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207-085
4110 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 0 7 - ©'.Well History File Identifier Organizing (done) wo -sided lflhIIIfI 1111 ❑ Rescan Needed III 11 11111 111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) Liz(olor Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner or Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: r BY: Wel Date: ■ - .3 /s/ 1 Project Proofing 1111111/1 11111 BY: ams Date: t /s/ nif) Scannin g Preparation 9' Pre x 30 = a7 + 3 = TOTAL PAGES ca / 3 (Count does not include cover sheet) 04 f3 BY: Mare Date: q /s/ / I Production Scanning 111111111111 11111 Stage 1 Page Count from Scanned File: P7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: - . Date: q 0 1 / Z /s/ p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I 111 111111 1 11111 ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIIlIIIIII 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/25/2013 Permit to Drill 2070850 Well Name /No. AHTNA 1 -19A Operator RUTTER AND WILBANKS CORPORAT API No. 50- 099 - 20005 -01 -00 MD 4341 TVD 4341 Completion Date 7/3/2007 Completion Status SUSP Current Status P &A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / • Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /Q Daily History Received? Y / N Chips Received? Y-1-N— Formation Tops Y / N Analysis Y.1 -iG" Received? • Comments: (jv Compliance Reviewed By: _- Alw'1 Dater W0_1j ^JO Ahtna 1 -19A Coil Tubing Workover Schlumberger Service Coil Unit #1 Photos by AOGCC Inspector J. Crisp 8/31 — 9/2/2009 NYC i ' .). . 0 . i'' 1 . . , ♦ Fri I V I ' ` .. Installing Schlumberger 1 , '13 I Coil Tubing BOPS Al , y kt i ,. . I r • c ' I 1 \ j IrdefAIINEN9 i , A. I EMIPIIIMIIIIL IIIIIIIPi Coil tubing work platform J F /11111 ' III ' i\ I ____ t l l i vi! i 1 , , . " / El �. ®• If • • efill '''' I lint * - - - maw imPilow I I Vtk_ I , * Iva - ,t,, , - rili 1 M _ 17110 _ ____ , l',ralii, 11 lir II i 1 ' 1 ' t r y e.) , t ._ . ,....,,,,..„....„ 1 .. mill ' 11■k tow, 1 . . yr + 1 ......-iii .. i r 1 1 _4 _ _ --=____-_ ,„, .- ,_ { _ . ._,. , 7t-; ,,...,,,,,,..... _ .....,.. 1 fit. r ` . sl #, y, *►. � a ,•. Ahtna 1 -19A �' '",.�.� { V wellhead; tree . • Wei r lifil, , i il _ v - • 4. , 3 WV' � tti � �� iwar.• . • i t s i . _ • • 1 ., • 3(7 • • 1 ' ''.•..t e 1■. t Rigging up coil ► `, tubing BOPS stack I iirif i "... ■v n 1 A•.111 i E , 1 ∎ •_ 1 , ..— —, mu. r ,,„. 1 a „,,,, �` ' P Kill line valve ; ,,,, v Ih., it 11111 al --.9. t i lik It a * * Choke line HCR , ' Iltik - w 3( 7 • • ■ 5 �.,�� IAidi 1�"tTNIS, LX 1N-1P"'lP 4 \iAl•l{ i? - t may r Prefabricated �"^�•Z -.�.. choke and kill lines T .oe f ;;:•";;Z : 1 . o . : : -° - " e - "". • - _ a --. t Pbt 90's _ .. to choke re- fa manifold ed { 1 t ri :illi . VII, 7 �; Plug valves on i ' : ' BOP stack for 41 � pressure sensors r4 f 1 II ' �� .ill 4 / 0 10 NIP' 4 I 41 /•- I Gas buster M r I - . 1 l i ! 1�.- e 1 y Hydraulic actuator for choke line HCR N. 114 ' r E _ x. r t. • r s it M y Wag Ng lai _ _ . Super choke panel �_ f ¢ ` ` t i I 4110 I 577 Flange testing leak during i. , Repairing gas - roy t buster ■ nun fj _ ,„,111 5 , ;' vr MINN ' 7 ''' ' ,... ( .---- iffaff/AV 1 ...: ''. 1 Fit , E • " _ , ' t- ` Accumulator skid , :' ++fit,. 4 f _ afilizi t 6 • I Tiger tanks il .1 ' ' ' t 1!1 ,. - _ _ v„....„„„,,,,. it s\ e Schlumberger 1 Coil Tu rigged up bing for operations _,�� Biel 1(1 • Petroleum Engineers, Inc. RECEIVED Three Riverway, Suite 1500 DEC 0 2 2009 Houston, TX 77056 Alaska Oil & Gas Cons. Commission Anchorage November 30, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: o(.O 7 Enclosed are two original sets of the Form 10-407 for the Plugging of the hie #1- c i! the Sidetrack & Completion of Ahtna #1 -19B and the Plug & Abandonment of the Ahtna #1 -19B. Each form includes the following: 1. Form 10 -407, Well Completion Report with pages 1 & 2, 2. Operational Summary, 3. Wellbore Diagrams with dated status, and 4. PEI Morning Drilling Reports with appropriate corrections. The Plugging of the Ahtna #1 -19A occurred from 8t79/e91hru 9/6/0 ". The Sidetrack & Completion of the Ahtna #1 -19B occurred 9/6/09 thru 9/19/09. The Plugging and Abandonment of Ahtna #1 -19B occurred from 9/20/09 thru 9/29/09. These packages should complete the AOGCC reporting requirements. If you have any questions or corrections, please send me an email or call my cell phone. Sincerely yours, it ( -'— Eddie L. Wright, P.E. Petroleum Engineers, Inc. Office: 713- 479 -7070 Cell: 713 - 823 -7789 Email: ewright @peiinc.com cc: