) SPAClN7TION "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 20 AAC 25,005(t), all records, data and logs acquired for the pilot hole 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), Please note that an disposal of fluids generated, , , Enclosed is the approved application for permit to drill the above referenced well, The permit is approved subject to full compliance with 20 AAC 25,055, Approval to erforate and produce is contingent upon issuance of a servatiY9? order approving a spacing exception. "~~ (Companv Name) will assume the liability 0 any protest to the spacing exception that may occur, ~(~-P'~ -Ä,~'t tu-ë-/( ~ cJ~!t~+- C~-K for c:dd¡'ðVt~ -f¿ì<-+ ~ ~C;¡/~ Lu~. {JU . ~D----._' ~ m'li- 4:Lrt 11 Ò -I- b .9lP f-é ¡red. !tfJ+'/ CL rJ.X:¿6-k ( 2ð-JLfL;~S(51or.:y ../).¿lJ/L.A) Ì/j W--rnIP/¿j.¿ " ~.eÐ.":~ (j C.(YJ/( Sf S/-eJ1 i-- C¡'llC\~ Rev: 5/6/02 C\jody\templates WELL PERMIT CHECKLIS COMPANY MARA THON FIELD & POOL Exploratory WELL NAME ABALONE 1* Initial Class/Type EXP I-GAS ADMINISTRATION APPR 1. Permit fee attached. 2. Lease number appropriate. 3. Unique well name and number. * 4. Well located in a defined pool. 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells. DATE 7. Sufficient acreage available in drilling unit. 8. If deviated, is wellbore plat included. 9. Operator only affected party. 10. Operator has appropriate bond in force. 11. Permit can be issued without conservation order. 9/20/2002 12. Permit can be issued without administrative approval. 13. Can permit be approved before IS-day wait. 14. ACMP Finding of Consistency has been issued for this project SJ } ENGINEERING 15. Conductor string provided 16. Surface casing protects all known USDWs. 17. CMT vol adequate to circulate on conductor & surf csg. 18. CMT vol adequate to tie-in long string to surf csg. 19. CMT will cover all known productive horizons. 20. Casing designs adequate for C, T, B & permafrost. 21. Adequate tankage or reserve pit. 22. If a re-drill, has a 10-403 for abandonment been approved. 23. Adequate well bore separation proposed. 24. If diverter required, does it meet regulations 25. Drilling fluid program schematic & equip list adequate 26. BOPEs, do they meet regulation 27. BOPE press rating appropriate; test to 3000/3500 psig. 28. Choke manifold complies w/ API RP-53 (May 84) 29. Work will occur without operation shutdown. 30. Is presence ofH2S gas probable. APPR DATE 1f"tf\ '1.()Ó~ ) GEOLOGY 31. Permit can be issued wlo hydrogen sulfide measures. 32. Data presented on potential overpressure zones 33. Seismic analysis of shallow gas zones. 34. Seabed condition survey (if off-shore) 35. Contact namelphone for weekly progress reports {exploratory only] APPR DATE SFD 6/21/02 GEOLOGY: ENGINERING: COMMISSION: TEM:~OT: RPC: SF~ WGA: DTS: I'^- c.-fI) IO/1(Ø z- PROGRAM: Exploritory (EXP) ~ Development (DEV) GEOL AREA 820 UNIT No. Yes No Yes. No No Yes Yes Yes No Yes No Yes No Yes Yes Yes Yes No Yes Yes Yes No Yes Yes No Yes Yes Yes Yes No Yes No No No No Redril_ Service (SER) Well bore seg 051432 ON/OFF SHORE On Annular disposal para req F.e...~ I~ J1& /o·'Ý~ov *8-22-02: Marathon requests well be renamed "Abalone I" instead of "NNA # I" (to avoid confusion with Unocal's Deep Creek NNA # 1). SPACING EXCEPTION REQUIRED: well lies on Fee acreage within 1500' of several property lines (CIRI, State, and Univ. AK First well in Section 32, T2N, R12W. Nearest well is 4300 feet ENE. W ell lies within 1500' of several property lines SPACING EXCEPTION REQUIRED 6-26-02: C.Underwood: Application in progress. 9-20-2002: Nina Brudie: Project deemed consistent on 9/17/2002, SFD 6/26102: Requested justification from S. Lambe. 8-12-02: Received justification. Surface casing set at 2200' MD (2069' TVD) and cemented to surface meets the intent of20 MC 25.030 (c)(3) to protect strata that are known or potential sources of drinking water. SFD Existing Marathon rig.. .no reserve pit planned NA--new well No conflicts identified. Nearest well approximately 4000' distant. Mud program is not exotic, but little information is provided. . . placed call to Steve Lambe MASP estimated at 3322 psi. 3000 psi on surface casing 3500 psi minimun on 9-5/8" H2S is not anticipated Normal pressure gradient expected Not applicable; delineation well Not applicable; onshore well S. Lambe, 907-564-6332 Comments/Instructions APPROVAL LETTER: Use standard text in approval letter stating that the well may not be perforated or produced until a spacing exception has been approved. ) ) Well History File APPENDIX Infornlation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. . To inlprove the readability of the Well History file and to sinlplify finding infomlation, information of this nature is accunlulated at the end of the file under APPENDIX, No special effort has been made to chronologically organize this category of information. c1) C Ç) I ~.} O¡ U )0--/0 I ) MARA THON OIL COMPANY ABALONE #1 EXPLORA TION - COOK INLET Section 29- T2S-R12W, SM ) Kenai Peninsula, Alaska February 28, 2003 Ralph Winkelman - Sr. Logging Geologist Craig Silva - Sr. Logging Geologist John Lundy - Logging Geologist Kent Dickens - Logging Geologist Peter Dykema - Logging Geologist ) U EPO(~H (!!)Marathon Oil Company - Abalone #1 ) TABLE OF CONTENTS Marathon Oil Company Abalone #1 Exploration - Cook Inlet Kenai Borough, Alaska TABLE OF CONTENTS ............................................................................... 2 ) WELL RESU ME....... ..................................................................................... 3 DRILLI NG SUMMARY ................................................................................. 4 LITHOLOGY SUMMARy....... ...... .... ........ ............... ..................................... 6 DAILY CH RONOLOGY ........ .... ~ .................... ............. ......................... ....... 30 RIG ACTiViTy..... ................. ..... ..... .............. .............. ............ ............... ..... 35 MU D RECORD ........................................................................................... 38 SU RVEY RECORD..................................................................................... 40 BIT RECORD...................................................... ........................................ 45 DAI L Y REPORTS................................................ ....................................... 46 F=INAL. L.<:)C;S .............................................................................................. 4~ ), [::I EPO(~H 2 ~)Marathon Oil Company - Abalone #1 ) WELL RESUME WELL NAME: ABALONE #1 FIELD: EXPLORATION REGION: LOCATION: CLAM GULCH, KENAI PENINSULA, ALASKA 126' FSL,2886'FEl SEC 29 - T 2 N - R 12 W SM BOROUGH: KENAI PENINSULA BOROUGH STATE: ALASKA ELEVATION: RKB: 303' AMSL - Gl: 282' AMSL API NUMBER: #50 - 133 - 20517 - 00 OPERATOR: MARATHON Oil COMPANY ROWLAND LAWSON, GENE ANDERSON STEVE lAMBE Operator Representatives: ) Company Geologist: DAVID BRIMBERRY CONTRACTOR: INLET DRILLING MUDLOGGING COMPANY: Logging Geologists: GLACIER DRILLING #1 GEORGE BREWSTER, MIKE LESLIE EPOCH WELL SERVICES, INC. CRAIG SILVA, RALPH WINKELMAN, PETE DYKEMA DRILLING RIG: Toolpushers: MUD COMPANY: Mud Engineers: MWD COMPANY: MWD Engineers: M -I FLOYD FAULKNER, BOB WILLIAMS BAKER HUGHES INTEQ STEVE STURGEON SPERRY SUN DIRECTIONAL COMPANY: Directional Driller: BAKER HUGHES INTEQ THOMAS WRIGHT BJ SERVICES SCHLUMBERGER DEAN RATCLIFF CEMENT COMPANY: WIRELINE COMPANY: Logging Engineers: } ~ EPO(~H 3 @ . \;;;) Marathon 011 Company - Abalone #1 ) DRilliNG SUMMARY PROSPECTUS The objective of the Abalone #1 wildcat well is twofold. The first and foremost objective is to produce natural gas from several gas-bearing sands in the Tyonek Formation, and perhaps to gain production from the Sterling and/or Upper Beluga Formations as well. A secondary objective is to provide important correlation data between the Kenai gas field, and other gas production further to the south, According to plan, this well will be drilled more or less vertically, departing only 839'(±) south to a bottom hole location that is 10,166'(±) MD /10,OOO'(±) TVD. In the event that the well will produce from both the Tyonek and from upper sands of the Sterling or Upper Beluga, then the well will be completed as a dual producer, 3-1/2" with a 3-1/2" liner, If Sterling/Beluga gas is present, then the well will be completed as a 4-1/2" single and 4-1/2" liner. BRIEF REVIEW OF ACTIVITY The drilling rig was Marathon's Glacier Drilling Rig #1, 20" conductor pipe was set at 170'. The well was spudded on January 31,2003 at 11 :30pm. 17%" hole was drilled vertically to 462', and then drilled directionally to 1972', 13 3/8" casing was set at 2,208', 12 "X" hole was directionally drilled to 4,350', 9 %" casing was set at 4336'. 8 % " hole was drilled vertically to 4370'. 6 %" hole was directionally drilled to 10,356', A MAD (Measurement After Drilling) logging run was made with the Sperry-Sun MWD- LWD tools from 4255' to 10,356'. ) BRIEF DIRECTIONAL REVIEW The well was vertical to the kick off point at 500', at which depth 3.0 deg per 100' was maintained until a max inclination of 27.6 deg was reached at 1576', Inclination and azimuth of 188 deg was held to 1982', at which point angle was dropped at 2 deg per 100', At 3356' 1,0 deg was reached and maintained till 6617' when the inclination was allowed to build slowly on its own, which was a deviation from the original well plan, The final inclination and azimuth of 7.9 deg and 339,5 deg respectively was reached at TD of 10,356' MD, 10,202' TVD. LOGGING PROCEDURES Epoch Well Services provided RIGWA TCH 2000™ Drilling Monitoring services and DML TM Mudlogging Service. Constant mud gas was generated by an air motor driven gas trap located at a shaker header box, and then extracted continuously from the trap to the logging unit by sample pumps. Hydrogen flame ionization instruments, a Hydrocarbon Analyzer and a Chromatograph, were employed to detect and analyze the formation gases. The gas J ~ EPO(~H 4 (.@)Marathon Oil Company - Abalone #1 ) trap was cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated regularly, Cuttings samples were collected at regular 10' and 20' intervals as directed by Marathon's sampling program. ) .> [1 EP()(~H 5 (!!)Marathon Oil Company - Abalone #1 ( LITHOLOGY SUMMARY SAND (2210' - 2300') = MEDIUM TO DARK GRAY OVERALL WITH ABUNDANT VARICOLORED LITHS, LIGHT TRANSLUCENT GRAY, DARK GRAY, BLACK, WHITE, PALE TO DARK ROSE; DARK BLUISH GREEN, TRANSLUCENT TO CLEAR; VERY COARSE UPPER TO FINE LOWER, DOMINANTLY MEDIUM UPPER TO COARSE LOWER; OCCASIONALLY VERY COARSE BROKEN PEBBLES; DOMINANTLY ANGULAR TO SUBANGULAR; VERY POORLY SORTED; UNCONSOLIDATED; TRACE LIGHT GRAYISH WHITE ASHY TUFF; NOTE ABUNDANT SAFE CARBONACEOUS MUD ADDITIVE IN SAMPLES. ( TUFFACEOUS CLAYSTONE (2270' - 2350') = LIGHT GRAY TO LIGHT GRAYISH LIGHT BROWN; VERY SOFT; CLAYEY TO SILTY TEXTURE; DULL TO SLIGHTLY EARTHY LUSTRE; POOR ADHESIVENESS AND COHES,IVENESS; VERY SOLUBLE; NON TO SLIGHTLY CALCAREOUS; COMMON SUPPORTING MATRIX FOR UNCONSOLIDATED SAND; TRACE ASHY, LIGHT GRAY TUFF, SAND, CONGLOMERATE (2300' - 2410') = MEDIUM TO DARK GRAY OVERALL WITH MODERATE SALT AND PEPPER APPEARANCE, ABUNDANT VARICOLORED LlTHS THROUGHOUT, TRANSLUCENT WHITE TO CLEAR, LIGHT TO DARK GRAY, BLACK, LIGHT TO DARK REDDISH BROWN, LIGHT TO DARK BLUISH GREEN, PALE YELLOWISH GREEN; VERY COARSE LOWER WITH SCATTERED BROKEN PEBBLES TO VERY FINE UPPER, DOMINANTLY FINE UPPER TO MEDIUM UPPER; ANGULAR TO SUBANGULAR; UNCONSOLIDATED; POORLY SORTED; TRACE COAL. TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE (2400' - 2480') = LIGHT TO MEDIUM GRAY WITH LIGHT TO MEDIUM BROWN SECONDARY HUES; VERY SOFT; SLIGHT TO MODERATELY STICKY; SHAPELESS, GLOBULAR CUTTINGS; CLAYEY TO SILTY TEXTURE; DULL TO EARTHY LUSTRE; MODERATE TO VERY SOLUBLE; EXPANSIVE WHEN HYDRATED; POOR TO FAIR COHESIVENESS; FAIR TO GOOD ADHESIVENESS; NON CALCAREOUS. SANDSTONE (2430' - 2500') = MEDIUM TO DARK GRAY; FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; FRIABLE; MODERATE TO MODERATELY WELL CONSOLIDATED; FAIR TO MODERATE WELL SORTING; CLAYEY TO SILTY; NON CALCAREOUS CEMENT; TRACE LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY TUFF. ( SAND/SANDSTONE(2500'-2700') = MEDIUM LIGHT GRAY TO MEDIUM GRAY; GENERALLY WITH FAINT LIGHT OLIVE GRAY TO OLIVE GRAY SECONDARY HUES; OCCASIONALLY ALSO LIGHT BROWNISH GRAY SECONDARY HUES; FINE LOWER TO COARSE UPPER, AND SPOTTY VERY COARSE GRAINS; CONSISTENT <5% FRACTION OF VERY FINE GRAINS THAT APPEAR TO BE SHARDS WINNOWED OUT OF THE VOLCANIC ASH; MODERATE TO ~ EP()(~H 6 ( (.4!!')Marathon Oil Company - Abalone #1 OCCASIONALLY MODERATELY WELL SORTED IN FINE UPPER TO MEDIUM UPPER RANGE, BUT LOCALLY CAN BE SURPRISINGLY POORLY SORTED; MOSTLY SUBANGULAR TO SUBROUNDED, SUBDISCOIDAL TO SUBSPHERICAL, BUT ALTERNATES WITH ZONES OF ABUNDANT SHARPER ANGULAR DISCOIDAL GRAINS; GENERALLY DISAGGREGATED, BUT SPOTTY BLEBS OF TUFFACEOUS CLAY MATRX SUPPORTED SANDSTONE, AND TRACE PIECES CALCAREOUS CEMENTED GRAIN SUPPORTED SANDSTONE; CLAYEY COMPOSITIONAL GRAYWACKE(>30% lithics) TO LITHIC ARENITE; ESTIMATE 45-65°k QUARTZ (AND 'CLEAR VOLCANIC GLASS), 10-25% CHALCEDONYI CHERTI OTHER CRYPTOSILICA, TRACE-5°k FELSPAR, 20-40ok LITHICS AND MAFIC MINERALS; NOTE DIVERSE GROUP OF LITHICS DOMINATED BY GREENISH GRAY, GRAY, LIGHT GREEN GREENSTONE ROCK FRAGMENTS; DISTINCTIVE TRACES OF RED VOLCANIC ROCK FRAGMENTS, AND YELLOWISH GREEN EPIDOTE; MANY META- IGNEOUS ROCK FRAGMENTS ARE LIGHT BLUISH GRAY; COMMON FLAKES OF COLORLESS (MUSCIVITE) MICA; LOCALLY VERY COMMON SAND SIZE FRAGMENTS OF CLASTIC LITHIC COAL; COMMON MEDIUM DARK GRAY MEDIUM TO HI GRADE META ARGILLITE-PHYLLITE ROCK FRAGMENTS, TUFFACEOUS CLAYSTONE/ARGILLACEOUS CLAYSTONE (2480'-27501) = MEDIUM LIGHT GRAY TO MEDIUM GRAY; SOME RANGES TO DARK GRAY; SOFT TO SLIGHTLY FIRM OR SLIGHTLY BRITTLE; MOST HAS SIGNIFICANT VISIBLE GLASS SHARDS AND "ASHIER" TEXTURE, BUT ABUNDANTLY GRADES TO CLAYSTONE WITH FEW GLASS SHARDS AND A MORE HOMOGENEOUS "CLAYIER" TEXT; ALSO COM CLAYSTONE WITH A MIX OF TEXTURES; LOCALLY THE CLAYSTONE IS GRADATIONAL TO CLAYEY TUFFACEOUS SILTSTONE; MASSIVE AND STUCTURELESS; OFTEN HAS DISPLAYED A FAINT SHALINESS, AND LOCALLY HAS IMPERFECT BUT STILL DISCERNIBLE SHALE DEVELOPEMENT; SOME CLAYSTONE PIECES HAVE A ROUGH PLANAR SEPARATION; ASHY TO CLAYEY TO SILTY TO VARIOUS MATTE TEXTURES; EARTHY TO MICROSPARKL Y TO SLIGHTLY "SOFT GLASSY" LUSTRES; SPOTTY ORGANIC-LOOKING CLAYSTONE WITH CARBONACEOUS LAMS GRAD TO CARBONACEOUS SHALE; IS SUPPORTING MATRIX FOR CLOSELY ASSOCIATED CLAYEY SANDSTONE. TUFFACEOUS SHALE / ARGILLACEOUS SHALE (2660'-2800') = MEDIUM LIGHT GRAY TO MEDIUM GRAY; OCCASIONALLY DARKER GRAYS; SLIGHT TO MODERATELY BRITTLE TO SLIGHTLY TO MODERATELY FIRM; ESSENTIALLY SAME CHARACTERISTICS AS THE TUFFACEOUS AND ARGILLACEOUS CLAYSTONE DESCRIBED ABOVE, BUT DISPLAYS EASILY DISCERNIBLE SHALE STRUCTURE; SPOTTY PARTS GRADATIONAL TO CARBONACEOUS SHALE, SAND/SANDSTONE (2700'-2930') = MEDIUM GRAY TO MEDIUM DARK GRAY; OCCASIONAL FAINT OLIVE SECONDARY HUES; NOTE SUBTLE CHANGE IN LIGHTNESS VALUES TO OVERALL DARKER GRAY COLOR AFTER 2700'; DARKER GRAY COLORS PRODUCED BY INCREASED FRACTION OF DARK GRAY TO ( BLACK METALITHIC GRAINS AND MAFIC MINERALS; VERY FINE UPPER TO ( (:I EPO(:H 7 (~. ( ( (!!)Marathon Oil Company - Abalone #1 VERY COARSE LOWER; MOST IS MODERATELY WELL SORTED IN FINE UPPER TO MEDIUM LOWER RANGE; FINING UPWARD IS NOT DISCERNIBLE, APPARENT MASSIVE SAND SECTIONS; VERY FINE SAND IS MIX OF GLASS SHARDS WINNOWED OUT VOLCANIC ASH, AND VERY FINE "MILKIER" AND WHITER QUARTZ GRAINS; LOCALLY LITHICS WILL ALSO RANGE INTO VERY FINE; 10- 20% OF THE SAND IS POORLY SORTED, AND COULD BE A RESULT OF THIN INTERBEDS OF COARSER SAND, OR EVEN A SECOND MODE OF COARSE SAND; DOMINANTLY SUBANGULAR TO SUBROUNDED, SUBDISCOIDAL TO SUBSPHERICAL; ABUNDANT CONSOLIDATED SANDSTONE PIECES ARE DOMINANTLY MATRIX SUPPORTED BY THE MIX OF CLAYS PRESENT, AND LOCALLY GRAIN SUPPORTED WITH INTERSTITIAL CLAYS; COMPOSITIONAL GRAYWACKE; ESTIMATE 30-40ok LITHICS AND MAFIC MINERALS; DARKER GRAY GRAINS FROM MEDIUM HI GRADE META ARGILLITE-PHYLLITE ROCK FRAGMENTS LESS ABUNDANT THAN LOW GRADE META GREENSTONE ROCK FRAGMENTS; DISTINCTIVE TRACE OF RED LITHIC VOLCANIC FRAGMENTS, COLORLESS MICA, AND RARE YELLOWISH GREEN EPIDOTE. SAND/SANDSTONE (2930'-3100') = MEDIUM GRAY TO MEDIUM DARK GRAY; OCCASIONALLY LOCAL OLIVE GRAY SECONDARY HUES; VERY FINE UPPER TO VERY COARSE LOWER; MODERATELY WELL SORTED IN FINE LOWER TO MEDIUM LOWER RANGE; LOCAL SORTING IS POOR WITH INCREASED COARSE; DOMINANTLY SUBANGULAR - SUBROUNDED, AND SUBDISCOIDAL - SUBSPHERICAL; DISAGGREGATED TO CONSOLIDATED WITH TUFFACEOUS CLAY MATRIX SUPPORT; NON CALCAREOUS; NOTE SAMPLES HAVE HIGH CONCENTRATION OF SAFE CARB MUD ADDITIVE (CRUSHED MARBLE) AFFECTING FINE GRAIN SAND PERCENTAGE AND ACID EFFERVESCENCE. SAND (3050' - 3086') = LIGHT TO MEDIUM GRAY WITH LIGHT GRAY TO TRANSLUCENT GRAY, WHITE AND CLEAR LITHS DOMINANT, TRACE DARK BLUISH GREEN AND LIGHT TO DARK REDDISH BROWN VOLCANIC LITHS, TRACE BLACK; VERY FINE UPPER TO MEDIUM LOWER, TRACE COARSE LOWER, DOMINANTLY FINE LOWER TO FINE UPPER; ANGULAR TO SUBROUNDED, DOMINANTLY SUBANGULAR; FAIR TO MODERATELY WELL SORTED; SUBDISCOIDAL TO SUBSPHERICAL DOMINANTLY UNCONSOLIDATED TO DISAGGREGATED; TRACE WELL CEMENTED SANDSTONE AND COMMON VERY LOOSELY SUPPORTED SAND WITH VERY LIGHT GRAY TO WHITISH GRAY ASHY TO CLAYEY SUPPORTING MATRIX; NON CALCAREOUS TRACE VERY THIN COAL STRINGERS. TUFFACEOUS CLAYSTONE (3090' - 3220') = VERY LIGHT GRAY WITH VERY LIGHT BROWN SECONDARY HUES WITH EQUAL AMOUNTS VERY LIGHT BROWN WITH LIGHT GRAY SECONDARY HUES; AMORPHOUS, GLOBULAR, SHAPELESS CUTTINGS; VERY SOFT; VERY STICKY; PLIABLE; SIL TV TO CLAYEY TEXTURE; EARTHY DULL TO SLIGHTLY GREASY LUSTRE; POOR TO FAIR COHESIVENESS; FAIR TO GOOD ADHESIVENESS; NON CALCAREOUS; COMMON SUPPORTING [:I EPO<=H 8 @ . ~Marathon 011 Company - Abalone #1 ( MATRIX FOR LOOSE SAND; TRACE TO COMMON LIGHT GRAYISH WHITE ASHYI SILTY TUFF; TRACE BLACK CLASTIC COAL LITHS. SANDI SANDSTONE (3200' - 3300') = LIGHT TO MEDIUM GRAY WITH VERY LIGHT BROWN SECONDARY HUES WITH MODERATE SALT AND PEPPER APPEARANCE OVERALL, INDIVIDUAL GRAINS DOMINANTLY LIGHT GRAY TO TRANSLUCENT CLEAR, TRACE DARK GRAY AND DARK GREENISH GRAY, TRACE REDDISH BROWN AND YELLOWISH GREEN VOLCANIC ROCK FRAGMENTS; TRACE TO COMMON YELLOWISH DARK BROWN MICA FRAGMENTS; VERY FINE UPPER TO TRACE VERY COARSE BROKEN PEBBLE FRAGMENTS, DOMINANTLY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; SUBDISCOIDAL TO SUBSPHERICAL; DOMINANTLY DISAGGREGATED WITH SCATTERED CLAY SUPPORTED, FRAGILE SANDSTONE; TRACE VERY THIN COAL STRINGER OR CLASTIC LlTHS. SANDI SANDSTONE (3290' - 3350') = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN SECONDARY HUES; DOMINANTLY SAME CHARACTERISTICS AS DESCRIBED ABOVE WITH TRACE SANDSTONE; VERY LIGHT GRAY TO MEDIUM GRAY; VERY FINE UPPER TO FINE LOWER; SUBANGULAR TO SUBROUNDED; MODERATELY WELL SORTED; MODERATELY HARD TO HARD; VERY WELL CONSOLIDATED WITH WHITE VERY CALCAREOUS CEMENT; CEMENT SOMEWHAT ASHY AND SIL TV. ( SAND/SANDSTONE/CONGLOMERITIC SAND (3350'-3500') = MEDIUM GRAY TO MEDIUM DARK GRAY TO LOCALLY DARK GRAY; OFTEN APPEARS GRAY WITH THIN SCATTERED MIX OF WHITE AND OTHER COLORS WHEN COARSER; VERY FINE UPPER TO RARE GRANULE; MOSTLY FINE LOWER TO MEDIUM UPPER, BUT LOCAL YL INCREASES IN COARSE AND LARGER FRACTION FROM 5% TO AS HIGH AS 40%; MOSTLY MODERATE TO OCCASIONALLY MODERATE WELL SORTED, BUT SOME (THIN?) ZONES ARE POORLY SORTED; DOMINANTLY SUBANGULAR TO SUBROUNDED, SUBDISCOIDAL TO SUBSPHERICAL BUT SIGNFICANTL Y MORE ANGULAR OVERALL WHEN % OF LITHICS INCREASES; DOMINANTLY DISAGGREGATED; MINOR CONSOLIDATED CLAY MATRIX SUPPORTED SANDSTONE THAT OCCASIONALLY "CLEANS UP" AND BECOMES GRAIN SUPPORTED; ABUNDANT SUPPORTING MATRIX IS VOLCANIC ASH DERIVED, TRACE OF WEAK CALCAREOUS-SILICEOUS CEMENTED SANDSTONE; COMPOSITIONAL GRAYWACKE (>40% lithics) TO LITHIC ARENITE; ESTIMATE 40- 70% QUARTZ AND GLASS, TRACE - 5% FELDSPAR, 5-15% CRYPTOSILICA (CHERT, CHALCEDONY, JASPER), 25-50°/Ó LITHICS AND MAFIC MINERALS; 80% OF QUARTZ IS COLORLESS - PALE GRAY - PALE BLUISH GRAY - PALE GREEN AND TRANSLUCENT, 20°/Ó COLORLESS TRANSPARENT; ABUNDANT GREENISH GRAY - GREEN TRANSLUCENT GRAINS ARE PART OF GREENSTONE LITHICS; DARK GRAY SAMPLES HAVE ABUNDANT DARK GRAY -GRAYISH BLACK LITHICS FROM MEDIUM - HIGH GRADE ARGILLITE - PHYLLITE SOURCE ROCKS, ( U EP()(~H 9 (". ( ( {!!)Marathon Oil Company - Abalone #1 VOLCANIC ASH DERIVED SEDIMENTS (3220'- 3700') = MOSTLY TUFFACEOUS CLAY, BUT INCLUDES SIGNIFICANT SHARD-RICH VOLCANIC ASH WITH MARGINAL REWORKING, TUFFACEOUS SILTSTONE, AND TUFFACEOUS SHALE; EACH OF THESE LITHS ARE GRADATIONAL TO EACH OTHER, AND HAVE PROMINENT ASHY OR MATTE TEXTURES IN COMMON; MANY VARIATIONS OF LIGHT GRAY TO MEDIUM GRAY COLORS, WITH LIGHT GRAYISH BROWN OR PALE BROWN SECONDARY HUES; ALSO AFTER 3200' THE DENSEST 'LOOKING CLAYSTONEI SHALE OFTEN HAS A LIGHT TO MEDIUM BLUISH GRAY SECONDARY HUE; SOFT TO SLIGHTLY FIRM TO SLIGHTLY BRITTLE; SOFTEST CLAY HAS MUSHY TO PASTEY TO SLIGHTLY GUMMY CONSISTENCY; MODERATELY HYDROPHILIC, NOTE THAT THE FIRMER CLAYSTONE - SILTSTONE DOES NOT APPEAR EXPANSIVE WHEN HYDRATED; MASSIVE TO SHAL Y; OCCASIONALLY WITH THIN CARBONACEOUS LAMINATIONS; SHAL Y PIECES HAVE IMPERFECT PLANAR SEPARATION; ASHY TO CLAYEY TO MATTE TEXTURES; "SOFT GLASSY" TO EARTHY TO MICROSPARKL Y LUSTRE; ASHIEST AND LEAST REWORKED ASH HAS ABUNDANT VISIBLE GLASS SHARDS; DEVITRIFICATION IS SPOTTY, MOST ASH IS REMIXED WITH SILT AND CLAY; ALSO NOTE THAT A LARGE OVERALL FRACTION OF THE TUFFACEOUS CLAYS ARE CLOSELY GRADATIONAL TO ARGILLACEOUS CLAY, BUT SHARDS ARE CONSISTENTLY PRESENT AND DRY TEXTURE IS NEARLY ALWAYS MICROSPARKL y, SAND ISANDSTONE (3650' - 3740') = LIGHT TO MEDIUM GRAY WITH A STRONG SALT AND PEPPER OVERALL APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY LIGHT GRAY TO TRANSLUCENT TO CLEAR, WHITE, LIGHT GREENISH GRAY WITH LESSER AMOUNTS OF BLACK AND DARK GRAY; VERY FINE UPPER TO RARE COARSE LOWER, DOMINANTLY FINE LOWER TO FINE UPPER; SUBANGULAR TO SUBROUNDED; DOMINANTLY DISAGGREGATED WITH TRACE FINE GRAIN, VERY CALCAREOUSLY CEMENTED SANDSTONE, VERY HARD; FAIR TO MODERATELY WELL SORTED IN FINE RANGE, POORLY SORTED IN UPPER MEDIUM TO COARSE RANGE; TRACE VERY COARSE TO PEBBLE FRAGMENTS; TRACE VERY THIN COAL STRINGERS; COMMON TO ABUNDANT LIGHT TO MEDIUM GRAY CLAYEY SUPPORTING MATRIX FOR VERY LOOSELY SUPPORTED SAND; TRACE LIGHT GRAY TO GRAYISH WHITE ASHY TUFF. TUFFACEOUS CLAYSTONE (3750' - 3860') = LIGHT TO MEDIUM GRAY WITH BLUISH GRAY SECONDARY HUES AND TRACE LIGHT TO MEDIUM BROWN SECONDARY HUES; DOMINANTLY SHAPELESS, GLOBULAR CUTTINGS, FIRMER PIECES ARE WEDGE SHAPED; VERY SOFT TO OCCASIONALLY SLIGHTLY FIRM; VERY STICKY; CLAYEY TO SILTY TEXTURE; GREASY TO SLIGHTLY EARTHY LUSTRE; FAIR TO GOOD ADHESIVENESS POOR TO FAIR COHESIVENESS; MODERATELY EXPANSIVE WHEN HYDRATED; HYDROPHILIC IN PART; MODERATELY SOLUBLE; NON CALCAREOUS TRACE THIN COAL STRINGERS, SAND (3840' - 3900') = MEDIUM TO DARK GRAY OVERALL WITH INDIVIDUAL GRAINS DOMINANTLY DARK GRAY TO BLACK, LIGHT GRAY TO TRANSLUCENT [j EP()C:H 10 ( ( (!!)Marathon Oil Company - Abalone #1 GRAY, WHITE; VERY FINE UPPER TO VERY COARSE LOWER, DOMINANTLY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBROUNDED, DOMINANTLY SUBANGULAR; POOR TO FAIR SORTING; DISAGGREGATED; TRACE YELLOWISH DARK BROWN MICA; NOTE SAND VERY FINE AND LIGHT GRAY AT 3900'. TUFFACEOUS CLAYSTONE (3900' - 3970') = LIGHT GRAY WITH VERY LIGHT BLUE SECONDARY HUES AND TRACE VERY LIGHT BROWN SECONDARY HUES; VERY SOFT; SHAPELESS, AMORPHOUS CUTTINGS; MUSHY TO SLIMY; MODERATE TO VERY STICKY; GREASY LUSTRE; SMOOTH TO CLAYEY TEXTURE; POOR COHESIVENESS; POOR TO FAIR ADHESIVENESS; HYDROPHILIC; EXPANSIVE WHEN HYDRATED; MODERATELY SOLUBLE; NON TO SLIGHTLY CALCAREOUS; ABUNDANT SAFE CARB MUD ADDITIVE (CRUSHED MARBLE). SAND (3950' - 4040') = MEDIUM GRAY OVERALL WITH STRONG SALT AND PEPPER APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY LIGHT GRAY TO LIGHT GREENISH GRAY, TRANSLUCENT TO CLEAR, WITH LESSER AMOUNTS OF DARK GRAY TO BLACK AND TRACE WHITE; VERY FINE UPPER TO VERY COARSE LOWER, DOMINANTLY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED IN FINE RANGE; POORLY SORTED IN COARSER RANGE; DISAGGREGATED; ABUNDANT CLAYEY SUPPORTED SANDY GLOBULES; DOMINANTLY A CLAYEY FORMATION WITH INTERBEDDED SANDS. TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE (4000' - 4080') = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN SECONDARY HUES; VERY SOFT; SLIGHT TO MODERATE TO VERY STICKY; SHAPELESS, GLOBULAR CUTTINGS; CLAYEY TO SIL TV TEXTURE; DULL TO EARTHY LUSTRE; MODERATE TO VERY SOLUBLE; EXPANSIVE WHEN HYDRATED; POOR TO FAIR COHESIVENESS; FAIR TO GOOD ADHESIVENESS, SAND I SANDSTONE (4080' - 4150') = MEDIUM GRAY WITH STRONG SALT AND PEPPER APPEARANCE WITH INDIVIDUAL GRAINS DOMINANTLY CLEAR TO LIGHT TRANSLUCENT GRAY WITH MEDIUM TO DARK GRAY, DARK GREENISH GRAY, BLACK, SCATTERED WHITE GRAINS; VERY FINE LOWER TO RARE VERY COARSE UPPER WITH INCREASE IN DEPTH, DOMINANTLY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBROUNDED, DOMINANTLY SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED WITH OCCASIONAL WELL CEMENTED SANDSTONE; LIGHT TO DARK GRAY WITH SALT AND PEPPER APPEARANCE; HARD; FINE TO MEDIUM; ANGULAR TO SUBANGULAR; VERY CALCAREOUS. VOLCANIC ASH DERIVED SEDIMENTS (4080'- 4250') = DOMINATED BY TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE; GENERALLY SAME CHARACTERISTICS AS DESCRIBED AT 4040'; NOTE PATCHY ZONES OF ( LIGHTER COLORED VOLCANIC ASH WITH MORE ABUNDANT GLASS SHARDS ~ EPO(~H 11 @ . ~Marathon 011 Company - Abalone #1 ( AND VISIBLY LESS REWORKNG; SOME CLAYSTONES HAVE MARGINALLY DEVELOPED SHALE STRUCTURE; RARE TO LOCALLY SPOTTY CALCAREOUS TUFF WITH DISTINCTIVE DARK YELLOWISH ORANGE TO PALE YELLOWISH BROWN COLOR AND MOSTLY BRITTLE AND TOUGH; TRACE OF SHAL Y YELLOWISH GRAY DEVITRIFIED ASH (IN SMECTITE-BENTONITE) GROUP; ABUNDANT TUFFACEOUS CLAYSTONE/SIL TSTONE IS CALCAREOUS, SPOTTY BRITTLE PIECES ARE VERY CALCAREOUS. ( SAND/SANDSTONE (4150'-4350') = MEDIUM LIGHT GRAY TO MEDIUM GRAY; OCCASIONAL TO MEDIUM DARK GRAY; VERY FINE LOWER TO RARE VERY COARSE UPPER, MOSTLY VERY FINE UPPER TO MEDIUM UPPER; MODERATE TO MODERATELY WELL SORTED IN FINE LOWER TO FINE UPPER RANGE; LOCALLY POOR SORTING; LOCAL COMMON VERY FINE CLEAR GRAINS INCLUDES ABUNDANT WINNOWED GLASS SHARDS; APPROXIMATELY 50% ANGULAR, 50% SUBANGULAR - SUBROUNDED; POSSIBLY 2 MODES OF ROUNDEDNESS & SHAPE; MOSTLY DISAGGREGATED; COMMON TO ABUNDANT LUMPY PIECES OF CONSOLIDATED CLAY MTRX SUPPORTED SANDSTONE; SPOTTY TO COMMON PIECES OF BOTH GRAIN AND MATRIX SUPPORTED SANDSTONE WITH CALCAREOUS CEMENTING; COMMONLY GRADES TO VERY SANDY CLAYSTONE; CLAYEY COMPOSITIONAL GRAYWACKE (>30% lithics); ESTIMATE 45-75% QUARTZ + GLASS, TRACE-5% FELDSPAR, 5-15°/Ó VARIOUS CRYPTOSILlC (CHERT, CHALCDNY), 25-45°/Ó LITHICS + MAFIC MINERALS; LlTHICS DOMINATED BY DARK GRAY-GRAYISH BLACK ARGLL TE- PHYLL TE ROCK FRAGMENTS; COMMON FINE CLASTIC COAL. TUFFACEOUS CLAYSTONEITUFFACEOUS SILTSTONE (4350'-4450') = NOTE OVERALL SIGNIFICANT CHANGE IN HARDNESS, DOMINANTLY STILL SOFT TO SLIGHTLY BRITTLE, BUT UP TO 40% FRACTION IS FIRMER, BRITTLER AND TOUGHER TO BREAK WITH THE PROBE; MEDIUM LIGHT GRAY TO MEDIUM GRAY TO LIGHT BROWNISH GRAY TO SPOTTY BROWNISH GRAY; CLAYEY TO SILTY TO ASHY TO VARIOUS MATTE TEXTURES; EARTHY TO MICROSPARKL Y LUSTRE; "ASHIEST" CLAY-SILT HAS VISIBLE GLASS SHARDS; COMMON THIN CARBONACEOUS LAMINATIONS OR MICROTHIN LAYERS OF COAL; SOFTER CLAYSTONES APPEAR HYDROPHiliC, MODERATELY EXPANSIVE AND MODERATELY STICKY. SAND/SANDSTONE (4350'-4500') = GENERALLY SAME CHARACTERISTICS AS PREVIOUS DESCRIPTION, BUT NOTE ADDITION OF COMMON SIL TV SANDSTONE THAT OFTEN HAS UL TRAFINE CARBONACEOUS FRAGMENTS IN THE SUPPORTING MATRIX; APPEARS TRACE TO SPOTTY SECONDARY MODE OF VERY COARSE GRAINS WITH FINE LOWER TO MEDIUM LOWER DOMINANT; APPEARS SLIGHTLY INCREASED DIVERSITY OF LITHICS. TUFFACEOUS CLAYSTONE (4450'-4600') = MEDIUM LIGHT GRAY TO MEDIUM GRAY; OCCASIONALLY RANGING TO LIGHT GRAY OR MEDIUM DARK GRAY; t SOFT TO SLIGHTL YFIRM OR SLIGHTLY BRITTLE; BRITTLER CLAYSTONEI [:I EP()(~H 12 ( ( ( @ . ~Marathon 011 Company - Abalone #1 SILTSTONE AT 4400' ONLY A TRACE; ASHY TO CLAYEY TO MIXED CLAYEY- SILTY TO VARIOUS SOFT MATTE TEXTURES; EARTHY LUSTRE; DRY SAMPLE OFTEN APPEARS MICROSPARKL Y; MOST IS MODERATELY HYDROPHILIC AND SLIGHT TO MODERATELY EXPANSIVE WHEN HYDRATED; MODERATE ADHESIVENESS, POOR COHESIVENESS; ASHIEST FRACTIONS HAVE ABUNDANT VISIBLE GLASS SHARDS; ABUNDANT CLAYSTONE HAS MICROTHIN CARBONACEOUS LAMINATIONS AND/OR PARTICLES; SPOTTY BROWNISH TUFFACEOUS CARBONACEOUS CLAYSTONE/SHALE; COMMONLY HAS DISPERSED FINE SAND GRAINS, AND SANDIEST GRADES TO A CLAYEY SANDSTONE. TUFFACEOUS CLAYSTONE (4600'-4750') = MEDIUM LIGHT GRAY TO MEDIUM GRAY; RANGES LIGHT GRAY OR MEDIUM DARK GRAY; COMMON LIGHT BROWNISH GRAY SECONDARY HUES; SILTIER CARBONACEOUS CLAYSTONE OFTEN BROWNISH GRAY WITH PATCHY DARKER LIGHTNESS VALUES; GENERALLY FAIRLY HOMOGENEOUS IN OVERALL APPEARANCE; ALMOST ENTIRELY SOFT, ONLY SPOTTY SLIGHTLY FIRM OR SLIGHTLY BRITTLE PIECES; CLAYEY TO ASHY TO MIXED CLAYEY-SILTY TO VARIOUS SOFT MATTE TEXTURES; EARTHY LUSTRE; DRY SAMPLE DOMINANTLY APPEARS MICROSPARKL Y; MOSTLY MODERATELY HYDROPHILIC AND SLIGHTLY EXPANSIVE WHEN HYDRATED; MODERATE TO POOR COHESIVENESS AND ADHESIVENESS; SAMPLES CAN BE JETTED AWAY WITH OVERWASHING; ASHIEST CLAYSTONE HAS COMMON TO ABUNDANT VISIBLE GLASS SHARDS; COMMON CARBONACEOUS LAMINATIONS; TRACE PIECES HAVE MICROTHIN COAL LAYERS; DOMINANTLY MASSIVE AND STUCTURELESS, BUT SPOTTY, SLIGHTLY FIRM PIECES SHOW IMPERFECT SHALE STRUCTURE; SPOTTY CLAYSTONE HAS COMMON TO ABUNDANT EVENLY DISTRIBUTED SAND GRAINS, AND IN PART GRADES TO VERY CLAYEY SANDSTONE. COAUCARBONACEUS SHALE (4350'-4850') = BLACK TO BROWNISH BLACK TO VERY DUSKY BROWN; LOW GRADE LIGNITE INTERBEDDED WITH, AND PARTIALLY GRADING TO CARBONACEOUS SHALE; BRITTLE AND FRAGILE; CARBONACEOUS SHALE IS SLIGHTLY FIRM AND ALSO FRAGILE; SMOOTH TO DENSE MATTE TO DENSE WOODY TEXTURE; ABUNDANT DENSE EARTHY LUSTRE; SMOOTH COAL IS DULL TO RESINOUS; THIN IRREGULAR PLATY FRACTURE; LARGER COAL FRAGMENTS HAVE IRREGULAR BLOCKY HABIT; TRACE PIECES WITH ALTERNATING MICROLAMINATIONS OF BLACK COAL AND BROWN CARBONACEOUS SHALE; MANY CUTTINGS PIECES OF TUFFACEOUS CLAYSTONE HAVE THIN CARBONACEOUSI COAL LAMINATIONS. TUFFACEOUS SILTSTONE (4350'-4850') = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY; OCCASIONALLY PALE BROWN VARIATION, AND LOCALLY BROWNISH GRAY IF CARBONACEOUS IN PART; SOFT TO SLIGHTLY BRITTLE OR SLIGHTLY FIRM; SILTY TO MIXED SILTY-CLAYEY TO ASHY TO VARIOUS ROUGH MATTE TEXTURES; EARTHY LUSTRE; MICROSPARKL Y WHEN DRY; CLOSELY U EPOC:H 13 'M.)Marathon Oil Company - Abalone #1 ( GRADATIONAL TO TUFFACEOUS CLAYSTONE; SOME WITH COMMON VISIBLE GLASS SHARDS; OFTEN WITH THIN CARBONACEOUS LAMINATIONS. TUFFACEOUS CLAYSTONE (4900' - 5010') = VERY LIGHT TO LIGHT MEDIUM GRAY WITH VERY LIGHT BROWN SECONDARY HUES; VERY SOFT TO OCCASIONALLY SLIGHTLY FIRM AND BRITTLE; AMORPHOUS, GENERALLY SHAPELESS, GLOBULAR CUTTINGS; VERY STICKY AND TACKY GREASY TO EARTHY LUSTRE; SMOOTH TO CLAYEY TEXTURE; POOR COHESIVENESS; POOR TO FAIR ADHESIVENESS; SOLUBLE; EXPANSIVE WHEN HYDRATED; HYDROPHILIC; MODERATE TO VERY CALCAREOUS; TRACE MICROTHIN, BLACK, COALI CARBONACEOUS LAMINATIONS AND INCLUSIONS; TRACE VERY FINE, CLEAR SAND SUSPENDED IN CLAYI SILTSTONE; SILTSTONE OCCASIONALLY GRADING TO VERY FINE SANDSTONEI SANDY SIL TSTONE;SAMPLE CAN BE WASHED AWAY WITH OVER WASHING, SAND (4950' - 5040')= INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT, LIGHT GRAY WITH TRACE DARK GRAY, BLACK, AND WHITE GIVING SAMPLE A SLIGHT SALT AND PEPPER APPEARANCE; VERY FINE LOWER, GRADING TO COARSE SILT TO MEDIUM UPPER, DOMINANTLY FINE LOWER TO FINE UPPER; SUBANGULAR TO SUBROUNDED; MODERATELY WELL TO WELL SORTED; DISAGGREGATED; PRESENT AS FLOATING GRAINS IN DOMINANTLY CLAYSTONEI SILTSTONE FORMATION. ( TUFFACEOUS CLAYSTONE I TUFFACEOUS SILTSTONE (5030' - 5130') = LIGHT TO MEDIUM GRAY WITH LIGHT TO MEDIUM BROWN SECONDARY HUES; GENERALLY SHAPELESS, GLOBULAR CUTTINGS, FIRMER PIECES ARE WEDGE TO TABULAR AND GENARALL Y DARKER GRAY; VERY SOFT TO SLIGHTLY FIRM; SMOOTH CLAYEY TO SLIGHT GRITTY TEXTURE (FROM SUSPENDED SANDS); EARTHY TO GREASY LUSTRE; POOR TO FAIR ADHESIVENESS AND COHESIVENESS; MODERATE TO VERY SOLUBLE; SLIGHTLY EXPANSIVE WHEN HYDRATED; HYDROPHILIC; SLIGHT TO MODERATELY CALCAREOUS; COMMON DARK BROWN TO BLACK CARBONACEOUS I COALY MICROTHIN LAMINATIONS AND INCLUSIONS IN FIRMER PIECES, COAU CARBONACEOUS SHALE (5120' - 5190') = 'BLACK WITH FAINT DARK, DUSKY BROWN SECONDARY HUES; PLATY TO BLOCKY WITH ABUNDANT FINELY GROUND UP FRAGMENTS FROM PDC BIT ACTION; FRAGILE TO BRITTLE, OCCASIONALLY FIRM; BETTER DEVELOPED COALS ARE SLIGHTLY HARD; SMOOTH TO MATTE TEXTURE; EARTHY TO RESINOUS LUSTRE; SLIGHT TRACE VISIBLE OUTGASSING BUBBLES FROM HARDER, LARGER PIECES; NO SAMPLE FLUORESCENCE. SAND (5150' - 5250')= INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT, LIGHT GRAY WITH TRACE DARK GRAY, BLACK, AND WHITE GIVING SAMPLE A SLIGHT SALT AND PEPPER APPEARANCE; VERY FINE ( LOWER TO TRACE VERY COARSE, DOMINANTLY FINE LOWER TO MEDIUM [:I EP()(~H 14 ( ( (.@)Marathon Oil Company - Abalone #1 LOWER; SUBANGULAR TO SUBROUNDED; MODERATELY WELL SORTED; DISAGGREGATED; COMMONLY PRESENT AS FLOATING GRAINS IN CLAY FORMATION; TRACE VERY THIN COAL BEDS. TUFFACEOUS CLAYSTONE (5220' - 5300') = LIGHT TO MEDIUM GRAY WITH LIGHT BROWNISH GRAY SECONDARY HUES; SOFT TO SLIGHTLY FIRM; ROUNDED WEDGE TO NODULAR CUTTINGS; PULVERULENT TO CRUMBLY; GREASY TO EARTHY LUSTRE; CLAYEY TO MATTE TEXTURE; MASSIVE; FAIR TO GOOD ADHESIVENESS AND COHESIVENESS; MODERATELY SOLUBLE; EXPANSIVE WHEN HYDRATED; COMMON MICROTHIN, BLACK CARBONACEOUS LAMINATIONS AND INCLUSIONS; NOTE CLAY GENERALLY HAS MORE CONSISTENCY AS OPPOSED TO SHAPELESS CLAY ABOVE. TUFFACEOUS CLAYSTONE I TUFFACEOUS SILTSTONE (5300' - 5380') = LIGHT TO MEDIUM GRAY WITH LIGHT TO MEDIUM BROWN SECONDARY HUES; GENERALLY SHAPELESS, GLOBULAR CUTTINGS, FIRMER PIECES ARE WEDGE TO TABULAR AND GENERALLY DARKER GRAY; VERY SOFT TO SLIGHTLY FIRM; SMOOTH CLAYEY TO SLIGHTLY GRllTY TEXTURE; DULL EARTHY TO GREASY LUSTRE; POOR COHESIVENESS; FAIR ADHESIVENESS; MODERATE TO VERY SOLUBLE; EXPANSIVE WHEN HYDRATED; TRACE TO COMMON BLACK MICROTHIN CARBONACEOUS LAMINATIONS. TUFFACEOUS CLAYSTONE (5380' - 5460') = LIGHT GRAY TO VERY LIGHT GRAY, OCCASIONALLY MEDIUM GRAY; MUSHY TO FIRM; DARKER PART IS FIRMER, SILTY IN PART; IRREGULAR TO EARTHY FRACTURE; MASSIVE SHAPELESS, OCCASIONALLY TABULAR CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TO SLIGHTLY GRITTY TEXTURE; MASSIVE BEDDING WITH RARE THIN COAU CARBONACEOUS SHALE PARTINGS; POOR COHESIVENESS; FAIR ADHESIVENESS; SAFE CARB MUD ADDITIVE CONTAMINATION. COAUCARBONACEOUS SHALE (5380' - 5460') = BLACK TO GRAYISH BLACK, OCCASIONALLY MEDIUM DARK GRAY; IRREGULAR TO HACKL Y FRACTURE WITH SOME CONCHOIDAL; PLATY, ELONGATED CUTTINGS; POORLY DEVELOPED CLEAT; DULL, EARTHY TO GREASY LUSTER; SMOOTH TO MATTE TEXTURE; PREDOMINANTLY OCCURINGAS VERY THIN STRINGERS WITHIN DOMINANT CLAY BEDS; RARE PREDOMINANT COAL BED AT 5463 - 5470; COAL COMMONLY GRADES TO SILTY MEDIUM TO DARK GRAY, FIRM TO MODERATELY HARD CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE (5460' - 5560') = VERY LIGHT TO LIGHT GRAY; CURDY CONSISTENCY; MODERATELY WATER SOLUBLE; CRUMBLY TO STIFF TENACITY; IRREGULAR TO EARTHY FRACTURE; MASSIVE GLOBULAR CUTTINGS; DULL TO WAXY LUSTER; SMOOTH CLAYEY TO OCCASIONALLY SILTY TEXTURE; MASSIVE CLAY BEDS WITH MINOR TUFFACEOUS SILTSTONE, SANDY UNITS AND CARBONACEOUS PARTINGS; CLAY/ASH IS SLIGHTLY ( CALCAREOUS IN PART. ~ EPO(~H 15 @ . ~Marathon 011 Company - Abalone #1 ( SANDSTONE (5545' - 5630') = VERY LIGHT TO LIGHT GRAY, OCCASIONALLY MILD SALT AND PEPPER APPEARANCE, WITH LIGHT BLUISH GRAY SECONDARY HUE; VERY FINE UPPER TO FINE LOWER GRAINS; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED; LOW TO MODERATE SPHERICITY; PREDOMINANTLY CLEAR TO MILKY WHITE QUARTZ GRAINS; GRAIN SUPPORTED; SOLUBLE ASHY/CLAY MATRIX MOSTLY WASHED OUT; COMMON BLACK ANGULAR CARBONACEOUS FRAGMENTS AND STRINGERS. ( TUFFACEOUS CLAYSTONE (5460' - 5720') = VERY LIGHT TO LIGHT GRAY WITH LIGHT BLUISH GRAY AND MEDIUM GRAY SECONDARY HUES; LUMPY TO CURDY CONSISTENCY; CRUMBLY TO STIFF TENACITY; IRREGULAR FRACTURE; MASSIVE TO NODULAR CUTTINGS; DULL TO WAXY LUSTER; SMOOTH CLAYEY, OCCASIONALLY SIL TV TEXTURE; MASSIVE BEDDING WITH OCCASIONAL THIN PARTINGS OF MEDIUM BROWN MODERATELY HARD SILTSTONE, AND FREQUENT BLACK COAL/ CARBONACEOUS FRAGMENTS AND THIN CARBONACEOUS STRINGERS CONTAINING TRACES OF PYRITE AND AMBER; OCCASIONALLY CONTAINS THIN BEDS OF VERY FINE TO FINE GRAINED ASHY SANDSTONE. COAU CARBONACEOUS SHALE (5700' - 5800')' = BLACK WITH FAINT DARK, DUSKY BROWN SECONDARY HUES; PLATY TO BLOCKY WITH ABUNDANT FINELY GROUND UP FRAGMENTS FROM PDC BIT ACTION; FRAGILE TO BRITTLE, OCCASIONALLY FIRM; BETTER DEVELOPED COALS ARE SLIGHTLY HARD; SMOOTH TO MATTE TEXTURE; EARTHY TO RESINOUS LUSTRE; PLANAR TO SLIGHTLY CONCHOIDAL FRACTURE IN HARD COAL PIECES; LESS DEVELOPED, SOFTER COAL AND CARBONACEOUS SHALES ARE FLAKY AND SCALY; DOMINANTLY PRESENT AS VERY THIN STRINGERS ANDMICROTHIN LAMINATIONS AND INCLUSIONS IN CLAY FORMATION. TUFFACEOUS CLAYSTONE I TUFFACEOUS SILTSTONE (5750' - 5900') = LIGHT TO MEDIUM GRAY WITH LIGHT TO MEDIUM BROWN SECONDARY HUES; GENERALLY SHAPELESS, GLOBULAR CUTTINGS, FIRMER PIECES ARE WEDGE TO TABULAR AND GENERALLY DARKER GRAY; VERY SOFT TO SLIGHTLY FIRM; SMOOTH CLAYEY TO SLIGHT GRITTY TEXTURE; DULL EARTHY TO GREASY LUSTRE; POOR COHESIVENESS; FAIR ADHESIVENESS; MODERATE TO VERY SOLUBLE; EXPANSIVE WHEN HYDRATED; SLIGHT TO MODERATELY CALCAREOUS; TRACE BLACK, MICROTHIN CARBONACEOUS LAMINATIONS. TUFFACEOUS SILTSTONE (5840' - 5930') = MEDIUM TO DARK GRAY; MODERATELY FIRM TO VERY FIRM; FRAGILE TO SPLINTERY; TABULAR TO ELONGATED CUTTINGS; SUCROSIC TO SLIGHTLY GRITTY TEXTURE; DULL EARTHY TO SLIGHTLY MICROSPARKL Y LUSTRE; OCCASIONALLY GRADING TO VERY FINE, SILTY SANDSTONE; NON CALCAREOUS; COMMON BLACK, MICROTHIN, COALY LAMINATIONS AND INCLUSIONS; NO SAMPLE ( FLUORESCENCE. U EPO(~H 16 (.M.}Marathon Oil Company - Abalone #1 ( SAND (5940' - 5990')= INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT, LIGHT GRAY WITH TRACE DARK GRAY, BLACK, AND WHITE GIVING SAMPLE A SLIGHT SALT AND PEPPER APPEARANCE; VERY FINE LOWER TO TRACE COARSE, DOMINANTLY FINE LOWER TO MEDIUM LOWER; SUBANGULAR TO SUBROUNDED; MODERATELY WELL SORTED; DISAGGREGATED; OVERALL VERY DIRTY SAMPLE WITH REDDISH BROWN "RUST" FLAKES, FROM WIPER TRIP?; VERY FRAGILE; LESS THAN 5°~ AT 5960'. TUFFACEOUS CLAYSTONE (5900' - 6100') = VERY LIGHT TO LIGHT GRAY WITH LIGHT BLUISH GRAY AND MEDIUM GRAY SECONDARY HUES; MUSHY TO CURDY CONSISTENCY; CRUMBLY TO STICKY TENACITY; IRREGULAR TO EARTHY FRACTURE; MASSIVE CUTTINGS, WITH TABULAR IN DARKER COMPONENT; DULL TO WAXY LUSTER; SMOOTH, CLAYEY OCCASIONALLY SIL TV TEXTURE; FINE GRAINED DISSEMINATED CARBONACEOUS FRAGMENTS CREATE A MODERATE SALT AND PEPPER APPEARANCE; MASSIVE BEDDING WITH OCCASIONAL THIN PARTINGS OF MEDIUM BROWN, MODERATELY HARD SILTSTONE, VERY FINE UPPER TO FINE LOWER ASHY MATRIX SUPPORTED SANDSTONE, AND FREQUENT BLACK COAL/CARBONACEOUS STRINGERS; NON TO SLIGHTLY CALCAREOUS. ( SANDTONE (5990'-6170') = MEDIUM LIGHT GRAY TO MEDIUM GRAY, OCCASIONALLY MEDIUM GRAY BROWN; VERY FINE LOWER TO VERY FINE UPPER, OCCASIONALLY FINE UPPER, TRACE MEDIUM GRAINS; MODERATE TO WELL SORTED, OCCASIONALLY POORLY SORTED; SUBANGULAR TO ROUNDED; MODERATE TO HIGH SPHERICITY; PREDOMINANT CLEAR TO MILKY QUARTZ GRAINS, OCCASIONALLY LIGHT TO MEDIUM GRAY, WITH RARE DARK META LITHICS; CLAY/ ASH MATRIX SUPPORTED; MOSTLY DISAGGREGATED DUE PRESUMABLY TO WASH OUT OF SOLUBLE CLAY/ ASH MATRIX; NON CALCAREOUS; CONTAINS ABUNDANT VERY FINE, ANGULAR, BLACK CARBONACEOUS FRAGMENTS; GRADES TO MORE COMMON SANDY CLAYSTONE. COAUCARBONACEOUS SHALE (6150-6180) = PREDOMINANTLY BLACK WITH DARK GRAY AND DARK GRAYISH BROWN SECONDARY HUES; CRUNCHY, BRITTLE TENACITY; IRREGULAR TO CONCHOIDAL FRACTURE; PREDOMINANTLY WEDGELlKE, ELONGATED CUTTINGS, MINOR ANGULAR FRAGMENTS AND CLEAT-DEFINED BLOCKY PARTICLES; RESINOUS TO EARTHY LUSTER; COAL IS SMOOTH TEXTURED; CARBONACEOUS SHALE IS MATTE TO SILTY TEXTURED; COAL FOUND AS PARTINGS, AS THIN BLACK STRINGERS, AND AS DISSEMINATED ANGULAR FRAGMENTS WITHIN THE ABUNDANT TUFFACEOUS CLAYSTONE. TUFFACEOUS SILTSTONE (6210' - 6350') = MEDIUM GRAY TO DARK GRAYISH BROWN, OCCASIONALLY DARK GRAY; PREDOMINANTLY SILT SIZED PARTICLES { WITH ABUNDANT CLAY/ASH COMPONENT; OCCASIONALLY GRADING TO SIL TV ~ EPO(~H 17 ~M)Marathon Oil Company - Abalone #1 ( VERY FINE GRAINED SILTY SANDSTONE; POORLY SORTED; MODERATELY FIRM TO MODERATELY HARD; BLOCKY TO PLANAR FRACTURE; TABULAR TO ELONGATED CUTTINGS; GRITTY, SILTY TEXTURE; DULL MATTE TO EARTHY LUSTER; PREDOMINANTLY NON CALCAREOUS, OCCASIONALLY MODERATELY CALCAREOUS; INCLUDES CARBONACEOUS MICROTHIN STRINGERS AND ANGULAR DISSEMINATED CARBONACEOUS FRAGMENTS; NO SAMPLE FLUORESCENCE. TUFFACEOUS CLAYSTONE (6220' - 6400') = VERY LIGHT GRAY TO LIGHT GRAY WITH MEDIUM GRAY AND LIGHT BLUISH GRAY SECONDARY HUES; CLUMPY TO PASTY CONSISTENCY; CRUMBLY TO STIFF TENACITY; FIRMER COMPONENT EXHIBITS IRREGULAR FRACTURE; CUTTINGS ARE MASSIVE, NODULAR; DULL, EARTHY LUSTER, WAXY LUSTER ON INCREASING ASH; SMOOTH CLAYEY TEXTURE, GRADING TO SIL TV TEXTURE; MASSIVE CLAY/ASH BEDDING, LOCALLY GRADING TO SILTY CLAYSTONE AND SANDY CLAYSTONE; NON CALCAREOUS; CONTAINS CONSISTENT CARBONACEOUS COMPONENT REPRESENTED BY BLACK CARBONACEOUS MICROTHIN STRINGERS AND DISSEMINATED ANGULAR CARBONACEOUS FRAGMENTS, ( SANDY CLAYSTONE (6400' - 6500') = LIGHT GRAY TO MEDIUM GRAY, OCCASIONALLY BROWNISH GRAY TO BROWNISH BLACK; MUSHY TO MODERATELY STIFF CONSISTENCY; CRUMBLY TO TOUGH TENACITY; SOFT PART IS EARTHY; FIRMER COMPONENT EXHIBITS IRREGULAR FRACTURE; CUTTINGS ARE MASSIVE TO NODULAR; DULL, EARTHY LUSTER; GRITTY ABRASIVE TEXTURE; MASSIVE BEDDING WITH LOCALIZED SANDY COMPONENT; SAND IS VERY FINE UPPER TO FINE LOWER; PREDOMINANTLY SUBANGULAR TO SUBROUNDED QUARTZ GRAINS. SANDSTONE (6430' - 6600') = LIGHT TO MEDIUM GRAY, INDIVIDUAL GRAINS PREDOMINANTLY MILKY WHITE TO TRANSLUCENT TO CLEAR, MINOR MEDIUM TO DARK GRAY GRAINS; VERY FINE UPPER TO FINE LOWER, TRACE MEDIUM; SUBANGULAR TO SUBROUNDED; ASSUMED SOLUBLE ASHY/CLAY MATRIX WASHED OUT LEAVING LOOSE SAND GRAINS; FAIR TO MODERATELY WELL SORTED; COMMON BLACK CARBONACEOUS FRAGMENTS, AND MICROTHIN STRINGERS; PREDOMINANTLY NON CALCAREOUS; GRADES TO TUFFACEOUS CLAYSTONE WITH INCREASE IN ASHY/CLAY COMPONENT. TUFFACEOUS CLAYSTONE (6520' - 6600') = VERY LIGHT TO LIGHT GRAY, OCCASIONALLY LIGHT BLUISH GRAY, MEDIUM GRAY; MUSHY TO CURDY CONSISTENCY; CRUMBLY, STICKY TENACITY; MASSIVE CUTTINGS, TABULAR IN DARKER COMPONENT; GREASY TO DULL EARTHY LUSTRE; CLAYEY TO SILTY, OCCASIONALLY SLIGHTLY GRITTY TEXTURE; POOR COHESIVENESS; POOR TO FAIR ADHESIVENESS; NON TO SLIGHTLY CALCAREOUS; COMMON BLACK, MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS; NO SAMPLE FLUORESCENCE. ( ~ EP()(~H 18 ( (.M.)Marathon Oil Company - Abalone #1 TUFFACEOUS SILTSTONE (6600' - 6680') = MEDIUM TO DARK GRAY; VERY FIRM TO SLIGHTLY HARD; TABULAR TO ELONGATED; SILTY TO GRITTY TEXTURE; EARTHY TO SPARKL Y LUSTRE; COMMONLY GRADING TO VERY FINE, SILTY SANDSTONE; NON CALCAREOUS. SAND ISANDSTONE (6670' - 6740') = LIGHT TO MEDIUM GRAY OVERALL WITH INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT LIGHT GRAY, TRACE DARK GRAY TO BLACK LlTHS; VERY FINE LOWER TO MEDIUM LOWER, DOMINANTLY VERY FINE UPPER TO FINE LOWER; SUBANGULAR TO SUBROUNDED; DOMINANTLY UNCONSOLIDATED TO VERY LOOSELY SUPPORTED IN VERY CLAYEY/ ASHY MATRIX; MODERATELY WELL SORTED; WITH SANDSTONE, MEDIUM TO DARK GRAY; GRADING TO COARSE SILTSTONE/ VERY SILTY SANDSTONE; NON CALCAREOUS; TRACE BLACK, MICROTHIN CARBONACEOUS/COAL LAMINATIONS AND VERY THIN STRINGERS; NO SAMPLE FLUORESCENCE. TUFFACEOUS CLAYSTONE (6740' - 6800') = LIGHT TO MEDIUM GRAY; VERY SOFT TO SLIGHTLY FIRM; STICKY; GLOBULAR, SHAPELESS TO ROUNDED WEDGE SHAPED CUTTINGS; SILTY TO CLAYEY TEXTURE; DULL EARTHY LUSTRE; POOR TO FAIR ADHESIVENESS AND COHESIVENESS; MODERATELY SOLUBLE; HYDROPHILIC; EXPANSIVE WHEN HYDRATED; SLIGHTLY CALCAREOUS. ( SAND I SANDSTONE (6790' - 6940') = NOTE SIGNIFICANT LITHOLOGY CHANGE IN THE 6800' SAMPLE; LIGHT TO DARK GRAY OVERALL WITH DISAGGREGATED SAND GENERALLY CLEAR TO TRANSLUCENT LIGHT GRAY, LIGHT GREENISH GRAY, DARK GRAY AND BLACK; SANDSTONE GENERALLY DARK GRAY WITH MODERATE SALT AND PEPPER APPEARANCE; VERY FINE UPPER TO RARE COARSE UPPER, DOMINANTLY FINE TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; SANDSTONE VERY FINE; MODERATELY HARD TO FRIABLE; NON CALCAREOUS; NOTE INCREASE IN VERY LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY TUFF, COMMONLY ACTS AS SUPPORTING MATRIX FOR VERY LOOSELY CEMENTED SANDSTONE; TRACE TO COMMON DARK DUSKY BROWN TO BLACK CARBONACEOUS MATERIAL/ COAL. COAL (6910' -7000') = BLACK WITH SCATTERED DARK GRAY AND DARK DUSKY BROWN SECONDARY HUES; WELL DEVELOPED; MODERATELY HARD; BRITTLE AT TIMES; DOMINANTLY PLANAR FRACTURE WITH COMMON CONCHOIDAL AND BIRDEYE FRACTURE; FLAKY, PLATY CUTTINGS DOMINANT; FINELY GROUND UP FROM PDC BIT ACTION; EARTHY TO RESINOUS LUSTRE; SMOOTH TO MATTE TEXTURE; LARGER FRAGMENTS HAVE TRACE VISIBLE OUTGASSING BUBBLES; COMMON LIGHT GRAYISH WHITE ASHY TUFF AND LIGHT YELLOWISH WAXY TUFF; NO SAMPLE FLUORESCENCE. ( fI EPC)CH 19 ( ( ( @ . ~Marathon 011 Company - Abalone #1 VOLCANIC ASH (6900'-7020') = LIGHT GRAY TO LIGHT GRAYISH WHITE WITH LIGHT BROWN SECONDARY HUES; VERY SOFT; PULVERULENT; SHAPELESS, GLOBULAR CUTTINGS; EARTHY TO SPARKLING LUSTRE; ABRASIVE TO GRITTY TEXTURE; ABUNDANT VISIBLE SHARDS; COMMONLY ACTS AS SUPPORTING MATRIX FOR SAND; COMMONLY GRADING TO VERY ASHY CLAY; MODERATE TO VERY CALCAREOUS; NO SAMPLE FLUORESCENCE. TUFFACEOUS CLAYSTONE (6800' - 7000') = VERY LIGHT TO LIGHT GRAY WITH MEDIUM GRAY AND LIGHT BLUISH GRAY SECONDARY HUES; PREDOMINANTLY CURDY, MUSHY WITH FIRM MEDIUM GRAY PORTION; CRUMBLY TO STIFF; VERY SOFT TO FIRM; IRREGULAR TO BLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; CLAYEY TO MICRO-CRYSTAL TEXTURE, OCCASIONALLY GRADING TO SILT; DULL TO WAXY LUSTER; POOR TO FAIR ADHESIVENESS, FAIR COHESIVENESS; VERY SOLUBLE; HYDROPHILIC. SANDSTONE/CONGLOMERITIC SAND (6940'-7170') = MEDIUM LIGHT GRAY TO MEDIUM DARK GRAY WITH BROWNISH GRAY AND DUSKY BROWN SECONDARY HUES; VERY FINE UPPER TO FINE UPPER WITH RARE MEDIUM TO COARSE CLEAR TO MILKY WHITE BIT FRACTURED GRAINS; MODERATELY WELL SORTED TO OCCASIONAL POOR SORTING; SUBANGULAR TO SUBROUNDED; DOMINANTLY DISAGGREGATED - ASSUMED WASHOUT OF MODERATELY SOLUBLE CLAY/ASH MATRIX; ASH/CLAY MATRIX SUPPORTED; MAJORITY IS GRAYWACKE WITH MINOR LITHIC ARENITE; COMPOSED OF PREDOMINANT QUARTZ¡ VOLCANIC GLASS WITH RARE FELDSPAR, CHERT, HORNBLENDE AND TRACE JASPER, GREENSTONE, LIMONITE; COMMON BLACK CARBONACEOUS MATERIAL PRESENT AS MICROTHIN STRINGERS AND ANGULAR DISSEMINATED FRAGMENTS; CLAY/ASH MATRIX IS PREDOMINANTLY NON TO SLIGHTLY CALCAREOUS, LOCALLY BECOMING MODERATE TO HIGHLY CALCAREOUS; RARE MEDIUM TO COARSE GRAINED QUARTZ AND CHERT BIT BROKEN, CLEAR TO TRANSLUCENT, TO MILKY WHITE AND MEDIUM GRAY TUFFACEOUS CLAYSTONE INCLUSIONS. COAL (7200-7260) = PREDOMINANTLY BLACK WITH DARK GRAY AND DARK GRAYISH BROWN SECONDARY HUES; CRUNCHY, BRITTLE TENACITY; PREDOMINANTLY BLOCKY (CLEAT DEFINED) AND CONCHOIDAL FRACTURE WITH TRACE BIRDEYE; WEDGELIKE, ELONGATED CUTTINGS HABIT; ALTERNATE BANDS VITREOUS LUSTER HIGHER RANK COAL AND EARTHY LUSTER LOWER RANK COAL; SMOOTH TO MATTE TEXTURED; MASSIVE BEDS WITH CURVING LAMINAR FEATURES; PREDOMINANT SUB-BITUMINOUS RANK; TRACE DARK YELLOWISH ORANGE TO LIGHT BROWN FLUORESCENT AMBER AND PYRITE CRYSTALS. TUFFACEOUS CLAYSTONE! TUFFACEOUS SILTSTONE (7270' -7360') = MEDIUM TO DARK GRAY; VERY FIRM TO MODERATELY HARD; MASSIVE TO UNEVEN FRACTURE; EARTHY TO WAXY LUSTRE; SMOOTH TO CLAYEY TEXTURE; NON [:I EPOC=H 20 ( ( ( (!!)Marathon Oil Company - Abalone #1 CALCAREOUS; OCCASIONALLY GRADING TO VERY DARK GRAY SILTY, VERY FINE SANDSTONE; NOTE ADDING NUT PLUG TO SYSTEM @ 7340'. SAND ¡SANDSTONE (7300' -7430') = LIGHT TO DARK GRAY OVERALL WITH VERY STRONG SALT AND PEPPER APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT LIGHT GRAY, MEDIUM TO DARK GRAY, DARK GREENISH GRAY, WITH LESSER AMOUNTS OF WHITE AND BLACK LITHS, TRACE LIGHT GREEN AND LIGHT YELLOWISH BROWN, SANDSTONE RANGES FROM LIGHT GRAY SALT AND PEPPER TO MEDIUM GRAY SALT AND PEPPER TO DARK GRAY TO ALMOST BLACK; VERY FINE UPPER TO RARE VERY COARSE LOWER, DOMINANTLY FINE LOWER TO MEDIUM LOWER; ANGULAR TO SUBROUNDED, DOMINANTLY SUBANGULAR; MODERATE TO WELL SORTED; OCCASIONALLY UNCONSOLIDATED WITH LIGHT GRAY ASHY SUPPORT; GENERALLY CONSOLIDATED SANDSTONE; MODERATELY HARD, OCCASIONALLY FRAGILE AND FRIABLE; DARKER SANDSTONES ARE NON CALCAREOUS; LIGHT GRAY SANDSTONE IS VERY CALCAREOUS WITH A WHITE CEMENT, FRAGILE TO FRIABLE; DARKER SANDSTONES ARE NON CALCAREOUS AND MODERATE TO VERY HARD AND WELL CONSOLIDATED; TRACE MICROTHIN BLACK COAL LAMINATIONS IN CLAYSTONE PIECES AND OCCASIONAL SANDSTONE FRAGMENTS. COAL (7455' -7510') = BLACK WITH TRACE VERY DARK, DUSKY BROWN SECONDARY HUES; MODERATE TO VERY HARD; BRITTLE AT TIMES; BLOCKY TO PLATY; DOMINANTLY PLANAR FRACTURE WITH COMMON CONCHOIDAL AND BIRD EYE FRACTURE; OCCASIONALLY EARTHY TO PREDOMINANTLY VITREOUS LUSTRE; SCATTERED GRITTY, EARTHY TO DOMINANTLY SMOOTH, GLASSY TEXTURE. TUFFACEOUS CLA YSTONEI TUFFACEOUS SILTSTONE (7510' - 7630') = LIGHT BOWNISH GRAY TO MEDIUM GRAY TO TRACE DARK GRAY; VERY SOFT TO FIRM TO MODERATELY HARD; RARE STICKY AT TIMES; RARE SHAPELESS, GLOBULAR CUTTINGS, DOMINANTLY WEDGE TO SUBBLOCKY AND MASSIVE; SILTY AND CLAYEY TO SLIGHTLY GRITTY TEXTURE; DULL EARTHY TO OCCASIONALLY WAXY LUSTRE; COMMONLY GRADING TO VERY FINE SILTY SANDSTONE; SILTY, WAXY, DARKER GRAY CLAYSTONE IS NON CALCAREOUS; GRITTIER, BROWNISH SILTSTONE IS MODERATE TO VERY CALCAREOUS; TRACE BLACK, MICROTHIN CARBONACEOUS! COAL LAMINATIONS AND INCLUSIONS. SANDSTONE (7590' - 7680') = LIGHT TO MEDIUM GRAY WITH STRONG SALT AND PEPPER APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO LIGHT GRAY TO LIGHT TRANSLUCENT GREENISH GRAY AND BLACK; VERY FINE UPPER TO FINE UPPER; ANGULAR TO SUBANGULAR; VERY WELL SORTED; LOOSELY CONSOLIDATED TO FRAGILE; LIGHT GRAY TO LIGHT GRAYISH WHITE NON CALCAREOUS CEMENT; ADDITIONAL SANDSTONE HAS SAME COLOR CHARACTERISTICS BUT IS VERY FINE LOWER TO COARSE LOWER; POORLY [::I EPOC:H 21 (.M)Marathon Oil Company - Abalone #1 f SORTED; ANGULAR TO SUBROUNDED; VERY CALCAREOUS CEMENT; MODERATE TO VERY HARD. TUFFACEOUS CLAYSTONE (7660' - 7760') = LIGHT BROWN TO LIGHT BROWNISH GRAY WITH MEDIUM BROWN SECONDARY HUES; VERY SOFT AND OCCASIONALLY VERY STICKY; GENERALLY SHAPELESS WITH OCCASIONAL PDC BIT ACTION SCOOPED CUTTINGS; SILTY TO ASHY TEXTURE; DULL EARTHY LUSTRE; POOR TO FAIR COHESIVENESS; FAIR ADHESIVENESS; TRACE BLACK TO DARK BROWN, MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS; TRACE LIGHT GRAYISH WHITE ASHY TUFF, VISIBLE SHARDS COMMON; TRACE THIN COAL STRINGERS. COAL (7700'-7900') = BLACK TO GRAYISH BLACK; SUB-BITUMINOUS RANK; BRITTLE, TOUGH TENACITY; IRREGULAR, BLOCKY TO CONCHOIDAL FRACTURE; POORLY DEVIATED CLEAT; ELONGATED, BLADED CUTTINGS; VITREOUS TO POLISHED LUSTER; SMOOTH TO MATTE TEXTURE; OCCASIONALLY LIGHT GRAY; THIN SLIGHTLY CALCAREOUS CLAY/ASH PARTINGS, RARELY GRADING TO MEDIUM GRAY TO MEDIUM GRAYISH BROWN CARBONACEOUS SHALE, SANDSTONE (7830' - 8000') = MEDIUM LIGHT GRAY TO LIGHT GRAY WITH MINOR BROWNISH GRAY AND MEDIUM GRAY SECONDARY HUES; VERY FINE UPPER TO FINE LOWER WITH OCCASIONAL MEDIUM LOWER AND RARE ( MEDIUM UPPER GRAINS; MODERATELY WELL SORTED, OCCASIONALLY POORLY SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; PREDOMINANTLY QUARTZ GRAINS WITH MINOR FELDSPAR AND VARIOUS MICRO-LITHIC FRAGMENTS; LOCALLY GRADES TO GRAYWACKE WITH INCREASING FELDSPAR CONTENT; GENERALLY SANDSTONE IS SOFT TO FRIABLE WITH OCCASIONALLY MODERATELY HARD IN DARKER AND BROWNISH VARIETIES; MATRIX COMPOSED OF WHITE TO LIGHT GRAY OCCASIONALLY BLUISH WHITE ASHY/CLAY; PREDOMINANTLY GRAIN SUPPORTED; COMMON CARBONACEOUS MICRO FRAGMENTS AND OCCASIONALLY CARBONACEOUS STRINGERS; GENERALLY SLIGHTLY CALCAREOUS; COMMONLY SILTY YIELDING A "DIRTY" APPREARANCE, NOTE: ABUNDANT SAFE CARB IN SAMPLES. COAL (8000-8025) = BLACK, OCCASIONALLY GRAYISH BLACK; CRUNCHY TO BRITTLE TENACITY; CONCHOIDAL AND ANGULAR CLEAT DEFINED FRACTURE; WEDGELlKE, CURVED CUTTINGS WITH BOWED, STRIATED SURFACE BREAKAGE; VITREOUS TO GREASY LUSTER; TEXTURE IS SMOOTH, OCCASIONALLY GRADING TO MATTE; MASSIVE BEDDING STRUCTURE; VISIBLE OUTGASSING; TRACE DARK YELLOWISH ORANGE TO LIGHT BROWN FLUORESCENT AMBER; PREDOMINANTLY SUB-BITUMINOUS RANK; OCCASIONALLY GRADING TO DARK BROWN LIGNITE AND GRAYISH BROWN TO DUSKY BROWN SIL TV CARBONACEOUS SHALE. ( [:I EP()C:H 22 (!!)Marathon Oil Company - Abalone #1 ( TUFFACEOUS CLAYSTONE (8015' - 8110 I) = WHITE TO VARIOUS SHADES OF GRAY FROM VERY LIGHT GRAY TO MEDIUM GRAY, ALSO VARIOUS SHADES OF LIGHT BROWN AND COMBINATIONS OF GRAYS AND LIGHT BROWNS; GENERALLY CURDY, OCCASIONALLY STIFF; CRUMBLY TENACITY; FRACTURE TYPE IS INDETERMINATE DUE TO SOLUBiliTY OF SAMPLES IN DRilliNG FLUIDS; CUTTINGS ARE TABULAR TO NODULAR; WAXY TO DULL, EARTHY LUSTER; SMOOTH TO MATTE TEXTURE; BEDS ARE MASSIVE WITH INTERBEDDED TUFFACEOUS SILTSTONE, AND ASHY SANDSTONE. SANDSTONE (8100' - 81801) = LIGHT TO MEDIUM GRAYISH BROWN WITH LIGHT BROWN SECONDARY HUES, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO LIGHT GRAY TO LIGHT TRANSLUCENT GREENISH GRAY AND BLACK; VERY FINE UPPER TO FINE UPPER; ANGULAR TO SUBANGULAR; VERY WELL SORTED; LOOSELY CONSOLIDATED TO FRAGILE; LIGHT GRAY TO LIGHT GRAYISH BROWN NON CALCAREOUS CEMENT; TRACE LIGHT GRAYISH WHITE, SALT AND PEPPER SANDSTONE, VERY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; POORLY SORTED; FRAGILE; 'VERY LOOSELY CONSOLIDATED WITH WHITE, VERY CALCAREOUS CEMENT; NO SAMPLE FLUORESCENCE, ( TUFFACEOUS CLAYSTONE (8150' - 82401) = DOMINANTLY LIGHT TO MEDIUM BROWN TO LIGHT BROWNISH GRAY WITH LIGHT GRAY AND DARKER BROWN SECONDARY HUES; SHAPELESS, AMORPHOUS CUTTINGS; VERY SOFT; VERY STICKY; EARTHY TO DULL LUSTRE; SMOOTH, SILTY TO SLIGHTLY GRITTY TEXTURE; POOR COHESIVENESS; POOR TO FAIR ADHESIVENESS; MODERATE TO VERY SOLUBLE; HYDROPHILIC; SLIGHT TO MODERATELY EXPANSIVE WHEN HYDRATED; TRACE BLACK, MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS; TRACE THIN COAL STRINGERS; TRACE VERY LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY TUFF. SANDI SANDSTONE (8270' - 8350') = VERY LIGHT GRAY OVERALL WITH MODERATE SALT AND PEPPER APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ, LIGHT GRAY, WITH TRACE LIGHT GREENISH GRAY, BLACK AND WHITE LITHS; FINE LOWER TO RARE COARSE LOWER, DOMINANTLY MEDIUM LOWER TO FINE UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED IN FINE RANGE, POORLY SORTED IN MEDIUM TO COARSE RANGE; DOMINANTLY DISAGGREGATED WITH ABUNDANT VERY LIGHT GRAY TO LIGHT GRAYISH WHITE ASHYI CLAYEY SUPPORTING MATRIX; MODERATE TO VERY CALCAREOUS; NOTE INCREASE IN WHTE TO LIGHT GRAY ASHY TUFF AT 8300'. COAL (8370-8400) = PREDOMINANTLY BLACK, OCCASIONALLY DARK GRAY; CRUNCHY, BRITTLE TENACITY; PREDOMINANTLY BLOCKY AND CONCHOIDAL FRACTURE WITH STAIR-STEP STRIATIONS COMMONLY VISIBLE ON LARGER FRAGMENTS; LARGER FRAGMENTS ARE WEDGELIKE, ELONGATED, WHEREAS ( SMALLER DISSEMINATED GRAINS ARE PREDOMINANTLY CLEAT-DEFINED [:I EP()(~H 23 @ . ~Marathon 011 Company - Abalone #1 (' BLOCKY; VITREOUS TO EARTHY LUSTER, OFTEN DISPLAYING THIN ALTERNATING BANDS OF VITREOUS AND EARTHY LAYERS; SMOOTH TEXTURE; RARE DARK YELLOWISH ORANGE FLUORESCENCE AMBER; SUB-BITUMINOUS; TRACE WHITE CHALKY CALCITE ON CLEAT SURFACES. ( CONGLOMERITIC SANDSTONE (8450' - 8500') = VERY LIGHT GRAY TO WHITE, MODERATE SALT AND PEPPER; FINE LOWER TO RARE BIT FRACTURED PEBBLES, PREDOMINANTLY FINE LOWER TO MEDIUM LOWER; ANGULAR TO SUBROUNDED; POOR SORTING; LOW TO MODERATE SPHERICITY; DOMINANTLY CLEAR TO MILKY TO LIGHT GRAY TRANSLUCENT QUARTZ, WITH COMMON CARBONACEOUS FRAGMENTS, FELDSPAR, HORNBLENDE AND OTHER VOLCANIC LITHICS (MANY OF WHICH ARE CRYPTO-CRYSTALLINE) OF VARIOUS COLORS INCLUDING PALE GREEN, GRAYISH ORANGE, MEDIUM GRAY, BLACK, WHITE; MODERATELY HARD TO HARD; ABUNDANT WHITE TO VERY LIGHT GRAY ASH/CLAY SUPPORTING MATRIX, WHICH IS COMMONLY SLIGHTLY CALCAREOUS. TUFFACEOUS CLAYSTONE (8500' - 8670') = DOMINANTLY LIGHT TO MEDIUM BROWN TO LIGHT BROWNISH GRAY WITH LIGHT GRAY AND DARKER BROWN SECONDARY HUES; SHAPELESS, AMORPHOUS CUTTINGS; VERY SOFT; VERY STICKY; EARTHY TO DULL LUSTRE; SMOOTH, SILTY TO SLIGHTLY GRITTY TEXTURE; POOR COHESIVENESS; POOR TO FAIR ADHESIVENESS; MODERATE TO VERY SOLUBLE; HYDROPHILIC; SLIGHT TO MODERATELY EXPANSIVE WHEN HYDRATED; TRACE BLACK, MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS. SANDSTONE (8570' - 8660') = LIGHT TO MEDIUM GRAYISH BROWN WITH LIGHT BROWN SECONDARY HUES, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO LIGHT GRAY TO LIGHT TRANSLUCENT GREENISH GRAY AND BLACK; VERY FINE UPPER TO FINE UPPER; ANGULAR TO SUBANGULAR; VERY WELL SORTED; LOOSELY CONSOLIDATED TO FRAGILE; LIGHT GRAY TO LIGHT GRAYISH BROWN NON CALCAREOUS CEMENT; TRACE LIGHT GRAYISH WHITE, SALT AND PEPPER SANDSTONE VERY FINE UPPER TO MEDIUM LOWER. TUFFACEOUS CLAYSTONE (8660' - 8750') = LIGHT GRAYISH BROWN WITH LIGHT BROWN AND LIGHT TO MEDIUM GRAY SECONDARY HUES; SHAPELESS, GLOBULAR CUTTINGS; VERY SOFT; VERY STICKY; CLUMPY TO TACKY; EARTHY TO GREASY LUSTRE; CLAYEY TO SLIGHTLY GRITTY TEXTURE FROM FLOATING SAND GRAINS; POOR COHESIVENESS; POOR TO FAIR ADHESIVENESS; MODERATELY SOLUBLE; HYDROPHILIC; EXPANSIVE WHEN HYDRATED; MODERATE TO VERY CALCAREOUS. VOLCANIC ASH (8750' - 8770') = LIGHT GRAYISH WHITE; PULVERULENT; VERY SOFT; COMMON VISIBLE SHARDS; COMMONLY ACTS AS SUPPORTING MATRIX FOR LOOSE SAND. ( [:I EPO(~H 24 '@)Marathon Oil Company - Abalone #1 (' COAL (8800' - 8820') = DARK GRAY TO BLACK, PREDOMINANTLY BLACK; FAIRLY BRITTLE WITH COMMON CONCHOIDAL FRACTURE, DOMINANT PLANAR FRACTURE; LARGE FRAGMENTS ARE PLATY TO BLOCKY, VERY ANGULAR; SMALLER FRAGMENTS ARE MORE FLAKY; EARTHY TO RESINOUS LUSTRE; SMOOTH TEXTURE; SCATTERED FINE TO MEDIUM SAND PRESENT; CLEAR, TRANSLUCENT TO DARK GRAY; VERY LOOSELY CONSOLIDATED TO UNCONSOLIDATED. ( SAND ¡SANDSTONE (8840' - 8960') = LIGHT TO DARK GRAY WITH STRONG SALT AND PEPPER APPEARANCE WITH VERY SILTY, DARK BROWN PIECES; FINE LOWER TO MEDIUM LOWER, OCCASIOANLL Y VERY FINE; FRAGILE TO SLIGHTY HARD; ANGULAR TO SUBANGULAR; FAIR TO MODERATELY WELL SORTED; VERY LOOSELY CEMENTED; OCCASIONALLY VERY WELL CEMENTED AND HARD; GENERALLY NON CALCAREOUS; COMMONLY GRADING TO VERY FINE, SANDY SILTSTONE; MODERATE TO VERY HARD; DARK GRAY TO DARK BROWNISH GRAY; COMMON LIGHT GRAY TO LIGHT GRAYISH WHITE, ASHY SUPPORTING MATRIX, TUFFACEOUS CLAYSTONE (8850' - 9000') = LIGHT BROWN TO LIGHT BROWNISH GRAY TO MEDIUM TO DARK GRAY; VERY SOFT TO VERY FIRM TO HARD; DARKER GRAY PIECES TEND TO BE HARDER; SHAPELESS, AMORPHOUS CUTTINGS TO TABULAR, WEDGE SHAPED FOR FIRMER; EARTHY TO WAXY LUSTRE; CLAYEY TO SLIGHT GRITTY TEXTURE; POOR TO FAIR COHESIVENES AND ADHESIVENESS; NON CALCAREOUS. SANDSTONE (8980' - 9060') = LIGHT TO DARK GRAY WITH SALT AND PEPPER APPEARANCE OVERALL, INDIVIDUAL GRAINS DOMINANTLY CLEAR QUARTZ, TRANSLUCENT LIGHT GRAY, WHITE, WITH BLACK AND LIGHT BROWNISH YELLOW TO TAN LlTHS; VERY FINE UPPER TO MEDIUM UPPER; ANGULAR TO SUBROUNDED; WELL SORTED IN FINE RANGE, POOR TO FAIR SORTING IN MEDIUM RANGE; SANDSTONE FRAGMENTS UP TO 7mm; VERY WELL CONSOLIDATED AT TIMES WITH VERY CALCAREOUS CEMENT; OTHER LIGHT GRAY SANDSTONE IS POORLY CONSOLIDATED WITH WHITISH GRAY, VERY ASHY SUPPORTING MATRIX; NON CALCAREOUS. TUFFACEOUS CLAYSTONE (9060' - 9250') = LIGHT BROWN WITH LIGHT GRAY TO LIGHT GRAYISH BROWN SECONDARY HUES; VERY SOFT TO FIRM; MODERATELY SOLUBLE; OCCASIONALLY SILTY; SILTY TO SLIGHTLY GRITTY TEXTURE; EARTHY LUSTER; SHAPELESS TO ROUNDED WEDGE CUTTINGS; FAIR COHESIVENESS; POOR TO FAIR ADHESIVENESS; OCCASIONALLY SLIGHTLY CALCAREOUS; COMMON CARBONACEOUS MIRCOTHIN STRINGERS, COAL (9100' - 9210') = PREDOMINANTLY BLACK, DARK GRAY TO GRAYISH BLACK IN LOWER SECTION TOUGH, BRITTLE TENACITY; BLOCKY, CONCHOIDAL FRACTURE ON LARGE FRAGMENTS, MEDIUM SIZED GRAINS AND FINER ARE IRREGULAR, SPLINTERY; VITREOUS TO DULL, EARTHY LUSTER; SMOOTH ( EI EPO(~H 25 (M)Marathon Oil Company - Abalone #1 ( TEXTURE; MASSIVE TO THINLY INTERBEDDED WITH AND GRADING TO CARBONACEOUS SHALE, AND/OR TUFFACEOUS CLAYSTONE; VISIBLE OUTGASSING FROM UPPER SEAM (9140'-9160'), WHICH IS SUB-BITUMINOUS, BLACK; NO VISIBLE OUTGASSING FROM LOWER SEAM (9200'-9210'), WHICH IS LOWER IN RANK, LIGHTER IN COLOR, GRADES TO SILTY, EARTHY LUSTER, LIGNITE IN PART. TUFFACEOUS SILTSTONE (9100' - 9210') = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY; OCCASIONALLY PALE BROWN AND BROWNISH GRAY; PREDOMINANTLY SILT SIZED PARTICLES IN AN ASHY/ SHALE MATRIX; FRIABLE TO MODERATELY HARD; GRADES FROM PREDOMINANTLY SILT TO SILT-CLAY MIX RESULTING IN VARIOUS ROUGH, MATTE TEXTURES; MASSIVE TO PDC-BIT BROKEN CUTTINGS; EARTHY TO FROSTED TEXTURE; COMMON GLASS SHARDS, AND DISSEMINATED CARBONACEOUS FRAGMENTS, AND MICROTHIN CARBONACEOUS STRINGERS. SANDSTONE (9160' - 9400') = WHITE TO VERY LIGHT GRAY TO DARK GRAY WITH BROWNISH GRAY TO DUSKY GRAY SECONDARY HUES; COMMON SALT AND PEPPER APPEARANCE IN LIGHTER VARIETIES, AND "DIRTY" APPEARANCE IN DARKER VARIETIES; VERY FINE UPPER TO FINE LOWER, WITH OCCASIONALLY MEDIUM GRAINS, AND RARE COARSE GRAINS; POOR TO FAIR SORTING; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; PREDOMINANTLY QUARTZ GRAINS WITH FELDSPARS AND VARIOUS LITHIC FRAGMENTS IN ASH/CLAY MATRIX; PREDOMINANTLY GRAIN SUPPORTED IN DARKER SANDSTONE, AND MATRIX SUPPORTED IN LIGHTER SANDSTONE; SLIGHT TO MODERATELY CALCAREOUS; COMMON DISSEMINATED CARBONACEOUS FRAGMENTS, AND MICROTHIN CARBONACEOUS STRINGERS; ASH/CLAY IS MODERATELY SOLUBLE RESULTING IN LARGE PERCENT OF LOOSE SAND GRAINS. COAL (9360' - 9400') = PREDOMINANTLY BLACK, WITH MINOR DARK GRAY TO GRAYISH BLACK; TOUGH, BRITTLE TENACITY; BLOCKY CONCHOIDAL FRACTURE, TRACE BIRDEYE; VITREOUS TO DULL, EARTHY LUSTER; SMOOTH TEXTURE; MASSIVE WITH THIN ASHY/CLAY AND SANDY PARTINGS; VISIBLE OUTGASSING; SUB-BITUMINOUS RANK; TUFFACEOUS CLAYSTONE (9250' -7760') = VERY LIGHT GRAY TO LIGHT BROWN TO LIGHT BROWNISH GRAY WITH MEDIUM BROWN SECONDARY HUES; VERY SOFT AND STICKY; GENERALLY SHAPELESS WITH OCCASIONAL PDC BIT ACTION SCOOPED CUTTINGS; SILTY TO ASHY TEXTURE; DULL EARTHY LUSTER; FAIR COHESIVENESS; POOR ADHESIVENESS; READILY SOLUBLE; SLIGHTLY CALCAREOUS; OCCASIONAL BLACK TO DARK BROWN, MICROTHIN CARBONACEOUS STRINGERS, AND DISSEMINATED FINE TO VERY FINE FRAGMENTS; OCCASIONALLY WHITE TO VERY LIGHT GRAY TO VERY PALE BLUE ASH WITH OCCASIONALLY SHARDS VISIBLE; NO SAMPLE ( FLUORESCENCE. ( ~ EPO(~H 26 (!!)Marathon Oil Company - Abalone #1 ( SAND ¡SANDSTONE (9500' - 95801) = NOTE GRADING TO VERY COARSE SILTSTONE; VERY LIGHT BROWN TO LIGHT BROWNISH GRAY; VERY FINE LOWER TO FINE UPPER; SUBANGULAR TO SUBROUNDED; VERY WELL SORTED; VERY LOOSELY CONSOLIDATED TO DISAGGREGATED; VERY ASHY! CLAYEY SUPPORTING MATRIX; VERY CALCAREOUS; INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ GRAINS, LIGHT BROWNISH TRANSLUCENT, TRACE BLUISH GREEN DARK GRAY AND BLACK LITHS; ABUNDANT LIGHT GRAY TO LIGHT GRAYISH WHITE ASH WITH LIGHT TO MEDIUM BROWN SECONDARY HUES; VERY SOFT TO PULVERULENT. COAL (9585' - 96501) = BLACK WITH DARK, DUSKY BROWN SECONDARY HUES; VERY FIRM TO MODERATELY HARD; FRAGILE TO BRITTLE AT TIMES; PLATY TO BLOCKY, OCCASIONALLY ELONGATED; MASSIVE; RESINOUS TO EARTHY LUSTRE; SMOOTH TO MATTE TEXTURE; DOMINANT PLANAR FRACTURE WITH COMMON CONCHOIDAL AND BIRDEYE; TRACE OUTGASSING IN LARGER, HARD FRAGMENTS; WELL DEVELOPED COALS IN THICKER BEDS, THIN STRINGERS COMMONLY GRADE TO CARNONACEOUS SHALE; VERY SILTY AND ASHY OVERALL RESULTING IN A VERY DIRTY SAMPLE; TRACE AMBER ALONG BEDDING PLANES. ( TUFFACEOUS CLAYSTONE I TUFFACEOUS SILTSTONE (9650' -97401) = LIGHT BROWN WITH BROWN AND LIGHT GRAY SECONDARY HUES; VERY SOFT TO MUSHY; GLOBULAR, SHAPELESS CUTTINGS; SOLUBLE IN PART; HYDROPHILIC; MODERATELY EXPANSIVE WHEN HYDRATED; SILTY TO SLIGHTLY GRITTY TEXTURE; EARTHY TO DULL LUSTRE; POOR ADHESIVENESS AND COHESIVENESS; MODERATE TO VERY CALCAREOUS; ABUNDANT CREAMY WHITE ASHY TUFF; VERY SILTY AND OVERALL DIRTY SAMPLE; OVER WASHING WILL JET AWAY SAMPLE. SANDI SANDSTONE (9700' - 98101) = VERY LIGHT GRAY OVERALL WITH STRONG SALT AND PEPPER APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ, LIGHT GRAY, WITH TRACE LIGHT GREENISH GRAY, BLACK AND WHITE LITHS; FINE LOWER TO RARE COARSE LOWER, DOMINANTLY MEDIUM LOWER TO FINE UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED IN FINE RANGE, POORLY SORTED IN MEDIUM TO COARSE RANGE; WELL CONSOLIDATED WITH WHITE CALCAREOUS CEMENT, VOLCANIC ASH (9810' - 98501) = VERY LIGHT GRAY TO CREAMY WHITE WITH LIGHT BROWN AND LIGHT GREENISH GRAY SECONDARY HUES; VERY SOFT TO PULVERULENT; IRREGULAR, SHAPELESS CUTTINGS; ABUNDANT VISIBLE SHARDS; SOFT GLASSY TO SPARKL Y LUSTRE; ASHY TO GRITTY TEXTURE; COMMON SUPPORTING MATRIX FOR FINE SANDS; MODERATE TO VERY CALCAREOUS; ABUNDANT LIGHT BROWN SILTY COMPONENT RESULTING IN DIRTY SAMPLE. ( [:I EPO(~H 27 @ . ~Marathon 011 Company - Abalone #1 (' COAL (9770' - 9870') = PREDOMINANTLY BLACK, RARE DARK GRAY; BRITTLE TENACITY; IRREGULAR AND CONCHOIDAL FRACTURE; VITREOUS TO WAXY LUSTER; SMOOTH TEXTURE; SUBBITUMINOUS; OUTGASSING IN UPPER SEAM. CONGLOMERITIC SANDSTONE (9870' -10050') = WHITE TO MEDIUM GRAY, MINOR GRADING TO BROWNISH GRAY; MODERATE SALT AND PEPPER APPEAR; PREDOMINANTLY FINE LOWER TO MEDIUM UPPER; OCCASIONALLY 1- 5mm ANGULAR BIT FRACTURED PEBBLES; GRADES FROM VERY FINE GRAINED, LIGHT GRAY, MASSIVE, SILTY, ASHY, NON CALCAREOUS TO MEDIUM GRAINED, LIGHT TO MEDIUM GRAY OVERALL, MASSIVE, CLEAR CALCITE MATRIX SUPPORTED; INDIVIDUAL GRAINS OF QUARTZ, CHERT, LIMONITE, HORNBLENDE, CHLORITE, JASPER AND OTHER VOLCANIC LITHICS; UNIT IS PREDOMINANTLY MODERATELY HARD TO HARD; POOR TO FAIR SORTING; ANGULAR TO SUBROUNDED; MODERATE SPHERICITY; CARBONACEOUS MATERIAL OCCURS THROUGHOUT, PRIMARILY AS DISSEMINATED FRAGMENTS; COMMON DARK GRAY CARBONACEOUS SHALE PARTINGS WITH THIN COAL STRINGERS. ( SANDSTONEI CONGLOMERATE (10035' -10100') = NOTE SAMPLE CHARACTERISTICS CHANGED WITH 10050' SAMPLE WITH ALL LITHOLOGY TYPES, SANDSTONE, CLAYSTONE, SILTSTONE AND CARBONACEOUS SHALES BECOMING HARD AND FRAGMENT SIZE INCREASING TO 3mm - 8mm COMMON; SANDSTONE IS LIGHT GRAY TO LIGHT BROWNISH GRAY WITH SALT AND PEPPER APPEARANCE AND DARK GRAY TO DARK BROWNISH GRAY WITH BLACK CARBONACEOUS INCUSIONS AND LAMINATIONS; FINE LOWER TO COARSE LOWER WITH 5°Æ, -10% SHATTERED PEBBLE FRAGMENTS 3mm - 6mm; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED BROWNISH SANDSTONE IN FINE RANGE; POORLY SORTED LIGHT GRAY TO WHITISH SANDSTONE IN MEDIUM TO COARSE RANGE; MODERATELY WELL CONSOLIDATED; CEMENTING RANGES FROM VERY CALCAREOUS TO TRACE TO NONE; ABUNDANT VARICOLORED, SHATTERED PEBBLE FRAGMENTS; TRACE LIGHT WHITISH GRAY ASHY TUFF;TRACE LIGHT BROWN AND GRAY WAXY TUFF; SCATTERED TO COMMON DARK BROWN TO BLACK CARBONACEOUS MATERIAL;COMMON THIN COAL STRINGERS; NO SAMPLE FLUORESCENCE. VOLCANIC ASH (10110' -10200') = VERY LIGHT GRAY TO CREAMY WHITE WITH LIGHT BROWN AND LIGHT BLUISH GRAY SECONDARY HUES; VERY SOFT TO PULVERULENT; IRREGULAR, SHAPELESS CUTTINGS; ABUNDANT VISIBLE SHARDS; SOFT GLASSY TO SPARKL Y LUSTRE; ASHY TO GRITTY TEXTURE; COMMON SUPPORTING MATRIX FOR FINE SANDS; NON CALCAREOUS. TUFFACEOUS SILTSTONE (10150' -10250') = PREDOMINANTLY MEDIUM DARK GRAY TO DARK GRAY WITH LESSER LIGHT BROWNISH GRAY AND DARK REDDISH BROWN; PREDOMINANTLY SILT SIZED PARTICLES WITH ABUNDANT ( CLAY/ASH COMPONENT; OCCASIONALLY GRADING TO VERY FINE GRAINED ~ EPO(:H 28 ( ( ( (M)Marathon Oil Company - Abalone #1 SIL TV SANDSTONE; POOR TO FAIR SORTING; MODERATELY HARD TO HARD; IRREGULAR TO BLOCKY FRACTURE; MASSIVE, TABULAR CUTTINGS; EARTHY LUSTER; MATTE TEXTURE; THINLY BEDDED, OR POSSIBLY OCCURS AS CONGLOMERITIC INCLUSIONS; FREQUENT CARBONACEOUS LAMINATIONS OCCASIONALLY UP TO 1 mm THICK; COMMON DISSEMINATED CARBONACEOUS FRAGMENTS; MEDIUM TO DARK GRAY IS NON CALCAREOUS; LIGHT GRAY IS SLIGHTLY CALCAREOUS; DARK REDDISH BROWN IS MODERATELY CALCAREOUS; COMMON VISIBLE GLASS SHARDS. CARBONACEOUS SHALE (10250' -10350') = MEDIUM DARK GRAY TO GRAYISH BLACK, OCCASIONALLY BROWNISH BLACK; TOUGH, BRITTLE; IRREGULAR TO TABULAR FRACTURE WITH MINOR CONCHOIDAL; MASSIVE ELONGATED TO EQUANT CUTTINGS; EARTHY LUSTER; SMOOTH TO SIL TV TEXTURE; THIN BEDDED WITH ABUNDANT THIN BANDS OF COAL THROUGHOUT; PREDOMINANTLY NON CALCAREOUS, COMMONLY SIL TV. [1 EPO(~H 29 (!!}Marathon Oil Company - Abalone #1 (" DAILY CHRONOLOGY 01/31/2003: [EPOCH RIG UP] Drill 17.5" hole from 123' to 169'. Clean out conductor. Unable to pass 169'. Circulate hole clean, Pump up survey, POOH, Lay down MWD probe, Break off bit. Adjust T opdrive compensator. Blow down mud line. Make up clean out bit. Pick up MWD probe. RIH. Attempt to. drill out of conductor failed again. POOH. Lay down MWD probe. Break aff clean out bit. Make up clean out assembly with steel DC's and 17,5" cleanout bit. RIH, Attempt to drill out of conductor failed again, POOH. Lay down 17.5" bit. Make up 12.25" bit on clean aut assembly, Work past shae. Drill from 170' to 175', POOH. Check bit. Wait an mill. Repair elevators. "Pull test" tuggers. Cellar bridge cranes, Pick up and make up mill assembly. Mill cauld not get through rotary table. Lay down mill. Pull test bridge cranes. Rig up to make up stands of 5" HWDP, Pick up and make up and drift 12 stands af HWDP, Wait on mill. Rack and set up 13,375" casing. Make up mill and RIH to. 169', Mill from 169' to. 175', Wark mill through shoe. POOH, Lay down steel drill collars, junk basket and mill. Make up 17.5" bit. Orient and install MWD, RIH. ( 02/01/2003: RIH, Tag bottom at 175', Drill 17.5" hole fram 175' to 481'. Change wear plate for #3 cyclinder liner on #2 mud pump. Drill from 481' to. 610'. POOH after MWD failure, Pull and lay down MWD tool far maintenance, Clean stabilizers and bit. Orient, install and test MWD tool. Service carrier and grease swivel. RIH, Survey at 570' and 605'. Drill fram 610' to. 708', Repair leaking weld on #2 mud pump suction screen bax. Drill from 708' to 867' (report depth) and cantinue to drill ahead. 02/02/2003: Drill from 867' to 881', Circulate, Pump up survey. Change saver sub. Drill from 881' to 1007', MWD failure, Circulate hale clean, POOH, Handle BHA, Lay dawn MWD tool. Clean stabilizers. Break bit. Make up New Bit #8. Orient, install and surface test MWD tool. Adjust Topdrive compensatar. RIH, Wash and ream from 885' to 1007'. Drill from 1007' to 1387' (report depth) and continue to drill ahead, 02/03/2003: Drill from 1387' to 1752'. Note small fluid lass at 1752', Circulate slaw. Change packing on rod oiler of mud pump #2, Change shaker screens, Drill from 1752' to 1765', Note increased mud losses at 1765'. Mix, pump and spot 40bbl LCM pill (20ppb SafeCarb M). Pull 3 stands to 1630'. Monitor well. Mix, pump and spat 40bbl LCM pill (10ppb SafeCarb F, 30ppb SafeCarb M), CBU three times. Work pipe from 1568' to 1630', Do wiper trip to. 885'. RI H. Drill fram 1765' to. 1965' (report depth) and continue to drill ahead. t 02/04/2003: Drill 17,5" hole fram 1965' to. 2110', Repair #2 charge pump suctian screen, Drill from 2110' to 2210'. Circulate and condition mud and hole. Monitor well. Pump and spot LCM pill. Pull to 2008', Monitor well. Pump and spot LCM pill. Pull to 1790'. Hole tight. Ream out from 1816' to 1754', Spot 40bbl LCM pill at 1630', POOH. Strap pipe an way out. Lay down MWD tool and hang aff sub. Glean stabilizers and bit. Monitor well. Service rig, RIH to 2130'. Wash and ream fram 2130' to 2210'. Circulate and condition mud and hole. Spot 40bbl LCM pill on bottom, Pull up to 2000', Spot 40bbl [j EPO(~H 30 {M)Marathon Oil Company - Abalone #1 ( LCM pill. Pull to 1816'. Mix and pump 40bbl LCM pill. Continued minor losses at report time. 02/05/2003: Mix and pump LCM pill at 1816'. Monitor fluid loss. Pull two stands to 1692', Mix mud and pump LCM pill. Monitor fluid loss, Mix and pump LCM pill at 1660'. Monitor fluid loss. Loss down to 2 bblslhr. POOH slow. Handle BHA. Clean stabilizers and bit. Lay down string stabilizer. Break off bit. Stand back MCS motor. Clear floor of 17.5" tools. Remove drill pipe elevators and bails, Rig up to run 13 3/8" casing. Adjust torque tube. Rig up stabbing board. Rig up Weatherford. Hold PJSM for running casing. Make up float equipment. Break circulation. Check floats. RI H with 13 3/8" casing to 1110'. Break circulation. Continue RIH to 2210'. Remove bell guide from elevator. Remove casing spyder. Land casing. ( 02106/2003: Rig down casing equipment. Change bails, Install drill pipe elevators, Adjust and secure top drive track. Rig up to run in hole with seal. Make up seal. Make up pup joint. RIH, POOH. Torque 13 STDS, RIH, tag landing collar at 2161', Circulate DP volume +40 bbls. Set down 15K on seal. PJSM, Make up CMT head. Pump 25bbls spacer. Test CMT lines 2Kpsi, OK. Pump CMT, 950 sx type 1 cmt with 20% LW-6, 20% MPA-1, 1 % CaCI2, 3% CD 32, 1 % A-2 & 1 gal FP-6L. No CMT returns to surface, Displace 3 bbls H20, Drop plug, Displace 18 bbls with rig pump. Rig down CMT head after checking floats. Pump WOL DP dart out of DP & POOH with 4" DP. Load out CMT equipment. CIO bales and elevators. Remove spider and run 1 1/4" pipe to 350' outside 13 3/8" casing for top job. Rig up to cement. P JSM and pressure test lines to 2000 psi OK. Repair valve in pill pit. 02/07/2003: Repair valve in pill pit. MIU CaCI2 for cement. Top job, Flush stack. Pull out and lay down 1 1/4 DP. RID small handling tools. Nipple down diverter and stack. Rough cut 13 3/8 and pull out. Set out diverter and stack in stand, Cut off surface pipe flange. Make final cut in 13 3/8, Set in slip on wellhead, Nipple up, Mix mud, 02/08/2003: Nipple up BOPE, riser, fill-up lines and trip tank chains, Tighten flanges and function test. Rig up test joint. Install test plug. Test all BOPE ( [12 choke valves] dart, floor check valve, 2 Topdrive valves, 2 kill valves, manual choke, HCR, top pipe rams, lower pipe rams, and blind rams) to 250psi Lo/3000psi Hi, Perform accumulator test. Pull test plug, Make up and land 95/8" hanger, Run wear bushing, Lay down casing tools. Change out bales, Change out stand pipe, Install brackets, Work on HCR control. Prep rig for M-I Unit and mud tank, Stage together BHA, Change out mud motors and stabilizers. Orient and install MWD tool. RI H with HWDP, Rig up to pick up DP. Pick up, make up, rabbit, strap and torque 66 joints DP,and RIH to 2065'. Slip and cut drill line. 02/09/2003: Slip and cut drill line, Circulate and condition old mud, Rig up and test 13 3/8" casing to 1500psi for 30 minutes, Circulate and clean out 133/8" casing. Tag top of float collar at 2163'. Tag top of shoe at 2206' and drill to 2209'. CBU. Do F,I.T to 11.0ppg. Clean pill pit. Displace well with 9,Oppg Flo-Pro mud after 10bbl water spacer. t Send old mud to tiger tank for disposal. Circulate and condition and build additional ~ EPOC.:H 31 (.M.}Marathon Oil Company - Abalone #1 (,. t volume, Drill new hole from 2209' to 2230'. CBU, Perform L.O.T. to 14.5 EMW, Change grabber dies. Drill from 2230' to 2774' (report depth) and continue to drill ahead. 02110/2003: Drill from 2774' to 3346', Circulate and condition hole for wiper trip. POOH to shoe at 2206'. Shut in well for electrical installation, Install additional breaker in generator house, for the new pump house. Service rig. RIH. Drill from 3346' to 3477' (report depth) and continue to drill ahead. 02/11/2003: Drill from 3477' to 3346'. Circulate and condition hole. POOH, Backream to 3410'. Circulate hole clean at 3410', POOH, Change out bits, RIH to shoe at 2206'. Service rig. Work on Topdrive grabber dies. 02/12/2003: Repair Topdrive grabber. RIH to 3472', Ream from 3472' to 3534'. Circulate and condition. Ream from 3534' to 3900', Drill from 3900' to 4350'. Circulate and condition. ( 02/13/2003: Circulate hole clean and condition, Back ream from 4221' to 2848', (Mud weight increased from 9,35ppg to 9,6ppg during backreaming), POOH to shoe. Service rig, RIH (tight from 4040' to 4273'). Fill pipe, Tag fill at 4339', Wash and ream to 4350', Circulate and condition mud, POOH (SLM). Break and lay down MWD tool, motor and bit. Hold P JSM for wireline logging. Rig up Schlumberger, Make up and pick up Platform Express logging tools for first run and RIH, Log up and POOH. Lay down and break down Platform Express, Make up and pick up DSllogging tools for second run and RIH, Log up and POOH. Lay down and break down DSI. While wireline logging, installed 4" liners in #3 mud pump, installed driller's console controls for the #3 mud pump, repaired the M-I Center Van and processed the mud in the pits (reducing the mud weight from 9,6ppg to 9.45ppg). 02/14/2003: RID SWS. P/U & M/U BHA #5, RIH W 4" HT38 DP, Fill pipe. Wash & ream 4272 to 4310. Tag fill @ 4347. CIO, C/4350, Circulate & condition mud. Mix and pump dry job. POOH. LID BHA. Install 9 5/8" csg rams & test door seals, 250/3000 psi. Pull down wear ring, . RIU to run esg. PJSM & run 9 5/8" esg, Break circulation at shoe. 02/15/2003: Run 9 518" esg, (40 Ibslft L80), M/U hanger & land. 216K high, 135K low. Circulate & condition mud, 200 spm @ 884 psi. PJSM W/BJ, Pump 2 bbls H20, Test lines to 3000 psi. Drop Plug. Mix & pump pre slush, 40 bbls @ 10 ppg, Mix & pump lead cmt, 60 bbls @ 12 ppg. Mix & pump tail cmt, 180 bbls @ 13.5 ppg. Drop plug. Displace W rig, Bump plug 500 psi over, Check floats, Rig down cmt equipment. C/O bails on TD, Blow down mud lines, Fold up stabbing boards, Hang tongs, Change liners in No, 1 pump. RlU & install 9 5/8 X 13 3/8 packott. Test to 5000 psi. Pull riser & repair. BD running low. Install variable pipe rams & riser. RlU to test BOPs, Test all BOPs to 250/3500 psi. Test Koomey. RID test equipment. Set wear ring, RIH & LID 5" HW DP, Rack DP. Service rig. CIO Dennison drive line. P/U 4" DP. ( 02/16/2003: Pick up and stand baek 31 stands of HT -38 4" drill pipe, Rack, strap and tally BHA #6. Strap and tally 100 joints 4" HT -38 drill pipe. Piek up, make up andRIH U EP()(~H 32 .M.)Marathon Oil Company - Abalone #1 (" BHA #6, Pick up, make up and RIH with 4" drill pipe. Rig up and test 9 5/8" casing (to 3350psi for 30 minutes). Drill out float collar at 4250'. Wash to 4336'. Drill out shoe. Wash to 4350'. Drill from 4350' to 4370'. CBU. Perform Leak Off Test (16.3 EMW). POOH. 02/17/2003: POOH. Pick up and make up BHA #7. Program, orient and test MWD tool. RI H to 4336', Clean pill pit and trip tank. Hold P JSM on displacement procedures. Displace well (at 160spm and 800psi). Mix and pump dry job, Blow down mud lines, POOH, Change bit. RIH to shoe, Service rig, Drill from 4370' to 4709' (report depth) and continue to drill ahead. 02/18/2003: Drill from 4675' to 4916', POOH to shoe, Repair top drive washpipe, Ream 4367' to 4916'. Drill from 4916' to 5430'. CBU, short trip to 4380'. RIH, drill 5430' to 5558'. 02/19/2003: Drilled 5558' to 5934', CBU 3 times, POOH to shoe, Rig repairs (replaced top drive compensator cylinder, replaced link tilt and elevator switches; rebuilt #1 pump valve; rig service), RIH smooth, Drilled ahead from 5934' to 6345' at midnight. Rigging up sol ids van for additional solids control at midnight. 02/20/2003: Drilled 6345' to 6677', Circulate and condition mud, POOH to 5934', RIH to 6677. Drilled from 6677' to 7236'. ( 02/21/2003: Circulate and condition hole @ 240 spm and 1400 psi. POOH to 6677', RIH to 7230'. Drill from 7236' to 7508'. CBU. POOH. Pull wear ring. 02/22/2003: Test BOP - check manifold valves, floor valve, dart valve, upper and lower top drive valves, 27/8 x 5 1/2 variable pipe rams, lower 4" pipe rams, Hydril, blind rams, 2 killing valves, check valve, HCR, Man HCR valve, +1250 & 3500 psi, accumulator test, blow down choke lines, set wear ring, BHA - change motor, make up bit and hole opener, orient, surface test MWD, RIH to 4245, cut and slip drill line 100', inspect brakes, RIH from shoe to 7430, break circulation, work and ream from 7430 to 7508, fan bottom, Drill ahead from 7508' to 7953'. 02/23/2003: Drilled from 7953' to 8272', CBU, Short trip to 7490', Drilling from 8272' to 8521', 02/24/2003: Drilled ahead from 8521', worked to reduce mud weight until 9,35 PPG achieved, drilled to 8774'. CBU. POOH (tight @ 7770') to shoe; removed top drive valve accuator, continued trip out; replaced top drive valve accuator, pulled motor - changed bit; began to RI H @ midnight. 02/25/2003: RIH, fill pipe @ 9 5/8 shoe; RIH to 8765'; wash & ream from 8765' to 8774'. Fan bottom. Drilling ahead from 8774' to 9386'. ( [:I EPO(:H 33 ~ . ~Marathon 011 Company - Abalone #1 ( 02/26/2003: Drilling ahead from 9386' to 9922'. CBU x2 and pump slug. Short trip to 8522'. RIH and pick up 18 joints of drill pipe. On bottom at midnight 02/27/2003: Drilling from 9922' to 10,276'. 02/28/2003: Drilled from 10,276' to 10,356'. Circulated, checked flow, pumped pill, POOH SLM. Cotta box oil pump failure, Continued to POOH to shoe. Monitor well and check cotta box and repair, Alternately POOH and repair cotta box in order to allow cotta box to cool down. 03/01/2003: Stand back HWDP, jars, LID MWD, stab, bit. RIH with logging tools, RR9 bit. PJSM. RIH to shoe, inspect gears in cotta box. LWD logging from 4316' to 5900' at midnight 03/02/2003: L WD log from 5900' to 6934'. Circ, remove grabber box from top drive. LWD log from 6934' to 7125'. Install grabber box in top drive. LWD log from 7125' to 8250'. 03/03/2003: MAD pass from 8250' to 10,356'. CBU and mix and pump dry job. Flow chech well. Lay down single and POOH. ( 03/04/2003: POOH with logging tools; BHA P JSM, remove sources, download logs, LID tools, pull wear ring, test BOP; Maintain and service rig while waiting on orders. 03/05/2003: Epoch Unit and crew released 12:05 March 5,2003. ( U EP()C:H 34 --' ~ ."-" 35 [~ EPOf:H (!!)Marathon Oil Company - Abalone #1 RIG ACTIVITY -I a.. :r: t') z w (f) w (f) t') w t') >- I- a.: <{ w Z t') l- t') ~ (f) (f) .....J -I ö:: ~ z a ü a::: z ~ a > z I- Z :3 :r: a.. ~ z (f) z a::: w :J « ö:: I- ~ ~ ;; ë( ::::¡ -I ö:: ð ;; w a a ü5 w I a a::: a 0 a::: a.. a.. w 0 ¡:::: :2: 0' CD CD I- ~ :J w f- w W -I 0 W W ....... 0 5 lL. (f) 0 z 0 ....... (f) a::: -I <{ Z a.. ~ ü (f) ....... lL. ü: ci w <{ :J :J ö:: ::::¡ z w a.. f- :2: Ü Ü :2: a z ...J ð :J I- a ë5 ü -I t') t') 0 w l- t') Z (f) a -I 0 ;5 a::: a::: ö:: ö:: a::: :J -I ::::¡ W W ~ W >- a.. a::: z ö:: ;5 a::: » a::: Ü Ü ~ ¡:::: ....... -I I- a.. ü .....J ::::¡ 0 a.. I- a.. (f) -i I- (f) :2: :J (f) a.. ...J -I ~ « rrl (f) ü w Z ...J a t') I- :;z 0 -I ö:: -I -I W $ 01/31 3.0 5.0 0.5 1.0 2.5 12.0 24.0 02101 17.5 3.0 0.5 3.0 24.0 02102 17.5 2.0 1.0 1.5 2.0 24.0 02103 13.5 2.0 2.0 5.5 1.0 24.0 02104 6.5 5.0 8.5 3.0 0.5 0.5 24.0 02105 2.0 6.0 15.0 1.0 24.0 02106 7.0 1.0 1.0 8.0 7.0 24.0 02107 0.5 1.5 1.0 21.0 24.0 02108 6.0 1.0 6.5 2.5 4.5 3.5 24.0 02100 14.0 6.0 0.5 0.5 1.0 2.0 24.0 02110 19.5 1.5 1.5 0.5 1.0 24.0 02/11 13.0 8.0 3.0 24.0 02112 13.5 1.5 3.0 1.0 1.0 4.0 24.0 02/13 0.5 7.5 3.5 3.0 1.0 8.5 24.0 02/14 9.0 0.5 3.0 0.5 9.0 2.0 24.0 02/15 5.0 2.0 1.0 0.5 5.0 3.0 2.0 3.5 2.0 24.0 02116 3.0 17.5 1.5 1.0 1.0 24.0 02117 6.0 10.0 5.5 1.0 1.5 24.0 02118 18.5 1.0 1.0 1.5 2.0 24.0 02119 16.5 2.0 2.0 1.0 2.5 24.0 ~ "-' ~i _36 ~ EPOCH (M)Marathon Oil Company - Abalone #1 02120 21.5 1.0 1.5 24.0 02121 14.5 6.5 2.5 0.5 24.0 02122 13.0 3.5 0.5 1.5 1.5 4.0 24.0 02123 22.0 1.0 1.0 24.0 02124 14.5 7.5 1.0 1.0 24.0 02125 20.5 3.0 0.5 24.0 02126 19.0 3.0 2.0 24.0 02127 24.0 24.0 02128 7.5 8.5 2.5 5.5 24.0 03/01 2.0 5.0 14.0 3.0 24.0 03/02 2.0 22.0 24.0 03/03 4.5 1.5 18.0 24.0 03/04 2.5 1.5 12.0 2.0 2.0 4.0 24.0 TOTAL 319.0 138.5 9.0 55.0 14.5 8.0 45.5 5.0 54.0 9.0 0.0 37.0 11.0 0.0 8.5 14.5 16.5 28.5 2.0 3.0 0.0 1.5 0.0 12.0 792 % 40.28 17.49 1.14 6.94 1.83 1.01 5.74 0.63 6.82 1.14 0.00 4.67 1.39 0.00 1.07 1.83 2.08 3.60 0.25 0.38 0.00 0.19 0.00 1.52 100.0 Marathon Oil Company - Abalone #1 RIG ACTIVITY SUMMARY TOP DRIVE -RUN CASING WIRELlNE LOG MAD SLIP DRILL LlNE-~ .~ ~, RIG LOST CIRCULATING REAM / WASH .DRILL · LOST CIRCULATION · MAD PASS · CMTING ACTIVITY .TEST LlNES/BOPE · FISHING TRIP .TRIP · RIG SERVICE .WIRELlNE LOG · DRILL CEMENT · NIPPLE UP/DOWN .DIR. WORK ACTIVITY DRILL CEMENT RIG UP/OWN EQUIP. LlNES/BOPE NIPPLE UP/DOWN DRILL DREAM / WASH DCIRCULATING .RIG REPAIRS .SLlP DRILL LINE ilTOP DRIVE .RUN CASING ilRIG UP/OWN EQUIP. .B H A DTEST CASING DLEAK OFF TEST .WELL KILL PROCEDURES D MISCELLANEOUS 37 (.M)Marathon Oil Company - Abalone #1 MUD RECORD DATE DEPTH MW VIS PV YP GELS Fl FC SOL Oil SD MBT pH Alk CI- Ca+ MD 1 TVD 1/31/03 273/273 4 0/96 20 10.0 0.60 0 -- ------ - --- - ------- 2/1/03 886/886 4.0 0/96 22.5 10.2 0.70 20 -- -----"_.-- 2/2/03 1442/1408 6.0 0/94 22.5 9.5 0.20 20 - - ----- 2/3/03 1950/1863 6.0 0/94 22 9.5 0.25 20 - -- -- --- ------ - ----- 2/4/03 2210/2100 5,5 0/94.5 22 9.0 0.10 40 2/5/03 2210/2100 6,0 0/94 23 8.5 1.00 40 2/6/03 2210/2100 4.5 0/95,5 16 8.8 200 2/7/03 2210/2100 3.0 0/97 0 9,5 20 - - -- -- -- -- 2/8/03 2210/2100 3.0 0/97 0 9.5 1.30 40 2/9/03 2764/2624 3.5 0/96.5 2 9,5 1.45 100 -- -.---------------------.-- 2/10/03 3558/3416 5.0 0.5/94.5 3 9.2 1.20 80 --------- ------- --~ 2/11/03 3900/3759 4.0 0.5/95.5 10 9,0 0.70 60 ---- - ------ 2/12/03 4350/4208 5.0 1/94.0 8.0 8.5 0.60 400 - 2/13/03 4350/4208 4.0 1/95,0 7.5 8,5 0.10 400 ---~ 2/14/03 4350/4208 5.0 1/94,0 10 8.5 0.05 400 - -------- 2/15/03 4350/4208 5.0 1/94 12.5 8.5 0.10 320 - - ~----- --- 2/16/03 4370/4228 7.0 1/92 10 11.7 2/17/03 4798/4656 7.5 0/92.5 5 9.7 120 __ __ _____u _____ ____ _____ 2/18/03 5557/5414 7.5 0/92.5 5.5 9,0 0.40 40 - -- ------ -------- 2/19/03 6345/6202 8.0 0/92 5.5 9.5 0.50 40 -- --------- ---- ---- 2/20/03 7230/7087 7.5 0/92.5 5 9.8 0.40 40 -- --- ------- - 2/21/03 7508/7364 7.5 0/92.5 5 9.9 0.50 40 - - - -------- 2/22/03 7950/7808 7.5 0/92.5 5.2 9,6 0.20 80 -- 2/23/03 8517/8373 7.5 0/92,5 5 9.9 0,60 . 40 ---------- - --- --- --- 2/24/03 8774/8630 7.5 0/92.5 5.2 9,8 0.50 60 ---------- [~ EP()(~H 38 ~. -~ ~ ~)Marathon Oil Company - Abalone #1 DATE DEPTH MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Alk CI- Ca+ MD I TVD 2/25/03 9382/9238 33 18/22/23 TR 6 9.5 0.33 28800 80 _ ____ _H _ ________ 2/26/03 9968/9818 29 16/20/24 TR 6 9.3 0.25 27000 60 -- ------- -------------- 2/27/03 10287/10134 29 15/18/22 TR 6 9.1 0.20 28000 60 2/28/03 10356/10202 27 14/17/21 0.25 6 9.5 0,35 27000 60 -- ----- 3/1/03 10356/10202 25 14/17/22 TR 6 9.4 0.15 25500 60 3/2/03 10356/10202 25 13/16/21 TR 6 9,3 0.1 24500 80 - -----.----" 3/3/03 10356/10202 26 13/16/23 TR 6 9.5 0,25 23000 80 - --- 3/4/03 10356/10202 21 11/14/19 TR 6 9,5 0.2 22500 80 [~ EPO(~H 39 ""~ --/ .--/ (M)Marathon Oil Company - Abalone #1 (' SURVEY RECORD MEASURED HOLE VERTICAL COURSE DOG COORDINATES LEG DEPTH TVD ANGLE AZIMUTH SECTION LENGTH N (+) or S (-) E(+)orW SEVE (-) RITY 0 0 0 0 0 0 0 0 0 196 196 0.35 311.7 -0.32 196 0.40 -0.45 0.18 255 255 0.26 314.1 -0.50 59 0.61 -0.68 0.15 287 287 0.44 48.7 -0.63 32 0.74 -0.64 1.65 345 345 0.35 78.9 -0.87 58 0.92 -0.30 0.39 406 406 0.50 303.9 -1.04 61 1.11 -0.33 1.29 467 466.99 0.35 320.1 -1.28 61 1.40 -0.67 0.31 526 525.98 2.5 187.3 -0.11 59 0.26 -0.95 4.66 555 554.94 3.0 184.6 1.28 29 -1.12 -1.10 1.78 585 584.88 4.1 186.9 3.13 30 -2.97 -1.29 3.70 ( 647 646.67 5.4 187.3 8.27 62 -8.06 -1.92 2.10 706 705.34 6.7 188.8 14.48 59 -14.22 -2.80 2.22 767 765.86 7.7 189.1 22.13 61 -21.77 -3.99 1.64 826 824.19 9.5 188.0 30.95 59 -30.50 -5.30 3.06 890 887.21 10.6 189.9 42.12 64 -41.53 -7.04 1.79 954 949.90 12.6 190.5 54.98 64 -54.19 -9.33 3.13 1016 1010.24 14.0 187.8 69.24 62 -68.27 -11.58 2.47 1078 1070.08 16.3 187.2 85.44 62 -84.33 -13.69 3.72 1140 1129.25 18.4 184.9 103.90 62 -102.72 -15.61 3.56 1202 1187.70 20.6 182.3 124.49 62 -123.37 -16.89 3.81 1264 1245.40 22.3 183.1 147.03 62 -146.01 -17.96 2.78 1326 1302.23 24.8 181.7 171.63 62 -170.76 -18.98 4.13 1386 1356.43 26.0 185.5 197.24 60 -196.43 -20.62 3.37 1449 1412.86 26.8 185.6 225.20 63 -224.31 -23.33 1.27 1511 1468.18 26.9 187.5 253.17 62 -252.13 -26.52 1.39 \ 1576 1525.98 27.6 193.0 282.90 65 -281.38 -31.83 4.02 I 1640 1582.77 27.3 195.2 312.28 64 -309.99 -39.01 1.65 [=I EPO(:H 40 ~M.)Marathon Oil Company - Abalone #1 (' MEASURED HOLE VERTICAL COURSE DOG COORDINATES LEG DEPTH TVD ANGLE AZIMUTH SECTION LENGTH N (+) or S (-) E (+) orW SEVE (-) RITY 1700 1636.26 26.6 197.1 339.26 60 -336.11 -46.57 1.85 1733 1665.83 26.1 197.8 353.75 33 -350.08 -50.96 1.78 1761 1691.00 25.8 196.9 365.87 28 -361.78 -54.62 1.77 1797 1723.51 25.1 195.1 381.22 36 -376.65 -58.88 2.90 1822 1746.19 24.7 192.5 391.71 25 -386.87 -61.39 4.66 1860 1780.79 24.1 190.9 407.39 38 -402.24 -64.58 2.35 1888 1806.30 24.6 187.2 418.93 28 -413.63 -66.39 5.73 1952 1864.40 25.0 188.2 445.76 64 -440.23 -69.99 0.91 1982 1891.61 24.8 186.7 458.39 30 -452.76 -71.63 2.21 2014 1920.69 24.6 188.2 471.75 32 -466.02 -73.36 2.06 2045 1948.92 24.2 188.5 484.56 31 -478.69 -75.22 1.35 2076 1977.18 24.3 187.3 497.29 31 -491.30 -76.97 1.62 ( 2158 2052.01 24.0 188.0 530.83 82 -524.55 -81.43 0.51 2231 2118.73 23.9 185.8 560.44 73 -553.96 -84.99 1.23 2295 2177.33 23.5 185.5 586.12 64 -579.56 -87.52 0.65 2357 2234.44 22.3 185.5 610.20 62 -603.58 -89.84 1.94 2419 2292.03 21.2 185.1 633.13 62 -626.45 -91.96 1.79 2482 2351.15 19.2 186.9 654.85 63 -648.09 -94.22 3.32 2545 2411.13 16.4 190.4 674.09 63 -667.12 -97.07 4.76 2607 2470.96 14.0 191.1 690.34 62 -683.09 -100.09 3.88 2669 2531.29 12.6 187.1 704.59 62 -697.16 -102.37 2.70 2731 2592.02 10.6 187.9 717.06 62 -709.52 -103.99 3.24 2793 2653.17 8.4 189.3 727.29 62 -719.64 -105.51 3.57 2855 2714.62 6.8 188.3 735.49 62 -727.74 -106.77 2.59 2918 2777.23 6.0 189.7 742.51 63 -734.68 -107.86 1.29 2980 2838.91 5.6 184.8 748.77 62 -740.89 -108.66 1.03 3042 2900.68 4.2 182.6 754.04 62 -746.17 -109.02 2.28 ( 3105 2963.55 3.3 191.8 758.14 63 -750.25 -109.49 1.71 3169 3027.47 2.4 204.5 761.27 64 -753.27 -110.43 1.71 U EPO(~H 41 ~ . MAIUllltOI Marathon 011 Company - Abalone #1 (' I MEASURED HOLE VERTICAL COURSE DOG COORDINATES LEG DEPTH TVD ANGLE AZIMUTH SECTION LENGTH N (+) or S (-) E (+) orW SEVE (-) RITY 3231 3089.42 2.4 198.5 763.81 62 -755.69 -111.38 0.41 3294 3152.38 1.3 199.5 765.81 63 -757.61 -112.03 1.75 3356 3214.37 1.0 154.9 766.95 62 -758.76 -112.04 1.48 3417 3275.36 1.1 143.3 767.8 61 -759.72 -111.46 0.38 3481 3339.35 0.8 132.4 768.47 64 -760.51 -110.77 0.55 3543 3401.35 0.9 154.4 769.11 62 -761.24 -110.24 0.55 3611 3469.34 0.6 161.2 769.87 68 -762.06 -109.89 0.46 3668 3526.33 1.1 156.3 770.59 57 -762.84 -109.57 0.89 3730 3588.32 0.9 160.2 771.52 62 -763.85 -109.17 0.34 3793 3651.31 1.0 177.4 772.49 63 -764.86 -108.98 0.48 3855 3713.30 1.1 174.9 773.60 62 -765.99 -108.90 0.18 3917 3775.29 1.2 171.1 774.79 62 -767.23 -108.75 0.20 3980 3838.28 1.4 160.2 776.10 63 -768.60 -108.38 0.50 ( 4041 3899.26 1.1 160.9 777.26 61 -769.86 -107.94 0.49 4103 3961.25 1.4 141.9 778.31 62 -771.02 -107.28 0.82 4166 4024.23 1.5 150.7 779.48 63 -772.34 -106.40 0.39 4229 4087.20 1.6 139.4 780.68 63 -773.72 -105.44 0.51 4290 4148.18 1.3 135.5 781.67 61 -774.87 -104.38 0.52 4371 4229.16 1.2 152.4 782.89 81 -776.28 -103.34 0.47 4434 4292.15 0.9 153.1 783.82 63 -777.30 -102.81 0.48 4625 4483.13 0.9 181.6 786.52 191 -780.14 -102.18 0.23 4810 4668.11 0.8 266.0 788.25 185 -781.68 -103.51 0.62 4997 4855.10 0.6 249.8 789.02 187 -782.11 -105.73 0.15 5182 5040.09 0.5 219.2 790.19 185 -783.07 -107.15 0.17 5370 5228.09 0.6 150.0 791.67 188 -784.56 -107.17 0.34 5558 5416.08 0.5 59.6 791.91 188 -785.00 -105.97 0.42 5747 5605.07 0.9 104.3 791.52 189 -784.95 -103.82 0.34 5874 5732.06 0.2 70.9 791.51 127 -785.12 -102.65 0.58 ( I 6059 5917.05 0.6 75.8 790.98 185 -784.78 -101.40 0.22 [:1 EPO(~H 42 (.M}Marathon Oil Company - Abalone #1 ( MEASURED HOLE VERTICAL COURSE DOG COORDINATES LEG DEPTH TVD ANGLE AZIMUTH SECTION LENGTH N (+) or S (-) E(+)orW SEVE (-) RITY 6245 6103.05 0.4 88.8 790.48 186 -784.52 -99.81 0.12 6431 6289.04 0.7 335.9 789.41 186 -783.47 -99.62 0.50 6617 6475.03 0.8 359.1 787.18 186 -781.14 -100.11 0.17 6804 6662.01 1.0 321.9 784.78 187 -778.55 -101.14 0.32 6990 6847.98 1.1 0.2 781.92 186 -775.49 -102.13 0.37 7178 7035.94 1.2 325.0 778.72 188 -772.07 -103.25 0.37 7366 7223.88 1.6 339.5 775.02 188 -768.00 -105.30 0.28 7448 7305.85 1.9 327.9 773 82 -765.77 -106.43 0.56 7678 7535.71 2.1 340.5 766.42 230 -758.57 -109.86 0.21 7866 7723.53 2.8 343.7 759.24 188 -750.92 -112.30 0.38 8051 7908.26 3.4 339.8 750.37 185 -741.43 -115.46 0.34 8115 7972.15 3.3 337.0 747.13 64 -737.93 -116.85 0.30 ( 8175 8032.05 3.3 341.6 744.13 60 -734.70 -118.07 0.44 8241 8097.93 3.7 348.2 740.45 66 -730.82 -119.11 0.86 8304 8160.80 3.6 344.0 736.76 63 -726.92 -120.07 0.45 8367 8223.66 4.1 347.5 732.87 63 -722.82 -121.10 0.87 8429 8285.50 4.1 348.9 728.72 62 -718.48 -122.01 0.16 8489 8345.34 4.3 349.6 724.59 60 -714.17 -122.83 0.34 8553 8409.16 4.3 344.7 720.14 64 -709.49 -123.90 0.57 8612 8468.00 4.2 348.6 716.10 59 -705.24 -124.91 0.52 8678 8533.82 4.3 350.0 711.49 66 -700.43 -125.81 0.22 8717 8572.70 4.5 347.2 708.69 39 -697.50 -126.41 0.75 8738 8593.64 4.1 346.5 707.23 21 -695.97 -126.76 1.92 8800 8655.47 4.5 350.0 702.88 62 -691.42 -127.70 0.77 8863 8718.27 4.7 344.7 698.19 63 -686.50 -128.82 0.74 8927 8782.03 5.1 348.2 693.15 64 -681.18 -130.09 0.78 8988 8842.79 5.2 345.4 688.08 61 -675.86 -131.34 0.44 ( 9050 8904.58 4.1 341.9 683.53 62 -671.03 -132.74 1.83 9113 8967.41 4.4 342.6 679.36 63 -666.58 -134.16 0.48 U EP()(~H 43 ~ . MIIIIJITIOI Marathon 011 Company - Abalone #1 ( I MEASURED HOLE VERTICAL COURSE DOG COORDINATES LEG DEPTH TVD ANGLE AZIMUTH SECTION LENGTH N (+) or S (-) E (+) or W SEVE (-) RITY 9175 9029.21 4.7 340.2 675.01 62 -661.92 -135.73 0.57 9237 9091.01 4.5 334.5 670.78 62 -657.34 -137.64 0.80 9300 9153.80 5.0 337.0 666.41 63 -652.58 -139.77 0.86 9363 9216.54 5.3 333.1 661.73 63 -647.46 -142.16 0.73 9424 9277.28 5.4 333.8 657.10 61 -642.37 -144.71 0.20 9486 9339.00 5.5 338.0 652.17 62 -637.00 -147.11 0.66 9548 9400.67 6.2 341.2 646.66 62 -631.07 -149.30 1.25 9610 9462.29 6.5 341.6 640.60 62 -624.60 -151.46 0.49 9672 9523.90 6.4 341.2 634.43 62 -618.00 -153.69 0.18 9735 9586.51 6.3 342.6 628.23 63 -611.38 -155.85 0.29 9799 9650.11 6.5 343.0 621.83 64 -604.56 -157.96 0.32 9862 9712.7 6.7 343.3 615.31 63 -597.63 -160.06 0.32 9920 9770.29 6.8 340.5 609.24 58 -591.15 -162.18 0.59 ( 9982 9831.82 7.4 343.3 602.42 62 -583.87 -164.55 1.12 10045 9894.29 7.3 340.2 595.13 63 -576.08 -167.13 0.65 10106 9954.78 7.5 341.6 588.20 61 -568.66 -169.70 0.44 10169 10017.22 7.8 340.2 580.81 63 -560.73 -172.44 0.56 10231 10078.65 7.9 340.20 573.51 62 -552.90 -175.26 0.16 10294 10141.05 7.9 339.50 565.95 63 -544.77 -178.24 0.15 10356* 10202.46 7.9 339.50 558.53 62 -536.79 -181.22 0.00 * PROJECTED TOTD ( [:IEP()(~H 44 BIT # 2 3 4 5 6 7* 8 BIT (!!!') Marathon Oil Company - Abalone #1 BIT RECORD SIZE TYPE SER NO, JETS DEPTH WOB RPM PP GRADE IN (Hi-Lo) Avg (Hi-Lo) Avg (Hi-Lo) Avg I - 0 - D - L - B - G - OT - R --~-~-~_._~--~ 17.5 STC DSJC ML6617 2 x 18,2 x 16 175 20-40 60 - 80 1000 -1500 2-2-WT -Ä-8-3-S D-DTF - -- - -- -- -- - - ------~-------~ 17.5 STC MSDGHQC LK1029 3 x 18,1 x 14 1007 15 - 25 60 - 70 581 - 1961 3-3-WT-Ä-E-2-SD-TD 12.25 STC FGXiVC MM3664 3 x 18, 1 x 12 2210 15 - 20 70-80 1300 -1600 2-2-WT-Ä-E-1-SD-PR 12.25 STC FGXiVC 3 x 18,1 x 12 39CX) 15 - 30 70 - 77 1478 -1877 2-2-WT -Ä-E-1-NO-CM 8.5 STC MS681 3x 16 4350 3- 28 60 - 80 474-1780 O-O-NO-Ä-E-IN-NO-BHÄ - -~------------ ---- 6.125 STC M50VYPX JS9630 6 x 10 4370 2-9 70-80 1400 -1950 0-1-NO-A-X-O-NO-PR - - - ---- 4.75 STC MDT285QYPX 7 x 10 7508 1 - 9 70-80 993 - 2186 0-1-WT - T -X-I N-NO-PR 6.125 HTC HCM406 3x 15 8772 2-6 70 - 80 1406-2190 1-1-WT-N-X-1-CT ~--~ -~~-~----~------- #7 WAS RUN WITH A OPENER [:I EpnCH 'y-- c___ ~",-,- MARATHON OIL COMPANY .( Wildcat DAILY WELLSITE REPORT g FJPOCH ABALONE #1 REPORT FOR Rowland Lawson DATE Mar 4,2003 TIME 24:00 DEPTH 10356 YESTERDAY 10356 PRESENT OPERATION= RIH with retainer 24 Hour Footage 0 CASING INFORMATION 95/8" @ 4336' DEPTH 10,356' SURVEY DATA INCLINATION 7.9 AZIMUTH 339.5 VERTICAL DEPTH 10,202.46' BIT INFORMATION NO. SIZE 8 6.125" TYPE HTC HCM406 SIN 7102176 INTERVAL JETS IN OUT 3x15 8774 10,356 FOOTAGE 1582 HOURS 61.55 CONDITION T/B/C 1-1-WT-N-X-1-CT REASON PULLED LOG DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRilLING MUD REPORT MW 9.5 VIS FC 2 SOL HIGH @ @ @ @ @ LOW @ @ @ @ @ ftIh r amps Klbs RPM psi AVERAGE CURRENT AVG ( 42 8 PV SD DEPTH: 10,356' 10 YP 21 TR OIL 0 FL 9.8 MBL 6 Gels pH 11/14/19 9.5 CL- 22500 80 CCI Ca+ MWD SUMMARY INTERVAL TO TOOLS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH lOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ None. LlTHOLOGY/REMARKS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 2/2 GAS SUMMARY(units) DITCH GAS CUTTING GAS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Interbedded conglomerltic sandstone, tuffaceous siltstone, carbonaceous shale and tuffaceous claystone, with occasional coal beds. 50% Conglomeritic sandstone, 20% tuffaceous siltstone, 20% volcanic ash, 10% tuffaceous claystone. POOH with logging tools; BHA PJSM, remove sources, download logs, UD tools, pull wear ring, test BOP; Maintain and service rig while waiting on orders. Epoch Personel On Board= 2 Daily Cost $2054 ($1709 mlog 1$345 rw) ( Report by: Peter Dykema file://C:\Abalone 1 \20030228.htm 3/5/03 ----J ---r--· MARATHON OIL COMPANY ( Wildcat DAILY WELLSITE REPORT g EPOCH ABALONE #1 REPORT FOR Rowland Lawson .DATE Mar 3,2003 TIME 24:00 DEPTH 10356 YESTERDAY 10356 PRESENT OPERATION= POOH after MAD pass 24 Hour Footage 0 CASING INFORMATION 95/8" @ 4336' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10,356' 7.9 339.5 10,202.46' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 6.125" HTC HCM406 7102176 3x 15 8774 10,356 1582 61.55 1·1·WT-N-X-1-CT LOG DRilLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 246 @ 8873 18 @ 9622 135 ftIh r SURFACE TORQUE 2748 @ 10,356 464 @ 10,179 2347 amps WEIGHT ON BIT 4.5 @ 10,179 0 @ 8988 0 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE 1288 @ 10,356 189 @ 9622 1003 psi ( DRILLING MUD REPORT MW 9.45 VIS FC 2 SOL 42 PV 8 SD DEPTH: 10,356' 9 YP 25 FL 7.8 Gels TR OIL 0 MBl 6 pH 13/16/21 9.3 CL- 24500 80 eCI Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH LOW 33 @ 9556 0 @ 9377 @ @ CHROMA TOGRAPHY(ppm) @ @ @ @ @ AVERAGE 9 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND/AVG~9 METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL @ @ @ @ @ None. LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Interbedded conglomeritic sandstone, tuffaceous siltstone, carbonaceous shale and tuffaceous claystone, with occasional coal beds. 50% Conglomeritic sandstone, 20% tuffaceous siltstone, 20% volcanic ash, 10% tuffaceous claystone. DAILY ACTIVITY SUMMARY MAD pass from 8250' to 10,356'. CBU and mix and pump dry job. Flow chech well. Lay down single and POOH. Epoch Personel On Board= 2 Daily Cost $2054 ($1709 mlog I $345 rw) Report by: Peter Dykema ( file:/ /C:\Abalone 1 \20030228.htm 3/4/03 MARATHON Oil COMPANY ( Wildcat DAILY WELLSITE REPORT g EPOCH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7102176 3 x 15 8774 . 10,356 1582 61.55 1-1-WT-N-X-1-CT lOG HIGH LOW AVERAGE CURRENT AVG @ @ ftIhr @ @ amps @ @ Klbs @ @ RPM @ @ psi DEPTH: 10,356' PV 9 YP 25 FL 7.8 Gels 13/16/21 CL- 24500 SO TR OIL 0 MBl 6 pH 9.3 Ca+ 80 CCI ABALONE #1 REPORT FOR Rowland Lawson DATE Mar 2, 2003 TIME 24:00 CASING INFORMATION 95/6" @4336' DEPTH 10,356' SURVEY DATA BIT INFORMATION NO. SIZE 6 6.125 TYPE HTC HCM406 ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.45 VIS FC 2 SOL 42 8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH 61 @ 7968 @ METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL @ @ @ @ @ DEPTH 10356 YESTERDAY 10356 PRESENT OPERA TION= MAD pass 24 Hour Footage 0 INCLINATION 7.9 AZIMUTH 339.5 VERTICAL DEPTH 10,202.46' 11 AVERAGE 12 LOW @ 7187 @ CHROMA TOGRAPHY(ppm) TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 6/12 @ @ @ @ @ None. LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Interbedded conglomerltlc sandstone, tUffaceo.us..slltstore, carbonaceous shale and tuffaceous claystone, with occasional coal beds. ,. 50% Conglomeritic sandstone, 20% tuffa¢eol,l.~. siltstone., 20% volcanic ash and 10% tuffaceous claystone. DAILY ACTIVITY LWD log from 5900' to 6934'. Circ, remove grabber box from top drive. LWD log from 6934' to 7125'. Install grabber box SUMMARY In top drive. LWD log from 7125' to 8250'. Epoch Personel On Board= 2 Dally Cost $2054 ($1709 mlog 1$345 rw) Report by: Peter Dykema ( file://C:\Abalonel \20030228.htm 3/3/03 MARATHON OIL COMPANY ( Wildcat DAILY WELLSITE REPORT g EPOCH ABALONE #1 REPORT FOR Rowland Lawson DATE Mar 1 2003 TIME 24:00 DEPTH 10356 YESTERDAY 10356 PRESENT OPERATION= MAD pass 24 Hour Footage 0 CASING INFORMATION 95/8" @ 4336' DEPTH 10,356' SURVEY DATA INCLINATION 7.9 AZIMUTH 339.5 VERTICAL DEPTH 10,202.46' BIT INFORMATION NO. SIZE 8 6.125" TYPE HTC HCM406 SIN 7102176 INTERVAL JETS IN OUT 3 x 15 8774 10,356 FOOTAGE 1582 HOURS 61.55 CONDITION T/B/C 1-1-WT-N-X-I-CT REASON PULLED LOG DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS Fe 2 SOL HIGH @ @ @ @ @ AVERAGE CURRENT AVG LOW @ @ @ @ @ ftIh r amps Klbs RPM psi ( 42 PV 8 SD DEPTH: 10,356' 10 YP 25 FL 7.6 Gels TR OIL 0 MBL 6 pH 14/17/22 9.4 CL- 25500 60 eCI Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH LOW AVERAGE METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL @ @ @ @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND/AVGM3 @ @ None. LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Interbedded conglomerltlc sandstone, tuffaceous siltstone, carbonaceous shale and tuffaceous claystone, with occasional coal beds. . 50% Conglomeritic sandstone, 20% tuffaceous siltstone, 20% volcanic ash and 10% tuffaceous claystone. DAILY ACTIVITY Stand back HWDP, jars, UD MWD, stab, bit. RIH with logging tools, RR9 bit. PJSM. RIH to shoe, inspect gears In cotta SUMMARY box. LWD logging from 4316' to 5900' at midnight. Epoch Personel On Board= 4 Dally Cost $2694.00 Report by: Peter Dykema ( file://C:\Abalone 1 \20030228.htm 3/2/03 Daily Report f MARATHON OIL COMPANY Wildcat ABALONE #1 REPORT FOR Rowland Lawson DATE ~ 28, 2003 TIME 24:00 rage:¡ 1 VI 1 DAILY WELLSITE REPORT g RPOCH . .. DEPTH 10;356 YE~T~RPA Y.,·1 0,276 24 Hour Footage 80 PRESENT OPERATION= P/U LWD tools. -CAS.ING INFORMATION 95/8" @ 4.336' DEPTH 10,356' SURVEY DATA BIT INFORMATION NO. SIZE 8 6.125" TYPE HTC HCM406 ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM ··PUMP PRESSURE DRILLING MUD REPORT MW 9.5 VIS I:=Q 2. SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) . PROPANE(C-3) . BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL INCLINATION 7.9 AZIMUTH 339.5 VERTICAL DEPTH 10,202.46' 44 8 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7102176 3 x 15 8774 10,356 1582 61.55 1-1-WT-N-X-J-CT LOG HIGH LOW AVERAGE CURRENT AVG 28.2 @ 10,276 2.7 @ 10,346 14.5 7.3 ftIhr 3369 @ 10,292 2983 @ 10,277 3201.4 3241.1 amps 10 @ 10,292 1 @ 10,304 5.4 4.4 Klbs 0 @ 10,356 , ,0 ...:..@'....' 1·0,356 0.0 0 RPM , .' ~ ' f071 .@:: ·1'0,216· '. 1864 @ 10,277 1961.5 1933 psi ,D~PTH: :10,356' PV 9 YP 27 FL 8.0 Gels 14/17/21 CL- 27000 SD 0.25 OIL 0 MBl 6 pH 9.5 Ca+ 60 CC\ 22 o HIGH LOW @ 10,336 @ 10,284 @ 10,356 0 @ 10,356 CHROMA TOGRAPHY(ppm) @ 10,336 404 @ 10,281 @ 10,329 1 @ 10,313 @ 10,336 1 @ 10,327 @ 10,356 0 @ 10,356 @ 10,356 0 @ 10,356 AVERAGE 5.6 0.0 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND/AVGOn 11019 55 8 o o 2088.0 8.9 1.4 0.0 0.0 None. LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Interbedded conglomeritlc sandstone, tuffaceous siltstone, carbonaceous shale and tuffaceous claystone, with occasional coal beds. 50% Conglomerltlc sandstone, 20% tuffaceous siltstone, 20% volcanic ash and 10% tuffaceous claystone. DAILY ACTIVITY SUMMARY Drilled from 10,265' to 10,356'. Circulated, checked flow, pumped pili, POOH SLM. Cotta box oil pump failure. Continued to POOH to shoe. Monitor well and check cotta box and repair. Alternately POOH and repair cotta box In order to allow cotta box to cool down. ( Epoch Personel On Board= 4 Daily Cost $2694.00 Report by: Peter Dykema .. -.. ... .. ..,-..........----...... , '" 11 11'\ ") .....,""'.......) ..........,1'"'''..... MARATHON OIL COMPANY ( Wildcat DAILY WELLSITE REPORT n EPOCH ABALONE #1 REPORT FOR Rowland Lawson DATE Feb 27,2003 TIME 24:00 DEPTH 10276 YESTERDAY 9922 PRESENT OPERATION= Drilling ahead 24 Hour Footage 354 CASING INFORMATION 9 5/8" @ 4336' DEPTH SURVEY DATA 10,169' INCLINATION 7.8 AZIMUTH 340.2 VERTICAL DEPTH 10,017.22' BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 8 6.125" HTC HCM406 7102176 3 x 15 8774 1502 54.72 DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 68.5 @ 10105 3.1 @ 10191 22.8 SURFACE TORQUE 3297 @ 10180 2004 @ 10230 3117.9 WEIGHT ON BIT 14 @ 10104 0 @ 10009 5.8 ROTARY RPM @ @ PUMP PRESSURE 2116 @ 10116 1546 @ 10230 1962.7 CONDITION T/B/C REASON PULLED In hole CURRENT AVG 28.2 3069.8 6.2 2071 ftlhr amps Klbs RPM psi DRILLING MUD REPORT DEPTH: 10,287' MW 9.45 VIS 44 PV 10 YP 29 FL 7.8 Gels 15/18/22 CL- 28000 ( Fe 2 SOL 8 SD TR Oil 0 MBl 6 pH 9.1 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 30 @ 10089 @ 10140 6.7 TRIP GAS= CUTTING GAS 0 @ 10276 0 @ 10276 0.0 WIPER GAS= 28u CHROMATOGRAPHY(ppm) SURVEY= METHANE(.C-1 ) 6100 @ 10089 240 @ 10140 1371.7 CONNECTION GAS HIGH= ETHANE(C-2) 63 @ 10027 1 @ 10263 6.2 AVG= PROPANE(C-3) 13 @ 10158 1 @ 10240 1.1 CURRENT BUTANE(C-4) 0 @ 10276 0 @ 10276 0.0 CURRENT BACKGROUND/AVG 3/8 PENTANE(C-5) 0 @ 10276 0 @ 10276 0.0 HYDROCARBON SHOWS None. INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Predominantly conglomeritic sandstone and volcanic ash, with lesser amounts of tuffaceous siltstone, carbonaceous shale, tuffaceous claystone and occasional coal beds. 50% Conglomeritic sandstone, 30% tuffaceous siltstone and 20% carbonaceous shale. DAILY ACTIVITY SUMMARY Drilling from 9922' to 10,276'. Epoch Personal On Board= 4 Dally Cost $2694.00 Report by: Peter Dykema ( f11p' I Ir"\ A h~ Innp.l \ ,.o010?')7 htm 2/28/03 Daily Report Page 1 of 1 (" MARATHON OIL COMPANY Wildcat DAILY WELLSITE REPORT g ,EPOCH ABALONE #1 REPORT FOR Rowland Lawson DATE Mar 1, 2003 TIME 08:00 DEPTH 10356 YESTERDAY 10293 PRESENt OPERATION= PIU LWD tools. 24 Hour Footage 63 CASING INFORMATION 95/8" @4336' DEPTH 10,356' SURVEY DATA INCLINATION 7.9 AZIMUTH 339.5 VERTICAL DEPTH 10,202.46' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIB/C PULLED 8 6.125" HTC HCM406 7102176 3x 15 8774 10,356 1582 61.55 1-1-WT -N-X-I-CT LOG DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 26.2 @ 10,311 2.7 @ 10,346 14.6 7.3 ftlhr SURFACE TORQUE 3269 @ 10,355 3018 @ 10,330 3219.0 3241.1 amps WEIGHT ON BIT 9 @ 10,346 1 @ 10,304 5.4 4.4 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE 2033 @ 10,350 1868 @ 10.311 1973.4 1933 psi DRILLING MUD REPORT DEPTH: 10.356' t MW 9.5 VIS 44 PV 9 YP 27 FL 8.0 Gels 14/17/21 CL- 27000 Fe 2 SOL 8 SD 0.25 OIL 0 MBL 6 pH 9.5 Ca+ 60 eel MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 22 @ 10,336 @ 10,319 6.5 TRIP GAS= CUTTING GAS 0 @ 10,356 0 @ 10,356 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= M ETHAN E(C-1 ) 11019 @ 10.336 471 @ 10,319 2457.4 CONNECTION GAS HIGH= ETHANE(C-2) 66 @ 10,329 1 @ 10,313 11.3 AVG= PROPANE(C-3) 8 @ 10,336 1 @ 10,327 1.8 CURRENT BUTANE(C-4) 0 @ 10,366 0 @ 10,366 0.0 CURRENT BACKGROUND/AVG on PENTANE(C-5) 0 @ 10,356 0 @ 10,356 0.0 HYDROCARBON SHOWS None. INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Epoch Personal On Board= 4 Daily Cost $2694.00 Report by: Peter Dykema ( uallY K.epOn (" ABALONE #1 REPORT FOR DATE Feb 28, 2003 TIME 01:59:31 CASING INFORMATION SURVEY DATA ·BIT INFORMATION NO. SIZE TYPE SIN DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW Fe ( MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY .. .....0..., . "". . DAILY WELLSITE REPORT g EPOCH D~PTI:ì . ,1 O~93 YESTERDAY 10040 PRESENT OPERATION= 24 Hour Footage 253 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH VIS SOL INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS TlB/C PULLED HIGH LOW AVERAGE CURRENT AVG 68.5 @ 10105 3.1 @ 10191 18.8 19.1 ftIhr 3297 @ 10180 1943 @ 10292 3143.0 3234.3 amps 14 @ 10104 2 @ 10105 6.6 3.8 Klbs @ @ RPM 2116 @ 10116 1546 @ 10230 1967.2 2000 psi DEPTH: PV YP Fl Gels CL- SD OIL MBL pH Ca+ eel HIGH LOW 30 @ 10089 @ 10284 o @ 10293 0 @ 10293 CHROMA TOGRAPHY(ppm) 6100 @ 10089 240' @ 10140 36 @ 10089 1 @ 10263 13 @ 10158 1 @ 10240 o @ 10293 0 @ 10293 o @ 10293 0 @ 10293 AVERAGE 6.3 0.0 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 1292.4 5.9 1.2 0.0 0.0 LlTHOLOGY/REMARKS GAS DESCRIPTION Epoch Parsonal On Board= Dally Cost Report by: ( ...., 11.-.. \ .., _,.._ _ 1\"'^^~^"''''O L..._~_ ") 1""~/()1 MARATHON OIL COMPANY ( Wildcat ABALONE #1 REPORT FOR Rowland Lawson DATE Feb 26, 2003 TIME 24:00 DAILY WELLSITE REPORT f.I EPðCH DEPTH 9922 YESTERDAY 9386 PRESENT OPERATION= Drilling ahead 24 Hour Footage 536 CASING INFORMATION 95/8"@4336' DEPTH 9920' SURVEY DATA BIT INFORMATION NO. SIZE 8 6.125" TYPE HTC HCM406 ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.45 VIS Fe 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL INCLINATION 6.8 AZIMUTH 340.5 VERTICAL DEPTH 9770.28' SIN 7102176 JETS 3 x 15 INTERVAL IN OUT 8774' HOURS 33.93 CONDITION T/B/C REASON PULLED In hole FOOTAGE 1148 HIGH LOW AVERAGE CURRENT AVG 120.4 @ 9614 5.6 @ 9890 39.8 45.7 ftlhr 3032 @ 9625 1717 @ 9486 2905.0 2872.3 amps 14 @ 9733 0 @ 9640 4.2 10.4 Klbs 0 @ 9922 0 @ 9922 0.0 0 RPM 2126 @ 9919 1595 @ 9802 1958.7 2086 psi DEPTH: 9968' 45 PV 9 YP 29 FL 7.6 Gels 16/20/24 CL- 27000 8 SD TR OIL 0 MBL 6 pH 9.3 Ca+ 60 eCI HIGH LOW AVERAGE 107 @ 9594 2 @ 9765 13.6 TRIP GAS= 0 @ 9922 0 @ 9922 0.0 WIPER GAS= ,'" CHROMA TOGRAPHY(ppm) SURVEY= 19612 @ 9594 435 @ 9765 2603.5 CONNECTION GAS HIGH= 44 @ 9594 1 @ 9910 6.6 AVG= 24 @ 9594 1 @ 9909 3.1 CURRENT 0 @ 9922 0 @ 9922 0.0 CURRENT BACKGROUND/AVG 5/10 0 @ 9922 0 @ 9922 0.0 None. LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major conglomeritlc sandstone, tuffaceous .claystone, tuffaceous siltstone and 'occasional coal beds, with minor carbonaceous shale and volcanic ash. 40% Conglomeritic sandstone, 40% tuffaceous claystone and 20% tuffaceous siltstone. DAILY ACTIVITY Drilling ahead from 9386' to 9922'. CBU x2 and pump slug. Short trip to 8522'. RIH and pick up 18 joints of drill pipe. SUMMARY On bottom at midnight. . Epoch Personel On Board= 4 Dally Cost $2694.00 Report by: Peter Dykema ( file:/ /C:\Abalone 1 \20030226,htm 2/27/03 .. -~_.-.-,-,~-- -.--.--.-.-.-.-..- - .. '" MARATHON Oil COMPANY (' Wildcat ABALONE #1 REPORT FOR Steven Lambe DATE Feb 25, 2003 TIME 24:00 DAILY WELLSITE REPORT n EPOCH DEPTH 9386 YESTERDAY 8774 PRESENT OPERATION= DrIlling ahead 24 Hour Footage 612 INCLINATION 5.0 9}sl- '?D r:ERTICALQ§fT~....., ~ 99153.80 /~.; "..",. . CASING INFORMATION 9 5/8" @4336' DEPTH 9300' SURVEY DATA BIT INFORMATION NO. SIZE 8 6.125" TYPE HTC HCM406 ( DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRilLING MUD REPORT MW 9.55 VIS Fe 1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS 227 CUTTING GAS 0 METHANE(C-1) 44669 ETHANE(C-2) 72 PROPANE(C-3) 45 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL AZIMUTH 337.0 46 8 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7102176 3X 15 8774' 612 18.57 In hole HIGH LOW AVERAGE CURRENT AVG 152.2 @ 9264 3.3 @ 8774 42.1 59.1 ftIhr 2965 @ 8774 133 @ 8930 1551.8 2871.1 amps 37 @ 9023 0 @ 9288 5.9 4.0 Klbs 0 @ 9386 0 @ 9386 0.0 0 RPM 2190 @ 9271 1406 @ 9049 1198.5 1903 psi DEPTH: 9382' PV 8 YP 33 Fl 7.7 Gels 18/22/23 CL- 28800 SD TR OIL 0 MBl 6 pH 9.5 Ca+ 80 CCI HIGH LOW AVERAGE @ 8810 1 @ 9024 27.7 TRIP GAS= 69u @ 9386 0 @ 9386 0.0 WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= @ 8810 362 @ 9024 5104.5 CONNECTION GAS HIGH= @ 9151 1 @ 9360 7.6 AVG= @ 9151 1 @ 9361 3.3 CURRENT @ 9386 0 @ 9386 0.0 CURRENT BACKGROUND/AVG 8/11 @ 9386 0 @9386 0.0 None. LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major sandstone and tuffaceous claystone, with minor tuffaceous siltstone, volcanic ash adn occasional coal beds. PRESENT LITHOLOGY 30% Sandstone, 30% tuffaceous siltstone, 30% tuffaceous claystone, 10% coal DAilY ACTIVITY SUMMARY RIH, fill pipe @ 9 5/8 shoe; RIH to 8765'; wash & ream from 8765' to 8774'. Fan bottom. Drilling ahead from 8774' to 9386'. Epoch Personel On Board= 4 Daily Cost $2694.00 Report by: Peter Dykema ( file:/ /C:\Abalone 1 \20030226.htm 2/26/03 Daily Report Page 1 of 1 MARATHON OIL COMPANY (" g EPOCH DAILY WELLSITE REPORT Wildcat ABALONE #1 REPORT FOR Steven Lambe DATE Feb 24,2003 TIME 24:00 DEPTH 8774 YESTERDAY 8521 PRESENT OPERATION= TrippIng out for bit 24 Hour Footage 253 CASING INFORMATION 95/8" @ 4336' DEPTH INCLINATION AZIMUTH SURVEY DATA 8738' 4.1 346.5 BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 7 4.75 x6.125 STC MDT285QYPX 7 x 10 7508 8774 1266 40.52 VERTICAL DEPTH 8593.66 CONDITION T/B/C 0-1-WT - T -X-I N-NO-PR REASON PULLED ROP DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS Fe 1 SOL HIGH 62.8 @ 8754 3000 @ 8600 10 @ 8675 0 @ 8774 1752 @ 8707 DEPTH: 8774' 48 PV 8 YP 7.5 SD TR Oil LOW AVERAGE 3.3 @ 8774 24.4 2669 @ 8598 2888.8 1 @ 8587 4.6 0 @ 8774 0.0 1412 @ 8676 1650.8 CURRENT AVG 3.3 2965.0 6.0 ftIh r amps Klbs RPM psi 1632 30 FL 7.8 Gels o MBl 5.2 pH 17/21/22 9.8 ( CL- 28600 60 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH LOW AVERAGE 29 @ 8702 @ 8743 7.4 TRIP GAS= 0 @ 8774 0 @ 8774 0.0 WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 5970 @ 8702 276 @ 8743 1426.1 CONNECTION GAS HIGH= 13 @ 8702 1 @ 8710 1.5 AVG= 7 @ 8702 1 @ 8709 0.2 CURRENT 0 @ 8774 0 @ 8774 0.0 CURRENT BACKGROUND/AVG 12/11 0 @ 8774 0 @ 8774 0.0 None. LITHOLOGY/REMARKS GAS DESCRIPTION METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY Major sandstone and tuffaceous claystone, with minor tuffaceous siltstone, volcanic ash, and occasional coal beds. PRESENT LITHOLOGY 60% tuffaceous claystone, 20% tuffaceous siltstone, and 20% carbonaceous shale. DAILY ACTIVITY Drilled ahead from 8521', worked to reduce mud weight until 9.35 PPG achieved, drilled to 8774'. CBU. POOH (tight @ 7770') SUMMARY to shoe; removed top drive valve accuator, continued trip out; replaced top drive valve accuator, pulled motor - changed bit; began to RIH @ midnight. Epoch Personel On Board= 4 Daily Cost $2694.00 Report by: Peter Dykema ( .:\j.' i _ ( , '\ '6 \) \.5...' ./// LJQ.U'y .I.'\.."'PV1" MARATHON OIL COMPANY ( Wildcat ABALONE #1 REPORT FOR Steven Lambe DATE Feb 23.2003 TIME 24:00 DAILY WELLSITE REPORT fI EPOCH DEPTH 8521 YESTERDAY 7953 PRESENT OPERATION= Dritllng ahead 24 Hour Footage 568 CASING INFORMATION 95/8" @4336' DEPTH 8489' SURVEY QAT A BIT INFORMATION NO. SIZE 7 4.75x6.125 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.45 VIS ( FC 1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) . BUTANE(C-4) PENTANE(G-S) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY INCLINATION 4.3 AZIMUTH 349.6 VERTICAL DEPTH 8345.34 INTERVAL CONDITION REASON TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED STC MDT285QYPX 7 x 10 7508 1013 30.28 In hole HIGH LOW AVERAGE CURRENT AVG 113.5 @ 8308 8.8 @ 8292 37.3 23.7 ftIhr 3062 @ 8250 978 @ 8490 2830.5 2810.5 amps 60 @ 8490 0 @ 7997 4.4 1.8 Klbs 0 @ 8521 0 @ 8521 0.0 0 RPM 1884 @ 8338 993 @ 8249 1613.3 1655 psi DEPTH: 8517' 49 PV 8 YP 34 FL 7.8 Gels 18/27/28 CL- 29250 7.5 SD TR OIL 0 MBL 5 pH 9.9 Ca+ 40 eCI HIGH LOW AVERAGE 137 @ 8009 2 @ 8365 13.7 TRIP GAS= 0 @ 8521 0 @ 8521 0.0 WIPER GAS= 14u CHROMA TOGRAPHY(ppm) SURVEY= 27205 @ 8012 449 @ 8365 2749.1 CONNECTION GAS HIGH= 34 @ 8012 1 @ 8521 3.1 AVG= 18 @ 8007 1 @ 8511 1.1 CURRENT 0 @ 8521 0 @ 8521 0.0 CURRENT BACKGROUND/AVG 8/17 0 @ 8521 0 @ 8521 0.0 None LITHOLOGY/REMARKS GAS DESCRIPTION Predominantly tuffaceous claystone and sandstone, with occasional conglomeritic sandstone, coal beds, tuffaceous siltstone, carbonaceous shale and volcanic ash. 50% Conglomeritic sandstone, 30% tuffaceous claystone, 10% tuffaceous siltstone and 10% volcanic ash. DAILY ACTIVITY SUMMARY Drilled from 7953' to 8272'. CBU. Short trip to 7490'. Drilling from 8272' to 8521'. Epoch Personel On Board= 4 Dally Cost $2694.00 Report by: Peter Dykema ( ,. " ( 97 ijJ .\~---.--.,/."...... ~1o·II(""'o·\ ^ h~ 1^nø 1 \,)(\(\~f\,),)LI. htm 2/24/03 2/23/03 tlle://C:\Abalonel \20030223.htm TA!;t ROP - ~hA~k mAnifold V::IIVA!;, floor V::IIVA, dJ:lrt V::IIVA. IIppAr J:lnd lowAr top drivA V:ÌIVA~. ? 7/R ')(' 51/? vArÎJ:lhlA pipA rJ:lm~. InWAr 4" pipe rams, Hydrll, blind rams, 2 killing valves, check valve; HCR, Man HCR valve; +1250 & 3500 psi; accumulator test; blow down choke lines, set wear ring, BHA - change motor, make up bit and hole opener, orient, surface test MWD, RIH to 4245, cut ~nd ~lIp drllllinP. 100', iMpMt hr~kA~. RIH frnm ~hnP. tn 74~n, hrA~k ~ir~lIl~tinn. wnrk And rA~m frnm 74~n tn 7finA. fRn hnttnm Drill ahead from 75081 to 7953'. . Epoch Personal On Board= 4 Dally Cost $2694.00 Report by: Peter Dykema ( OAIL. Y ACTIVITY RllMMARY Predominantly tuffaceous claystone with some sandstone, and occasional coal beds, tuffaceous sllstone and volcanic ash. PRESENT LITHOLOGY 60% tuffaoeous olaystone, 20% sandstone, 10% tuffaoeous siltstone, 10% voloanlo ash. LITHOLOGY MWD SUMMARY INTERVAL TO TOOlS GAS SUMMARY(units) HIGH LOW AVERAGE , DITCH GAS 65 @ 7707 .3 @ 7584 14.8 TRIP GAS= 64u CUTTING GAS 0 @ 7953 0 @ 7953 0.0 WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= METHANE(C-1 ) 13027 @ 7707 542 @ 7928 2950.9 CONNECTION GAS HIGH= ;. ETHANE(C-2) 14 @ 7625 1 @ 7953 2.9 AVG= PROPANE(C-3) 11 @ 7770 1 @ 7882 1.2 CURRENT . BUTANE(C-4) 0 @ 7953 0 @ 7953 0.0 CURRENT BACKGROUND/AVG 12/17 PENTANE(C-5) 0 @ 7953 0 @ 7953 0.0 HYDROCARBON SHOWS None INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION iNTERVAL CONûiTION REASON TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED STC MDT285QYPX 7 x 10 7508 -1-15 11.98 In hole HIGH LOW AVERAGE CURRENT AVG 122.9 @ 7631 3.8 @ 7929 52.1 34.0 ftIhr 2929 @ 7698 284 @ 7929 2763.7 2797.4 amps 24 .@ 7929 0 @ 7584 5.9 1.2 Klbs 0 @ 7953 0 @ 7953 0.0 0 RPM 2186 @ 7797 1298 @ 7929 1770.3 1583 psi DEPTH: 79501 47 PV 8 YP 30 FL 7.5 Gels 18/23/25 CL- 29500 7.5 SD TR OIL 0 MBL 5.2 pH 9.6 Ca+ 80 CC! VERTICAL DEPTH 7535.71 INCLINATION 2.1 DEPTH 7678' AZIMUTH 340.5 SOL FC ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS BiT INFORiviA TiON NO. SIZE 7 -1.75 x 6.125 GURVEY DATA 24 Hour Footage 445 CASING :NrORMATION 95/8" @ 4336' PRESENT OPERATION- Drilling I::th~l::tù DEPTH 7953 YESTERDAY 7508 n EPOCH _ A .. " ~ A ._. . _....._ _____.... UJ-\IL T VVt:LL~111::: I"'\t:r-Ul"'\ I ABALONE #1 REPORT FOR Steven Lambe DATE F~u 22, 2003 TIME 24:00 VŸiiåcat ( MARATHON OIL COMPANY MARATHON OIL COMPANY .( Wildcat ABALONE #1 REPORT FOR Steven Lambe DATE Feb 21,2003 TIME 24:00 DAILY WELLSITE REPORT (;I EPOCH DEPTH 7508 YESTERDAY 7237 PRESENT OPERA TION= Trip for bit 24 Hour Footage 271 CASING INFORMATION 95/8" @ 4336' DEPTH 7448' SURVEY DATA BIT INFORMATION NO. SIZE 6 6.125" TYPE STC M50VYPX DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS Fe SOL ( MWD SUMMARY INTERVAL . TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY INCLINATION 1.9 AZIMUTH 327.9 VERTICAL DEPTH 7305.85' SIN JS9630 INTERVAL IN OUT 4370 7508 FOOTAGE 3138 CONDITION REASON HOURS T/B/C PULLED 68.50 Not avail Low ROP AVERAGE CURRENT AVG 31.7 7.4 ftlh r 2774.0 2081.5 amps 6.3 10.5 Klbs 0.0 0 RPM 1660.1 1442 psi JETS 6x10 46 7.5 PV SD HIGH 110.7 @ 7254 3194 @ 7348 13 @ 7425 o @ 7508 1951 @ 7410 DEPTH: 7508 10 YP TR OIL eel LOW 4.0 @ 7437 2081 @ 7508 0 @ 7247 0 @ 7508 1273 @ 7473 27 o FL MBl 7.6 5 Gels pH 18/22/25 9.9 CL- 30000 40 Ca+ HIGH LOW AVERAGE 45 @ 7466 3 @ 7508 17.6 TRIP GAS= 0 @ 7508 0 @ 7508 0.0 WIPER GAS= 22u CHROMA TOGRAPHY(ppm) SURVEY= 8995 @ 7468 610 @ 7508 3322.0 CONNECTION GAS HIGH= 30 @ 7323 1 @ 7491 3.5 AVG= 17 @ 7313 1 @ 7477 1.3 CURRENT 0 @ 7508 0 @ 7508 0.0 CURRENT BACKGROUND/AVG 0/12 0 @ 7508 0 @ 7508 0.0 None LlTHOLOGY/REMARKS GAS DESCRIPTION Comglomeritic sandstone, tuffaceous claystone, with occasional tuffaceous siltstone, volcanic ash, and carbonaceous shale. 70% Sandstone, 20% tuffaceous siltston.e, and 10% volcanic ash. OAII.Y ACTIVITY Circulate and condition hole @ 240 spm and 1400 psi. POOH to 6677', RIH to 7230', Orill from'iTi30'oIfo 7508', caw, SUMMARY POOH. Pull wear ring. Epoch Personel On Board= 4 Daily Cost $2694.00 Report by: Peter Dykema ( file:/ /C:\Abalone 1 \20030221,htm 2/22/03 uauy KepOn MARATHON OIL COMPANY ( Wildcat ABALONE #1 REPORT FOR Steven Lambe DATE Feb 20,2003 TIME 24:00 DAILY WELLSITE REPORT g EPOCH DEPTH 7237 YESTERDAY 6352 PRESENT OPERATION=Wlper Trip 24 Hour Footage 885 CASING INFORMATION 95/8" @ 4336' DEPTH 7178' SURVEY OAT A BIT INFORMATION NO. SIZE 6 6.125" INCLINATION 1.2 VERTICAL DEPTH 7035.94 AZIMUTH 325.0 SIN JS9630 INTERVAL IN OUT 4370' HOURS 54.83 CONDITION T IB/C REASON PULLED In hole FOOTAGE 2867 TYPE STC M50VYPX JETS 6x10 ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS Fe 1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE{C-1) ETHANE{C-2) PROPANE{C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH 191.5 @ 6870 3136 @ 7218 12 @ 6552 0 @ 7237 1950 @ 7179 DEPTH: 7230' 46 PV 9 YP 7.5 SD TR OIL LOW 6.0 @ 6889 1635 @ 7052 1 @ 7200 0 @ 7237 1119 @ 6678 ftIhr amps Klbs RPM psi AVERAGE 64.9 2744.2 6.2 0.0 1618.4 CURRENT AVG 88.4 2973.1 6.7 o 1684 27 FL 7.6 Gels o MBL 5 pH 18/24/28 9.8 CL- 30000 40 Ca+ eel HIGH LOW AVERAGE 80 @ 6517 6 @ 6698 26.4 TRIP GAS= 0 @ 7237 0 @ 7237 0.0 WIPER GAS= 13u CHROMA TOGRAPHY{ppm) SURVEY= 16613 @ 6517 1346 @ 6698 5034.5 CONNECTION GAS HIGH= 18u 28 @ 7137 1 @ 7156 3.7 AVG= 17u 16 @ 7190 1 @ 7236 0.7 CURRENT 0 @ 7237 0 @ 7237 0.0 CURRENT BACKGROUND/AVG 24/21 0 @ 7237 0 @ 7237 0.0 None LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major tuffaceous claystone. Minor ashy sandstone, tuffaceous siltstone, volcanic ash, and coal/carbonaceous shale. PRESENT LITHOLOGY 60% Congloneritic sandstone, 30% tuffaceous claystone, 10% carbonaceous shale. DAILY ACTIVITY SUMMARY Drilled 6307i'tb 6677'. Circulate and condition mud. POOH to 5934'. RIH to 6677. Drilled from 6677' to"f286\ .,.',\ Epoch Personel On Board= 4 Daily Cost $2694.00 Report by: Peter Dykema ( ~. ",..., \ A 1. _1 _.~ _1 \ "'f\i),,}iV''''/) .....,.ft"t 2/21/03 ·. J MARATHON OIL COMPANY ( Wildcat ABALONE #1 REPORT FOR Steven Lambe DATE Feb 19, 2003 TIME 24:00 DAILY WELLSITE REPORT U'EPOCH DEPTH~52~';· YESTERDAY 5558 PRESENT OPERATION= Drilling ahead 24 Hour Footage 794 CASING INFORMATION 95/8" @ 4336' DEPTH 6245' SURVEY DATA BIT INFORMATION NO. SIZE 6 6.125" INCLINATION 0.4 AZIMUTH 88.8 VERTICAL DEPTH 6103.05 TYPE STC M50VYPX SIN JS9630 JETS 6x10 INTERVAL IN OUT 4370' HOURS 38.04 ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,6 VIS Fe 1 SOL MWD SUMMARY INTERVAL TO TOOLS . GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT ANE(C-5) HYDROCARBON SHOWS INTERVAL CONDITION T/B/C REASON PULLED In hole FOOTAGE 1982 HIGH 188.3 @ 5888 2797 @ 6306 15 @ 6305 0 @ 6352 1877 @ 5976 DEPTH: 6345' 47 PV 8 YP 8 SD TR OIL LOW 10.0 @ 5695 2040 @ 5680 0 @ 5619 0 @ 6352 1190 @ 5680 ftlh r amps Klbs RPM psi AVERAGE 68.4 2525.2 5.7 0.0 1534.4 CURRENT AVG 63.4 2672.8 6.8 o 1636 29 FL 7.8 Gels o MBL 5.5 pH 18/24/26 9.5 CL- 31000 40 Ca+ CCI HIGH LOW AVERAGE 52 @ 5948 2 @ 5789 18.8 TRIP GAS= 0 @ 6352 0 @ 6352 0.0 WIPER GAS= 14u CHROMA TOGRAPHY(ppm) SURVEY= 10611 @ 5948 520 @ 5789 3594.9 CONNECTION GAS HIGH= 13 @ 6936 1 @ 6333 1.0 AVG= 0 @ 6352 0 @ 6352 0.0 CURRENT 0 @ 6352 0 @ 6352 0.0 CURRENT BACKGROUND/AVG 21/17 0 @ 6352 0 @ 6352 0.0 None LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major tuffaceous claystone. Minor tuffaceous siltstone, sandstone, coal carbonaceous shale, volcanic ash. PRESENT LITHOLOGY Tuffaceous claystone DAIL Y ACTIVITY Drllleð'~545rto 5934', CBU 3 times. POOH to shoe. Rig repairs (replaced top drive compensat()r cylinder, replaced link tilt and SUMMARY elevator switches; rebuilt #1 pump valve; rig service). RIH smooth. Drilled ahead from 5934' to~S45~"8t midnight. Rigging up solids van for additional solids control at midnight. Epoch Personel On Board= 4 Dally Cost $2694.00 Report by: Peter Dykema ( file://C:\Abalone 1 \20030220.htm 2/20/03 uallY.K:epon ( MARATHON OIL COMPANY Wll.d.cat ABALONE #1 REPORT FOR Steven Lambe DATE Feb 18, 2003 TIME 24:00 DA1lY WEll-S1TE REPORT g EPOCH DEPTH 55"58 " YE·STERDAY 4709 PRESENT OPERATION= Drilling ahead 24 Hour Footage 849 · CASING INFORMATION 95/8" @ 4336' DEPTH 5558 SURVEY DATA BIT INFORMATION NO. SIZE 6 6.125" INCLINATION 0.5 AZIMUTH 59.6 SIN JS9630 INTERVAL IN OUT 4370 FOOTAGE 1188 HOURS 22.28 TYPE STC M50VYPX JETS 6x10 ( DRI LLl.NG, ,PARAMETERS . ..'-:'" IÞ'~\ ".... .' RÄTË 6F ÞENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM · PUMP PRESSURE DRILLING MUD REPORT MW 9.45 VIS Fe SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) · BUTANE{C-4} PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH 1'âf.2 @ 5Õõ1 2482 @ 4872 13 @ 5120 o @ 5558 1610 @ 5400 LOW 6.é @ 4817 1767 @ 4997 0 @ 5012 0 @ 5558 977 @ 5558 AVERAGE 60,6 2304.6 4.4 0.0 1344.2 VERTICAL DEPTH 5416,08 CONDITION T/B/C in hole REASON PULLED 47 PV 7.5 SD DEPTH: 5557' 10 YP 28 FL 7.0 Gels 0.25 OIL 0 MBL 5.5 pH 16/20/26 9.0 CURRENT AVG 27.8 2013.6 3.8 o 977 ftlhr amps KI~s RPM psi CL- 33800 40 eel Ca+ HIGH LOW AVERAGE 4~ @ 5465 2 @ 4915 16.5 fRIP-eAS:D 0 @ 5558 0 @ 5558 0.0 WIPER GAS= 46 CHROMA TOGRAPHY(ppm) SURVEY= 10118 @ 5465 520 @ 4915 3278.7 CONNECTION GAS HIGH= 10 @ 5483 1 @ 5495 1.0 "AVG= 0 @ 5558 0 @ 5558 0.0 CURRENT 0 @ 5558 i3 @ 5558 i3.i3 CURRENT BACK-GROUNOlAVG 11124 0 @ 5558 0 @ 5558 0.0 .£':1_.111"""1.\ /I. L_1__....1'",f\f\')f\")1 0 1-.+..,.. .None LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major tuffaceous claystone. Minor tuffaceous sllstone, sandstone, coal/carbonaceous shale, volcanic ash. PRESENT LITHOLOGY Tuffaceous claystone DAILY ACTIVITY Drill fro~iìj~() 4916'. POOH to shoe. Repair top drive washplpe. Ream 4367' to 4916'. Drill from 4916' to 5430'. CBU, SUMMARY short trip to 4380'. RIH, drill 5430' to~ß\~J Epoch Personal On Board= 4 Dally Cost $2694.00 Rèport by: Peter Dykema ( 2/19/03 - --- J - - - c - . (~ MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR STEVE LAMBE DATE Feb 17, 2003 TIME 24:00 DAILY WELLSITE REPORT n EPOCH o .0. 1}.4° DEPTH 4709 ~ YESTERDAY 4370 PRESENT OPERATION= DRILLING 24 Hour Footage 339 CASING INFORMATION 95/8" @ 4336' DEPTH 4625 SURVEY DATA BIT INFORMATION NO. SIZE 6 6.125 TYPE STC M50VYPX ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROP ANE( C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL INCLINATION 0.9 VERTICAL DEPTH 4483.13 AZIMUTH 181.6 SIN JS9630 JETS 6x10 INTERVAL IN OUT 4370 CONDITION T IB/C In Hole REASON PULLED FOOTAGE 339 HOURS 4.61 HIGH 191.7 @ 2821 @ 9 @ @ 1444 @ LOW 4443 20.0 @ 4668 4521 1371 @ 4492 4679 1 @ 4548 @ 4447 1074 @ 4492 CURRENT AVG 40.7 2292.7 3.6 ftlhr amps Klbs RPM psi AVERAGE 88.4 2267.0 4.2 1281.0 1193 49 PV 7.5 SD DEPTH: 4798/4656 rvD 9 YP 25 FL 7.6 Gels 0.25 OIL 0 MBl 5.0 pH Ca+ 15/19/23 9.7 CL- 34000 120 CCI HIGH 53 @ @ 10644 @ 9 @ @ @ @ AVERAGE 27.1 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 12/22 LOW 4378 11 @ 4503 @ CHROMA TOGRAPHY(ppm) 4378 2344 @ 4503 4609 0 @ @ @ @ 5417.4 3.0 None to remark on. Highest gas Is only 53 units. No "clean" sands In this report interval. LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Claystone, Sand/Sandstone. Minor Tuffaceous Siltstone, Coal/Carbonaceous Shale, Volcanic Ash. PRESENT LITHOLOGY ..........TUFFACEOUS CLAySTONE.......... DAIL Y ACTIVITY POOH. Pick up and make up BHA #7. Program, orient and test MWD tool. RIH to 4336'. Clean pill pit and trip tank. Hold PJSM SUMMARY on displacement procedures. Displace well (at1.~Ospm and 800psi). Mix and pump dry job. Blow down mud lines. POOH. Change bit. RIH to shoe. Service rig. Drill fro~'~a7,o.~r,to 4709' (report depth) and continue to drill ahead. ",.+!"II' Epoch Personel On Board= 4 Dally Cost 2694 Report by: Craig Sliva ( fi1e://C:\Abalonel\20030217,htm 2/18/03 J,J....J..J..J .......'WtI"..... ( MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR GENE ANDERSON DATE Feb 16, 2003 TIME 24:00 DAILY WELLSITE REPORT n EPOCH DEPTH 4370 YESTERDAY 4350 PRESENT OPERATION= PULLING OUT OF HOLE CASING INFORMATION 95/8" @4336' 24 Hour Footage 20 SURVEY DATA BIT INFORMATION NO. SIZE TYPE 5 8.5 STC MS681 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.85 VIS 53 ( FC 3 SOL 7.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL DEPTH INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED ER6059 3x16 4350 4370 20 2.05 Not Graded Drill 6 1/8 hole HIGH LOW AVERAGE CURRENT AVG 30.3 @ 4360 3.6 @ 4370 10.3 3.6 ftIhr 2057 @ 4361 1837 @ 4360 2092.4 1985.8 amps 9 @ 4369 3 @ 4352 7.6 9.6 Klbs @ @ RPM 652 @ 4361 474 @ 4355 621.9 620 psi DEPTH: 4370 I 4228 rvD PV 12 YP 25 FL 12.6 Gels 11/23/27 CL- 28500 SD 0.5 OIL 1.0 MBL 10.0 pH 11.7 Ca+ CCI HIGH LOW AVERAGE 30 @ 4360 4 @ 4354 15.0 TRIP GAS= @ @ WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 6056 @ 4360 877 @ 4354 3003.8 CONNECTION GAS HIGH= @ @ AVG= @ @ CURRENT @ @ CURRENTBACKGROUND/AVG 4/15 @ @ NONE LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone. Minor CoallCarbonceous Shale, Tuffaceous Siltstone, Volcanic Ash PRESENT LITHOLOGY .......... TUFFACEOUS CLAYSTONE... ...... . SAND/SANDSTONE. .... ..... COAUCARBONACEOUS SHALE.......... Pick up and stand back 31 stands of HT -38 4" drill pipe. Rack, strap a~d tally BHA #6. Strap and tally 100 joints 4" HT -38 drill pipe. Pick liP, make up and RIH BHA #6. Pick up, make up and RIH with 4" drill pipe. Rig lip and test 9 5/8" casing (to 3350psi for 30 minutes). Drill out float collar at 4250'. Wash to 4336'. Drill out shoe. Wash to 4350'. Drill from 4350' to\43'1D'~\CBU. Perform Leak Off Test (16.3 EMW). POOH. Epoch Personel On Board= 4 Daily Cost 2694 Report by: Craig Silva DAILY ACTIVITY SUMMARY ( F;lø'//("I,\ Å h~1l\np.l \?OOiO?l lí.htm 2/17/03 uauy Kepon: [ MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR GENE ANDERSON DATE Feb 15, 2003 TIME 24:00 CASING INFORMATION 95/8" @ 4336' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 4 12.25 STC-FGXIVC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 VIS 54 FC 3 SOL 5 ( MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS 2 CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY NIA PRESENT LITHOLOGY NIA rage 1 01 1 DAILY WELLSITE REPORT n FJPOCH DEPTH 4350 YESTERDAY 4350 PRESENT OPERATION= Picking up 4" drill pipe 24 Hour Footage 0 DEPTH INCLINATION AZIMUTH INTERVAL SIN JETS IN OUT FOOTAGE HOURS MM327 3X18, 1X12 3900 4350 450 11.18 VERTICAL DEPTH CONDITION T IB/C 2-2-A-E-1-NO- TO REASON PULLED Casing Point HIGH @ @ @ @ @ AVERAGE CURRENT AVG LOW @ @ @ @ @ fl:/h r amps Klbs RPM psi PV SD DEPTH: 4350' 16 YP 22 0.5 Oil 1/94 CCI Gels pH 11/22/29 8.5 CL- 28500 320 FL 10 MBL 12.5 Ca+ HIGH @ 4350 0 @ LOW AVERAGE o TRIP GAS= 5u @ 0205hrs WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUN~AVG @ @ @ @ @ @ 4350 @ CHROMA TOGRAPHY(ppm) @ @ @ @ @ NIA LITHOLOGY/REMARKS GAS DESCRIPTION Run 9 5/8" O5g. (40 Ibs/ft l80). MIU hanger & land. 216K high, 135K low. Circulate & condition mud, 200 spm @ 884 psI. PJSM W/BJ. Pump 2 bbls H20. Test lines to 3000 psi. Drop Plug. Mix & pump pre slush, 40 bbls @ 10 ppg. Mix & pump lead cmt, 60 bbls @ 12 ppg.Mlx & pump tail cmt, 180 bbls @ 13.5 ppg. Drop plug. Displace W rig. Bump plug 500 psi over. Check floats. Rig down cmt equipment. C/O bails on TD. Blow down mud lines. Fold up stabbing boards. Hang tongs. Change liners in No. 1 pump. R/U & ¡nstall9 5/8 X 13 3/8 packoff. Test to 5000 psI. Pull riser & repair. BD running low. Install variable pipe rams & riser. RlU to test BOPs. Test all BOPs to 250/3500 psI. Test Koomey. RID test equipment. Set wear ring. RIH & UD 5" HW DP. Rack DP. Service rig. C/O Dennison drive line. PIU 4" DP. Epoch Personel On Board= 2 Dally Cost 1709 Report by: John Lundy DAILY ACTIVITY SUMMARY ( ~1 IIr"'o.\ .1..1... .1'''''''''''''''''''1'''' 1..... "" /1. 4': fA."" ( MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR GENE ANDERSON DATE Feb 15, 2003 TIME 24:00 CASING INFORMATION 133/8" @ 2210' SURVEY DATA DEPTH INCLINATION AZIMUTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 4 12.25 STC-FGXIVC MM327 3X18, 1X12 3900 4350 450 11.18 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 @82f VIS FC 2 SOL ( MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(unlts) DITCH GAS CUTTING GAS M ETHAN E(C-1 } ETHANE(C-2) PROPANE(C-3} BUTANE(C-4) PENT ANE(C-5) HYDROCARBON SHOWS INTERVAL 54 PV 5 SO DAILY WELLSITE REPORT g EPOCH DEPTH 4350 YESTERDA Y4350 PRESENT OPERATION= RUNNING 9 5/8" CASING 24 Hour Footage 0 VERTICAL DEPTH CONDITION TIBIC 2-2-A-E-1-NO- TO REASON PULLED Casing Point HIGH @ @ @ @ @ DEPTH: 4350' 14 YP 0.5 OIL LOW @ @ @ @ @ AVERAGE CURRENT AVG ftlh r amps Klbs RPM psi 7.6 10 26 1/94 FL MBl Gels pH 13/14/27 8.5 CL- 29000 400 Ca+ eel . LOW @ 4360 0 @ 4350 @ @ CHROMA TOGRAPHY(ppm) @ @ @ @ @ I.Ä.. HIGH AVERAGE o @ @ @ @ @ TRIP GAS= 320'@0815 hrs WIPER GAS= SURVEY= CONNECTION. GAS HIGH= AVG= CURRENT CURRENTBACKGROUND/AVG llTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NIA PRESENT LITHOLOGY N/A DAILY ACTIVITY RID SWS. PIU & MIU BHA#5. RIH W 4" HT38 DP. Fill pipe. Wash & ream 4272 to 4310. Tag fill @ 4347. CIO, C/4350. SUMMARY Circulate & condition mud. Mix and pump dry job. POOH. UD BHA. Install 9 5/8" csg rams & test door seals, 250/3000 psi. Pull down wear ring. . RIU to run csg. PJSM & run 9 5/8" csg. Break circulation at shoe. Epoch Personel On Board= 3 Daily Cost 2269 . Report by: John Lundy ( ¡ , ~ ( I' \ " f , " / ., "'/,(.. ,", '-\ 1...1. ... ./." 1.( .:".. ... J / ~'.' ...- ';, /'''',' ., I ï ,~') kt.-,- \".') i . . \. , .J file://C:\Abalone 1 \20030212,htm 2/15/03 ( MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR GENE ANDERSON DATE Feb 13, 2003 TIME 24:00 DAILY WELLSITE REPORT g EPOCH DEPTH 4350 YESTERDAY 4350 PRESENT OPERATION= WIRELlNE LOGGING SURVEY DATA CASING INFORMATION 133/8" @2210' 24 Hour Footage 0 BIT INFORMATION NO. SIZE TYPE 4 12.25 STC FGXIVC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.45 VIS FC 2 SOL ( MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY NIA PRESENT LITHOLOGY N/A .,' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS TlB/C PULLED MM3272 3x18, 1x12 3900 4350 450 11.18 2-2-A-E-1-NO- TD Casing point HIGH lOW AVERAGE CURRENT AVG @ @ NIA ftIhr @ @ N/A amps @ @ N/A Klbs @ @ NIA RPM @ @ NIA psi DEPTH: 4350 I 4208 rvD 48 PV 11 YP 26 FL 8.8 Gels 1/23/26 CL- 28000 4.0 SD 0.25 OIL 1 MBl 7.5 pH 8.5 Ca+ 400 CCI HIGH LOW AVERAGE 60 @ 4350 6 @ 4350 16 @ @ CHROMA TOGRAPHY(ppm) TRIP GAS= WIPER GAS= 46 SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG N/A @ @ @ @ @ @ @ @ @ @ NIA LlTHOlOGY/REMARKS GAS DESCRIPTION Circulate hole clean and condition. Back ream from 4221' to 2848'. (Mud weight Increased from 9.35ppg to 9.6ppg during backreaming). POOH to shoe. Service rig. RIH (tight from 4040' to 4273'). Fill pipe. Tag fill at 4339'. Wash and ream to 4350'. DAILY Circulate and condition mud. POOH (SlM). Break and lay down MWD tool, motor and bit. Hold PJSM for wlreline logging. Rig up ACTIVITY Schlumberger. Make up and pick up Platform Express logging tools for first run and RIH. Log up and POOH. Lay down and break SUMMARY down Platform Express. Make up and pick up DSllogglng tools for second run and RIH. Log up and POOH. lay down and break down DS!. While wlreline logging, installed 4" liners In #3 mud pump, Installed driller's console controls for the #3 mud pump, repaired the M-I Center Van and processed the mud In the pits (reducing the mud weight from 9.6ppg to 9.45ppg). Epoch Personel On Board= 4 Dally Cost 2349 Report by: Craig Silva ( file://C:\Abalone 1 \20030212,htm 2/14/03 - ---J ---r --- MARATHON OIL COMPANY ( TYONEK FIELD ABAlONE #1 REPORT FOR GENE ANDERSON DATE Feb 12, 2003 TIME 24:00 DAILY WELLSITE REPORT n EPOCH DEPTH 4350 YESTERDAY 3900 PRESENT OPERATION= CIRCULATING AND CONDITIONING CASING INFORMATION 133/8" @ 2210' 24 Hour Footage 450 SURVEY DATA BIT INFORMATION NO. SIZE TYPE 4 12.25 STC FGXIVC ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 VIS Fe 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) . BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 51 5.0 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3855 1.1 174.9 3713.30 4290 1.3 135.5 4148.19 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS TIBIC PUllED MM3272 3x18, 1x12 3900 4350 450 11.18 In Hole Casing point HIGH lOW AVERAGE CURRENT AVG 130.1 @ 3986 7.3 @ 4068 49.4 38.2 ftlhr 2489 @ 4234 1187 @ 3908 2298.4 2344.9 amps 28 @ 4280 1 @ 3901 18.4 28.0 Klbs @ @ RPM 1877 @ 40.93 1478 @ 4157 1752.2 1780 pßi DEPTH: 4350 14208 rvD PV 11 YP 28 FL 8.5 Gels 13/23/29 Cl- 26000 SD 0.25 Oil 1.0 MBl 8.0 pH 8.5 Ca+ 400 eel HIGH 228 @ @ lOW AVERAGE 42.5 TRIP GAS= 42 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 13 124 44798 27 4117 10 @ 3907 @ CHROMATOGRAPHY(ppm} @ 4117 2113 @ 3907 @ 4117 1 @ 4321 @ @ @ @ @ @ 8271.7 5.6 NONE lITHOlOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone. Minor Tuffaceous Siltstone, Volcanic Ash, Tuffaceous Shale. PRESENT LITHOLOGY ..........SAND/SANDSTONE..........TUFFACEOUS CLAySTONE.......... DAILY ACTIVITY SUMMARY Repair Topdrive grabber. RIH to 3472'. Ream from 3472' to 3534'. Circulate and condition. Ream from 3534' to 3900'. Drill from 3900' to 4350'. Circulate and condition. ( Epoch Personel On Board= 4 Daily Cost 2269 Report by: Craig Silva fi1p.'//r:\Ah~1onp.l \20030212.htm 2/13/03 MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Feb 11, 2003 TIME 24:00 - -.-- eI ( DAILY WELLSITE REPORT g EPOCH DEPTH 3900 YESTERDAY 3477 PRESENT OPERATION= WORKING ON TOPDRIVE 24 Hour Footage 423 CASING INFORMATION 133/8" @ 2210' DEPTH 3417 3846 SURVEY DATA BIT INFORMATION NO. SIZE TYPE 3 12.25 STC FGXIVC 4 12.25 STC FGXIVC ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.25 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE( C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL INCLINATION 1.1 1.1 AZIMUTH 143.3 171.4 VERTICAL DEPTH 3275;36 3704.31 INTERVAL SIN JETS IN OUT FOOTAGE HOURS MM3664 3x18. 1x12 2210 3900 1690 32.58 MM3272 3x18,1x12 3900 CONDITION T/B/C 2-2-WT -A-E-1-SD-PR In Hole REASON PULLED Bit stopped drilling HIGH LOW AVERAGE CURRENT AVG 130.4 @ 3720 6.1 @ 3897 45.6 69.0 ftIhr 3581 @ 3480 1448 @ 3847 2424.4 2116.2 amps 33 @ 3652 5 @ 3784 19.5 30.2 Klbs @ @ RPM 1777 @ 3792 1424 @ 3506 1599.9 1617 psi DEPTH: 3900 I 3759. TVD 46 PV 11 YP 24 FL 8.4 Gels 16120/24 CL- 28000 4.0 SD 0.5 OIL 0.5 MBL 10.0 pH 9.0 Ca+ 60 CCI HIGH LOW 156 @ 3786 16 @ 3782 @ @ CHROMA TOGRAPHY(ppm) @ 3788 3186 @ 3782 @ 3786 @ @ @ @ @ @ @ AVERAGE 38.3 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH::: AVG= CURRENT CURRENT BACKGROUND/AVG 161 32 31328 19 7665.4 1.7 NONE LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone. Minor Tuffaceous Siltstone. Volcanic Ash. Tuffaceous Shale, Coal. PRESENT LITHOLOGY ..........SAND/SANDSTONE..........TUFFACEOUS CLAySTONE.......... DAILY ACTIVITY Drill from 3477' to 3346'. Circulate and condition hole. POOH. Backream to 3410'. Circulate hole clean at 3410'. POOH. SUMMARY Change out bits. RIH to shoe at 2206'. Service rig. Work on Topdrive grabber dies. Epoch Personel On Board= 4 Dally Cost 2269 Report by: Craig Silva ( ñle'//C:\Abalonel\20030211.htm 2/12/03 Ui1UY 1'..t::pun MARATHON OIL COMPANY (' ~age 1 01 1 DAILY WELLSITE REPORT g EPOCH DEPTH 3477 YESTEROA Y. 2~T4 PRESENT OPERATION= DRILLING CASING INFORMATION 133/8" @ 2210' 24 Hour Footage 703 TYONEK FIELD ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Feb 10, 2003 TIME 24:00· ðEP"fH tNCUI'lA "ft01'l AZIMUTH SURVEY DATA 2731 10.6 187.9 33S6 1.0 154.9 BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 3 12.25 STC FGXIVC MM3664 3x18, 1x12 2210 1262 21.32 DRILLING PARAMETERS HIGH LOW AVERAGE · RATE OF PENETRATION 30·9.6 ~ 3173 3.6 ~ 3089 75.7 SURFACE TORQUE 3594 @ 3438 268 @ 3034 1877.6 WEIGHT ON·BtT ~e @ ~OM 1 @ 2Sð8 12:8 ROTARY RPM @ @ , PUMp· PRESSURE 1694 @ 3319 1016 @ 2-848 14OO.S ( DRILLING MUD REPORT MW 9.35 VIS Fe 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DlTOH GAS CUTTING GAS METHANE(C~1 ) · ÊfHANÊ{e~2) PROPANE(C~3) · BUT ANE(C-4} PENTANE(C~5) · HYDROCARBON SHOWS INTERVAL VeR'f1CAI:. ðEP"fH' 2592.02 32·14.37 CONDITION T/B/C In Hole REASON PULLED CURRENT AVG 33.6 3379.5 16:1' ftIl1 r amps Ktbs RPM pst 1494 DEPTH: 3558/3416 rvD 49 PV 11 yp 27 FL 9.0 Gels 1èl2~126 tL~ ~4000 5.0 SD 0.5 OIL 0.5 MBL 3.0 ~~, 9.2 Ca+ 80 . .. ·Cg.V· \ .I-y.t.. ...-. ~y\:~~~'~' ' ...~""'" HIGH LOW AVERAGE 505 @ 3179 18 @ 3033 87.3 TRt? 'GAS" @ @ WIPER GAS= 30 CHROMATOGRAPHY(ppm) SURVEY= 100603 @ 3179 3613 @ 3033 17385.4 CONNECTION GAS HIGH= @ @ 'ÂV6= @ @ CURRENT @ @ CURRENT BACKGROUNDlAV-G 22 ¡. 35 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone. Minor Volcanic Ash, Tufffaceous Siltstone, Conglomeratic Sand/Conglomerate, Tuffaceous Shale, Argillaceous Claystone, Coal. ........ ..SAND/SANDSTONE.......... TUFFACEOUS CLAySTONE.......... õÁ,L Ÿ Áéfi\¡,tv Drill from 2774' to 3346'. Circulate- and condition hole for wiper trip. POOH to shoe- at 2206'. Shut in wen for &lectrica. SUMMARY Installation. Install additional breaker in generator hòuse, for the new pump house. Service rig. RIH. Drill from 3346' to 3477' (report depth) and continue to drill ahead. ( Epoch Personel On Board= 4 Daily Cost 2269 Report by: Craig Sliva .C':.1_.1II""I.\ AL_1_.__1\"\^^~^"\1^ 1....... -. ... .. ..... .... .1J'Q.1.l.y L'\..'-'l^'I.... MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Feb 09, 2003 TIME 24:00 ( DAILY WELLSITE REPORT g EPOCH CASING INFORMATION 133/8" @ 2210' DEPTH 2231 2482 2669 SURVEY DATA BIT INFORMATION NO. SIZE 3 12.25 TYPE STC FGXIVC ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS FC 1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE{C-1 ) ETHANE{C-2) PROPANE{C-3) BUTANE{C-4) PENTANE{C-5) HYDROCARBON SHOWS INTERVAL SIN MM3664 80 3.5 PV SD DEPTH 2774 YESTERDAY 2210 24 Hour Footage 564 292.0 3181 34 INCLINATION 23.9 19.2 12.6 INTERVAL JETS IN OUT 3x18, 1x12 2210 HIGH LOW @ 2464 19.3 @ @ 2406 1114 @ @ 2619 0.5 @ @ @ @ 2627 541 @ PRESENT OPERATION= DRILLING AZIMUTH 185.8 186.9 187.1 VERTICAL DEPTH 2118.72 2351.14 2531.29 1486 FOOTÀGE 564 CONDITION T/B/C In Hole REASON PULLED HOURS 7.10 2410 2477 2528 AVERAGE 108.7 1496.4 10.3 ftIhr amps Klbs RPM psi CURRENT AVG 45.4 2099.7 9.0 2211 1253 1109.7 DEPTH: 2764 12624 TVD 11 YP 32 FL 6.8' Gels 0.25 OIL 0 MBL 2.0 pH 18/24/27 9.5 CL- 28500 100 eCI Ca+ HIGH LOW AVERAGE 60 @ 2502 2 @ 2211 27.0 @ @ CHROMA TOGRAPHY{ppm) 12303 @ 2502 399 @ 2211 5376.1 @ @ @ @ @ @ @ @ NONE LITHOLOGY IRE MARKS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 21/31 GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone. Minor Volcanic Ash, Conglomeratic Sand/Conglomerate, Tuffaceous Siltstone, Tuffaceous Shale, Argillaceous Claystone, Argillaceous Shale. ......... . SAN DISANDSTONE. ......... TUFFACEOUS CLAySTONE......... .ARGILLACEOUS CLAySTONE.......... ( DAILY ACTIVITY SUMMARY Slip and cut drill line. Circulate and condition old mud. Rig up and test 13 3/8~' casing to 1500psl for 30 minutes. Circulate and clean out 13 3/8" casing. Tag top of float collar at 21631. Tag top of shoe at2206' and drill to 2209'. CBU. Do F.I.T to 11.0ppg. Clean pill pit. Displace well with 9.0ppg Flo-Pro mud after 10bbl water spacer. Send old ml,ld to tiger tank for disposal. Circulate and condition and build addtlonal volume. Drill new hole from 2209' to 2230'. CBU. Peform L.O.T. to 14.5 EMW. Change grabber dies. Drill from 2230' to 2774' (report depth) and continue to drill ahead. l::.1"..,/Ir'1,\ ^ 1-....1"",.0 1 \ ")()()':1 ()"){)Q htm 2/10/03 ( MARATHON OIL COMPANY TYONËK FiCËD ABALQ.N.ê·l~:1. REPORT FOR ROWLAND LAWSON DATE Feb 08,2003'- TIME 24:00 CASING INFORMATION r3'31äiï@2210' SURVEY DATA BIT INFORMATION NO. SIZE 9 12.25 TYPE STC FGXIVC DRILLING PARAMETERS RATE OF PENETRATION·'· SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.05 VIS 78 FC 1 SOL 3.0 ( MWQ ~~MMARY INTERVAL TOOLS l,;:' TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY N/A PRESENT LITHOLOGY NIA 1. 4ZSl;i .1 VJ. J. DAILY WELLSITE REPORT ~ EPOCH DEPTH 2210 YESTERDAY 2210 PRESENT OPERATION= SLIP AND CUT DRILL LINE 24 Hour Footage 0 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED MM3664 3x18, 1x12 2210 In Hole HIGH LOW AVERAGE CURRENT AVG @ @ ftIhr @ @ amps @ @ Klbs @ @ RPM @ @ psi DEPTH: 2210 /2100 TVD PV 9 YP 37 FL 6.2 Gels 22/29/31 CL- 31000 SD 0 OIL 0 MBL 0.0 pH 9.5 Ca+ 40 CCI HIGH AVERAGE LOW N/A @ NIA @ NIA @ @ CHROMA TOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ N/A LlTHOLOGY/RE~~RKS .'r'-, .I TRIP GAS= YYIP§R GAS= SURVEY= CONNECTION GAS HIGH= AVG= GU.RRENT CURRENT BACKGROUND/AVG N/A GAS DESCRIPTION Nipple up BOPE, riser, fill-up lines and trip tank chains. Tighten flanges and function test. Rig up test joint. Install test plug. Test all BOPE ( [12 choke valves] dart, floor check valve, 2 Topdrive valves, 2 kill valves, manual choke, HCR, top pipe rams, lower pipe ~~~~ITY rams, and bllnd,rams)to 250psl Lo/3000psl HI. Peform accumulator test. Pull test plug. Make up and land 9 5/8" hanger. Run wear SUMMARY bushing. Lay down casing tools. Change out bales. Change out stand pipe. Install brackets. Work on HeR control. Prep rig for M-I Unit and mud tank. Stage together BHA. Change out mud motors and stabilizers. Orient and Install MWD tool. RIH with HWDP. Rig up to pick up DP. Pick up, make up, rabbit, strap and torque 66 joints DP, and RIH to 2065'. Slip and cut drill line. . Epoch Personel On Board= 4 Dally Cost 2269 ( Report bÿ: CréïsfSilva \ file://C:\Abalone 1 \20030204.htm ..., 10/A") ....,....JLJLJ ...........yvl.... MARATHON OIL COMPANY ( ;-#-t;.... . ...:.,...r.'If""~~"""" TYONEK FIELD ABALONE..#..t:,,,.,·· ..- .. REPORT FOR ROWLAND LAWSON DATE FeD 07, 2Òô'3' TI~~~.QO. - ri1gc 1 Ui i DAILY WELLSITE REPORT g EPOCH ._~. DEPTH- 2210 YESTERDAY 2210 24 Hour Footage 0 -' .ç' 'SURVEY DATA CASING INFORMAtIÕÑ~"2'f)d'@":1"70' 133/8" @2161" INCLINATION BIT INFORMATION ..I''''~''''"''OC-'.''-_. NO. SIZE TYPE SIN 8 17.5 LK1029 3X18, ." .. . DRILLING PARAMETERS RATE OF PENETRÄfrö~r·'~'ì·'~·"'· SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE;..~~ì~\~·'>",:_· ( DRILLING MUD REPORT -<~: MW 9..0 VIS Not Listed FC SOL 3 I. .,.. '.'~'_.." ...,..., . MWD SUMMARY INTERVAL TO TOOLS "': GAS SUMMARY(unlts) DITCH GAS CUTTING GAs . ~ ~.I,~' , ..,..."....,.,':'~, " .. . ':" ;, .. . (. METHANE(C-1 ) ETHANE(~~2) . PROPANE(ë-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ..: ,.'.,\::., .·:,;.h\.......·..: ' ~.,~.',..,'...',.."'''''-'.....;.~,'.. DEPTH JETS 1X14 INTERVAL IN OUT 1007 2210 FOOTAGE 1203 PRESENT OPERATION= NIPPlING UP AZIMUTH VERTICAL DEPTH HIGH @ @ @ @ @ LOW @ @ @ @ @ HOURS 21.82 CONDITION T IB/C 2-2-WT -A-E-1-NO- TD REASON PULLED Casing point PV SD DEPTH: 2210' 9 YP 30 o OIL 0/97 AVERAGE CURRENT AVG HIGH LOW AVERAGE 2 @ 2210 0 @ 2210 0 @ @ CHROMA TOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ LlTHOLOGY/REMARKS ftIhr amps Klbs RPM psi FL 6.4 Gels MBL 0 pH 18/28/33 9.5 CL- 33000 20 Ca+ eCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND/AVG GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY N/A .., DAILY ACTIVITY Repair valve in pili pit. MIU CaCI2 for cement. Top job. Flush stack.Pull out and lay down 1 1/4 DP. RID small handling tools. SUMMARY N.ipp'l~ ~<?"Y!:!"di".ertepmd stack. Rough cut 13 3/~ and pull out, Set out diverter and stack in stand. Cut off surface pipe flange. Meke·fnal:.cuHn13·3/8. Set in slip on wellhead. Nipple up. Mix mud. Ep~c~ Personel On Board= 2 Daily Cost 1709 ." Report by: JOHN LUNDY c f11ø'//r"\ A h'=ll1n.....ø 1 \ ")()()~()")()A h~ ~ 1011"\"" (" MARATHON OIL COMPANY ;~~~'!I,-:-:~.- ·TYONEK FIELD . _,~t,. REPORT FOR ROWLAND LAWSON DAILY WELLSITE REPORT g EPOCH DATE Feb 06, 2003 TIME 24~OO· _ DEPTH 2210 YESTERDAY 2210 PRESENT OPERATION= WAITING ON CHEMICALS FOR MIXING CEMENT 24 Hour Footage 0 CASING INFORMATION 20" @170' 133/8" @ 2161' .; SURVEY DATA DEPTH INCUNATION AZIMUTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 8 17.5 srO-MSDGQL LK 1020 3X18, 1X14 1007 2210 1203 21.82 VERTICAl. DEPTH ·CONDITION TIBIC 2~2-WT-A.;;E-1-NO- TO REASON PULLED Ca$ing· point ( DRILLING PARAMETERS RATE OF PENETRATION· SURFACE TORQUE WEIGHT ON BIT . '"'".. ROTARY RPM PUMP PRESSURE··",,"~,mo:!':~"""-'·"·· . DRILLING MUD REPORT ''MW 9.4 - VIS 62 FC 2 . ._..,.~....;¡.;g8Þ..::.::.;:.::.....,~.~ MWD SUMMARY INTERYAl TO TOOLS HIGH @ @ @ @ @ LOW @ @ @ @ .@ ft/hr amps Klbs RPM psi AVERAGE CURRENT AVG PV SD DEPTH: 2210' 7 YP 28 0:25 Oil 0/91 Fl 11 Gels MBL 18 ·pH 3/8/9 9;0 Cl- 300 Ca+ 80 eCI . ... ~ ..~";;. ""'iÞ\",.cc. ... . GAS SUMMARY(units) '" DITCH GAS CUTTING GAS HIGH 7 @ 2210 @ lOW AVERAGE ,;" r'. M" ~:I~~~I.i..~;" :._. ".. ',' . . . @ 2210 @ CHROMATOGRAPHY(ppm) METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4)··'" PENTANE(C-5) HYDROCARBON SHOWS INTERVAL @ @ @ @ @ @ @ @ @ @ TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG LlTHOLOGY/REMARKS GAS DESCRIPTION . ",,", ..4. "."_ _~...... _ n,· DAILY ACTIVITY SUMMARY LITHOLOGY NIA PRESENT LITHOLOGY NIA Rig down csg equip. Chainge bails. Install DP elevators. Adj. and secure top drive track. Rig up to· RIH W/seal. M/U seal. M/U pup joint.RIH. POOH. Torque 13 stds. RIH. Tag landing collar @ 2161'. Circulate DP volume. + 40bbls. Set down 15K on seal. Make up cmt'ftlfà-a:Þump'25bbls spacer. Test cmt lines 2Kps10K. Pump·cmt 950 sx type 1 cmtwith 20% LW-6, 20% MPA-1, 1%CaCI2, 3% CD32, 1 % a-2 & 1 gal FP-6L. No Cmt returns to surface. Displace 3bbls H20 & drop plug. Displace 18 bbls with rig pump. RID cmt head after checking floats. Pump WOl DP & POOH with 4" DP. load out CMT equipment. CIO bailes and elevators. Remove spider and run 1 1/4" pipe to 350' outside 13 3/8" csg for top job. Rlu to cmt PJSM. Pressure test lines to 2Kpsi, OK. Repair valve In Pill Pit. ( Epoch Personal On -Board=·2 Daily Cost 1709 Report by: John Lundy . . file://C:\Abalonel \Morning Reports\20030206.htm 2/8/03 ·_..".¡:.;.:...:..,:_;...,:;.·....,L:.. .;~~.,~~~~; -' ...",,~, '.' "'J..' ...',.. (' MARATHON OIL COMPANY TYONEK FIELD ABALON,~~1 REPORT FOR ROWLAND LAWSON DATE Feb 05, 2003-" TIME 24:00 CASING INFORMATION 20" @ 170' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 8 17.5 STC MSDGQL ( DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC 2 SOL MWD sUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT ANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY NIA PRESENT LITHOLOGY NIA SIN LK1029 62 6.0 HIGH 3 @ @ DAILY WELLSITE REPORT .6 EPOCH DEPTH 2210 YESTERDAY 2210 PRESENT OPERATION= LAND CASING 24 Hour Footage 0 DEPTH 2158 INCLINATION 24.0 AZIMUTH 168.0 VERTICAL DEPTH 2052.01 INTERVAL JETS IN OUT 3x18, 1x14 1007 2210 CONDITION T/B/C 2-2-WT -A-E-1-NO- TD REASON PULLED Casing point FOOTAGE 1203 HOURS 21.82 HIGH @ @ @ @ @ LOW @ @ @ @ @ 'AVERAGE CURRENT AVG ftIh r amps Klbs RPM pSI PV SD DEPTH: 2210 12100 TVD 15 YP 19 FL 10.2 Gels 0.75 OIL 0 MBL 23.0 pH CL- 300 Ca+ 40 eel 6/14/18 6.5 LOW @ 2210 @ CHROMATOGRAPHY(ppm) AVERAGE 2210 2 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG NIA @ @ @ @ @ @ @ @ @ @ NIA lITHOLOGY/REMARKS DESCRIPTION GAS Mix and pump LCM pill at 1816'. Monitor fluid loss. Pull tv./o stands to 1692'. Mix mud and pump LCM pilI. Monitor fluid loss. Mix and pump LCM pill at 1660'. Monitor fluid loss. Loss down to 2 bbls/hr. POOH slow. Handle BHA. Clean stabilizers and bit. Lay down string stabilizer. Break off bit. Stand back MCS motor. Clear floor of 17.5" tools. Remove drill pipe elevators and bails. Rig up to run 13 3/8" casing. Adjust torque tube. Rig up stabbing board. Rig up Weatherford. Hold PJSM for running casing. Make up float equipment. Break circulation. Check floats. RIH with 133/8" casing to 1110', Break circulation. Continue RIH to 2210'. Remove bell guide from elevator. Remove casing spyder. Land casing. Epoch Personel On Board= 2 Daily Cost 1709 Report by: Craig Silva DAILY ACTIVITY SUMMARY ( file://C:\Abalonel \20030204,htm 2/6/03 ually KepOn ( MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Feb 04, 2003 TIME 24:00 CASING INFORMA110N 20" @ 170i SURVEY DATA BIT INFORMATION NO. stZE 8 17.5 TYPE STC MSDGQL ( DRILLING PARAMETERS RATE Qf..P'I;NI;.,TRAIION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS Fe 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS 8UMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(è-5) . . HYDROCARBON SHOWS INTERVAL LITHOLOGY N/A PRESENT LITHOLOGY NIA r U!;Ç i Vi k DAILY WELLSITE REPORT [:I EPOCH DEPTH 2210 YESTEROA Y 1965 PRESENT OPERATION= Spotting LCM pills before POOH 24 Hour Footage 245 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1982 24.8 186.7 1891.61 2158 24.0 188.0 2052.01 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED lK1029 3x18, 1x14 1007 2210 1203 21.82 In Hole Casing point HIGH LOW AVERAGE CURRENT AVG 226.2 @ 1984 10.2 @ 2104 82.4 69.0 ftIhr 2599 @ 2026 260 @ 2100 2194.5 2339.1 amps 18 @ 2043 2 @ 2199 9.6 6.1 Klbs @ @ RPM 1961 @ 2141 1446 @ 2193 1833.1 1548 psi 60 5.5 DEPTH: 2210/2100 TVD 15 YP 22 FL 10.0 Gels 0.5 Oil 0 MBl 22.0 pH CL- 300 Ca+ 40 eel 8/18/22 9.0 PV SO HIGH LOW 89 @ 2071 26 @ 2109 @ @ CHROMA TOGRAPHY(ppm) 17917 @ 2071 5650 @ 2109 @ @ @ @ @ @ @ @ AVERAGE 57.7 TRIP GAS= 23 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 30 162 11530.5 NONE LlTHOlOGY/REMARKS GAS DESCRIPTION Drill 17.5"hölefrom 1965' to 2110'. Repair #2 charge pump suction screen. Drill from 2110' to 2210'. Circulate and condition mud and hole. Monitor well. Pump and spot LCM pill. Pull to 2008'. Monitor well. Pump and spot LCM pill. Pull to 1790'. Hole tight. Ream out from 1816' to 1754'. Spot 40bbl LCM pill at 1630'. POOH. Strap pipe on way out. Lay down MWO tool and hang off sub. Clean stabilizers and bit. Monitor well. Service rig. RIH to 2130'. Wash and ream from 2130' to 2210'. Circulate and condition mud and hole. Spot 40bbl lCM pill on bottom. Pull up to 2000', Spot 40bbl LCM pill. Pull to 1816'. Mix and pump 40bbl LCM pill. Continued ..,!,i.~.lJr losses at report time. Epoch Personel On Board= 2 Daily Cost 1709 Rep?rt by: Craig Silva DAILY ACTIVITY SUMMARY ( '/~'...... 11 ..., ^^^^^^^ AI t . " I~ I^", -...- - - . ( MARATHON OIL COMPANY TYONEK FIELD DAILY WELLSITE REPORT g EPOCH ,ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Feb 03, 2003 TIME 24:00 DEPTH 1965 YESTERDAY 1387 PRESENT OPERATION= DRILLING TRIP GAS= WIPER GAS= 34 .$VRVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 30/38 24 Hour Footage 578 CASING INFORMATION 20" @ 170' DEPTH INCLINATION AZIMUTH 1386 26.0 185.5 SURVEY DATA 1576 27.6 193.0 1952 25.0 188.2 BIT ··NFORMA:rIGN "INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 8 17.5 STC MSDGQL LK1029 3x18, 1x14 1007 958 17.36 DRILLING ·PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 21.1.0 @ ,1471 1 :4..8 .@ 1,87,9 8~.2 @ ¡" SURFACE TORQUE 2510 1624 255 @ 1788 . '1545.1 WEIGHT ON BIT 46, @ 179.5. 2 @ 18.16. 16.5. ROTARY RPM @ @ PUMP PRESSURE 1861 @ 1961 581 @ 1753 1671.0 DRILLING MUD REPORT DEPTH: 1950 11863 TVD ( 55 PV 6.0 SD 15 0.25 YP 21 FL 10.0 Gels OIL 0 MBL 22.0 pH MW Fe 9..25 2 VIS SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(unlts) OITGti. GA~ CUTTING GAS HIGH AVERAGE 24.7 LOW 62 @ 1893 @ 1765 @ @ CHROMA TOGRAPHY(ppm) @ 1893 315 @ 1765 @ @ @ @ @ @ @ @ 4910.7 METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 12414 NONE LlTHOLOGY/REMARKS GAS LITHOLOGY N/A PRESENT LITHOLOGY N/A ~ -0- ~ ....~- VERTICAL DEPTH 1356.43 1525.98 1864.40 OONDIT~0N TIBIC In Hole ,REASON PULLED CURRENT AVG 51.1 2252.0 12.1 ftIhr amps Klbs RPM psi 1811 8/20/23 9.5 CL- 300 Ca+ 20 eCI DESCRIPTION Drill from 1387' to 1752'. Note small fluid loss at 1752'. Circulate slow. Change packing on rod oiler of mud pump #2. Change shaker screens. Drill from 1752' to 1765'. Note increased mud losses at 1765'. Mix, pump and spot 40bbl LCM pill (20ppb ß.e'øp~rb M). P.I,IJJ ;3 .$tfm.~$ to ~,f$.3,O·. M,QnJtQr w,~JJ. MJ>.c, pµmp ~,d .!?p,ot 4:,QbbJ lGM piJJ O,Qppb.S.$f.~C.erb F,.~.QpPb.~ef.~C,wb M). CBU three times. Work pipe from 1568' to 1630'. Do wiper trip to 885'. RIH. Drill from 1765' to 1965' (report depth) and continue to drill ahead. Epoch Personel On Board= 2 Daily Cost 1709 Report· by: Craig Silva DAILY , ACTJVJTY SUMMARY ( . file:/fC:\Aha.1rme 1 \20010201. htm ") I t1 /0 '" MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Feb 02, 2003 TIME 24:00 ( CASING INFORMATION 20" @ 170' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 7 17.5 STC DSJC 8 17.5 STC MSDGQL DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT ( MW 9.3 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE{C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY NIA PRESENT LITHOLOGY N/A DAILY WELLSITE REPORT g EPOCH DEPTH 1387 YESTERDAY 867 PRESENT OPERATION= DRILLING 24 Hour Footage 520 DEPTH 767 1326 INCLINATION 7.7 24.8 AZIMUTH 189.1 181.7 VERTICAL DEPTH 765.86 1302.23 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T IBIC PULLED ML6617 2x18, 2x16 175 1007 832 14.54 2-2-WT -A-3/16-SD-DTF MWD failure LK1029 3x18, 1x14 1007 380 8.23 In Hole HIGH LOW AVERAGE CURRENT AVG 202.8 @ 1312 5.2 @ 886 72.3 29.6 ftIhr 2384 @ 945 222 @ 1007 917.3 278.7 amps 27 @ 911 1 @ 1174 13.9 14.9 K1bs @ @ RPM 1685 @ 1377 1053 @ 947 1453.6 1583 psi DEPTH: 1442/1407 TVD 57 PV 17 YP 20 FL 10.0 Gels 8/20/28 CL- 300 6.0 SD 0.25 OIL 0 MBL 22.5 pH 9.5 Ca+ 20 eel HIGH LOW AVERAGE 10 @ 1360 0 @ 1068 4.6 TRIP GAS= 3 @ @ WIPER GAS= CHROMA TOGRAPHY{ppm) SURVEY= 2129 @ 1360 164 @ 1077 915.9 CONNECTION GAS HIGH= @ @ AVG= @ @ CURRENT @ @ CURRENT BACKGROUND/AVG 5/8 @ @ NONE LlTHOLOGY/REMARKS GAS DESCRIPTION DAILY ACTIVITY SUMMARY Drill from 867' to 881'. Circulate. Pump up survey. Change saver sub. Drill from 881' to 1007'. MWD failure. Circulate hole clean. POOH. Handle BHA. Lay down MWD tool. Clean stabilizers. Break bit. Make·up New Bit #8. Orient, install and surface test MWD tool. Adjust Topdrive compensator. RIH. Wash and ream from 885' to 1007'. Drill from 1007' to 1387' (report depth) and continue to drill ahead. ( Epoch Personel On Board= 2 Dally Cost 1709 Report by: Craig Silva file://C:\Abalone 1 \20030202,htm 2/3/03 uauy J.'\..\;.tpvu ( MARATHON OIL C.OMPANY TYONEK FIELD - "0- DAILYWELLSITEREPORT n EPOCH' ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Feb 01, 2003 TIME 24:00 CASING INFORMATION 20" @ 170' DEPTH INCLINATION AZIMUTH SURVEY DATA 526 2.5 187.3 706 6.7 188.8 BIT INFORMATION INTERVAL NO. SIZE· TYPE SIN JETS IN OUT FOOTAGE HOURS 7 17.5 STC DSJC ML6617 2><18, 2x16 175 692 11.34 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE . f.~, '. '(" I .. , .! ( DRILLING MUD REPORT MW 9.1 VIS FC 3 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY NlA PRESENT LITHOLOGY N/A DEPTH 867 YESTERDAY 175 PRESENT OPERATION= DRILLING 24 Hour Footage 692 VERTICAL DEPTH 525.98 705.34 CONDITION T/B/C In Hole REASON PULLED 54 4.0 HIGH LOW AVERAGE 346;8 @ 186 8.2 @ 610 88.7 2342 @ 557 260 @ 729 1192.8 28 @ 846 0.4 @ 186 9.6 @ @ 1461 @ 830 222 @ 175 1056.0 .. ' ., -1'. . _', . .....-.'., ., ~. . -'"'I" , -" /'.-> . DEPtH: 886 I 885 TVD . PV 12 YP 21 FL 10.0 Gels SO 0.5 OIL 0 MBL 22.5 pH CL- 300 Ca+ 20 CCI CURRENT AVG 63;5 2252.2 6.2 ftIhr amps Klbs RPM psi 1291 ,.-, ,i"" rl,-, ~ . '?,. ,.-:.. I" 'i"I ·....,\..11. 8/24/29 10.2 HIGH LOW AVERAGE 7 @ 809 0.2 @ 323 1.9 @ @ CHROMA TOGRAPHY(ppm) 1555 @ 809 40 @ 342 377.3 @ @ @ @ @ @ @ @ NONE LlTHOLOGY/REMARKS TRIP GAS= 3 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 3/4 GAS DESCRIPTION RIH. Teg bottom 8t. H5'..Drill 17.5" ftøle-from H5'{o48t'.Cheftgewe&f~te'for~.cy~nnd"ðf 1ifw:r~fdl·2 moo pump. DrllHfOfl'l 481' to 610'. POOH after MWD failure. Pull and lay down MWD tool for maintenance. Clean stabilizers and bit. Orient, install and test MWD tool. Service carrier and grease swivel. RIH. Survey at 570' and 60S'. Drill from 610' to 708'. Repair leaking weid on #2 mud pump suction screen box.. Drill from 708~ to 867r (report depth) and continue to driU ahe8d. ' Epoch Person'el On Board= 2 Dally Cost 1709 Report by: Craig Silva . DAILY ACTIVITY SUMMARY ( \ fi1p.'//r·\Ah~1nnp.l\?OO~O?Ol htm ? I? 10'>. MARATHON OIL COMPANY TYONEK FIELD ABALONE #1 REPORT FOR ROWLAND LAWSON DATE Jan 31, 2003 TIME 24:00 ,'.i " CASING INFORMATION 20"@ 170' SURVEY DATA BIT INFORMATION NO. SIZE TYPE NIA 17.5 Mill DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE . WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.7 VIS FC 3 SOL ( MWD SUMMARY 'INTERVAL TO TOOLS GAS SUMMARY(unlts) . DITCH GAS CUTTING GAS METHANE(C-1 ) .. ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS· INTERVAL LITHOLOGY NIA PRESENT LITHOLOGY N/A DAILY WELLSITE REPORT g EPOCH DEPTH 175 YESTERDAY 170 PRESENT OPERATION= RUNNING IN HOLE 24 Hour Footage 5 DEPTH INCLINATION VERTICAL DEPTH AZIMUTH SIN N/A INTERVAL IN OUT 170 175 HOURS 1.26 CONDITION TIBIC NJA REASON PULLED Drill with bit #1 FOOTAGE 5 JETS N/A HIGH LOW AVERAGE CURRENT AVG 22.9 @ 172 3.8 @ 174 18.1 14.1 ftIhr 1538 @ 173 1071 @ 175 1711.8 1071.7 amps 3 @. 175 0.4 @ 172 1.9 3.9 Klbs @ @ RPM 223 @ 174 181 @ 172 256.0 222 psi DEPTH: 170/170 TVD 70 PV 16 YP 26 FL 15.0 Gels 27/34/38 ct- 200 4.0 SO 0.25 OIL 0 MBl 20.0 pH 10.0 Ca+ 20 eCI HIGH lOW AVERAGE 0.38 .@ 175 0.12. @ 171 0.3 0 @ 175 0 @ 175 0.0 CHROMA TOGRAPHY(ppm) 76 @ 175 24 @ 171 65.5 @ @ @ @ @ @ @ @ TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 0.2/0.3 NONE LlTHOLOGY/REMARKS GAS DESCRIPTION Drill 17.5" hole from 123' to 169'. Clean out conductor. Unable to pass 169'. Circulate hole clean. Pump up survey. POOH. lay down MWD probe. Break off bit. Adjust Topdrive compensator. Blowdown mud line. Make up clean Ollt bit. Pick lip MWD probe. RIH. Attempt to drill out of conductor failed again. POOH. lay down MWD probe. Break off clean out bit. Make up clean out assembly DAilY with steel De's and 17.5" cleanout bit. RIH. Attempt to drill out of conductor failed again. POOH. Lay down 17.5" bit. Make up 12.~5" ACTIVITY bit on clean out assembly. Work past shoe. Drill from 170' to 175'. POOH. Check bit. Wait on mill. Repair elevators. "Pull test" SUMMARY tuggers. Cellar.brtdge cranes. Pickup and make up, milt assembly. Mill could not get:ttTroughrotary table. Lay down mill. Pull test bridge cranes. Rig up to make up stands of 5" HWDP. Pick up and make up and drift 12 stands of HWDP. Wait on mill. Rack and set up 13.375" casing. Make up mill and RIH to 169'. Mill from 169' to 175'. Work mill through shoe. POOH. Lay down steel drill collars, junk basket and mill. Make 'up 17.5" bit. Orient 'and install MWD.RIH. Epoch Personel On Board= 2 Daily Cost 1709 Report by: Craig Silva I t file://C:\Abalone 1 \20030131.htm 2/1/03