Mr. Bill Rutter, Jr Mr. Mick Francisco Rutter & Wilbanks Corp Sandalwood Oil & Gas Inc. P.O. Box 3186 1220 Augusta Dr., Suite 400 Midland, TX 79702 Houston, TX 77057 STATE OF ALASKA ?Zflllzoo Y ALASKI IL AND GAS CONSERVATION COMMIS N WELL COMPLETION OR RECO REPORT AND LOG 1 a. Well Status: Oil U Gas Li Plugged U Abandoned [ (Suspended Li 1 b. Well Class: 20AAC 25.105 VJ4l OAAC 25.110 Development ❑ Exploratory El GINJ WINJ❑ WDSPL❑ WAG Other El No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Rutter and Wilbanks Corporation , Aband.: 9/5/2009 2070850 3. Address: 6. Date Spudded: 13. API Number: 301 S. Main St., Suite B, OR PO Box 3186, Midland, TX 79702 6/11/2007 50- 099 - 20005 -01 -09 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1139.4' FEL & 2224.2 FSL Sec 19, T4N, R3W, CRM 6/28/2007 / Ahtna #1 -19A Top of Productive Horizon: 8. KB (ft above MSL): 2037' 15. Field /Pool(s): 4230' Ground (ft MSL): 2018.7' NA Total Depth: 9. Plug Back Depth(MD +TVD): 3,995' TD 3995' MD / TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 527867 y- 2964256 Zone- 3 4341' MD / TVD Sec 19, T4N, R3W, CRM TPI: x- y- Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- y- Zone- NA Ahtna Surface 18. Directional Survey: Yes Li No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost (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): None 22. 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 13 -3/8" 68# L -80 0 78 0 78 18.3 bbls Class G 9 -5/8" 40# L -80 0 1226 0 1226 20 bbls Perafrost & Class G 0 7" 26# L -80 0 1915 0 1915 66 bbls Class G 0 5" 17.8# L -80 0 4639 0 4639 53 bbls Class G 0 3 -1/2" 8.8# L -80 4577 5165 4577 5165 5 bbls Class G 0 23. Open to production or injection? Yes U No U If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) The None well has been prepared for sidetrack operations as Ahtna #1 -19B. 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4140 -4148 3 sqeezes for total of 428 sacks Class G 4072.8- 4074.8 Squeeze 24 sack Class G 26 PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NA NA Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas-Oil Ratio: NA Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate N.► 27. CORE DATA Conventional Core(s) Acquired? Yes No U Sidewall Cores Acquired? Yes Li No H 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. A f r' UII11 IU-41.) 1 RCVIJCU L/LUU a c r 9 e it • • T 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? n Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Nelchina 4230 4230 Formation at total depth: Shale 4341 4341 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Eddie L. Wri• ht Title Project Engineer Air Signature: Ei % �J / fl Phone: (713) 823 -7789 Date: 7/7/2007 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 la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with 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 TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 Report No. Date • Activities Start P &A for Ahtna #1 -19A 1 8/22/09 MIRU Schlumberger Coil Tubing Unit, check pressures on wellhead, rig up fluid circulating system. 2 8/23/09 MIRU Schlumberger Coil Tubing Unit, conduct BOPE Test 3 8/24/09 Complete pressure testing BOPE. MIRU mud mixing equipment and perform maintenance on Injector head 4 8/25/09 Waiting on 2 -7/8" mud motors. Completed hook up of mud mixing system. Received a denial on hammer unions in the choke line between the drilling spool and choke manifold. 5 8/26/09 Pick up Cement Drilling BHA with 2 -7/8" mud motor, under reamer, & 3 -blade cement mill. Drill from 3198' to 3162' in 10 hrs, Average ROP = 16.4 ft/hr. Completed pump repairs and back on bottom at 01:10 hrs 8/26/09, Depth at 04:00 is 3392' 6 8/27/09 Milling cement form 3362 to 3442'. Found metal cuttings on magnets. Trip to repair underreamer. Two of three blades were damaged. Replaced all three blades and milled cement from 3442 to 3458'. Still having metal in returns. Trip for 3.75" PDC bit and clean up flowlines. 7 8/28/09 Milling cement form 3458 to 3887'. Milled 429 ft in 9.25 hrs for a IROP = 46.3 ft/hr. Average ROP for last 23 hrs = 18.6 ft/hr. Cutting cement with 3.75" PDC bit in 4.26" ID casing is leaving a cement sheath about 0.25" thick. Sheath is breaking up and falling down hole during wiper trips causing sticking problems pulling up and cutting build -up on bottom. 8 8/29/09 Milling cement form 3887 to 4133'. Milled 246.5 ft in 6.0 hrs for a IROP = 41.1 ft/hr. Lost 11.5 hours cleaning out the large cement cuttings in thicknesses from 0.25 to 0.5" thick and 2-4" in length. Average ROP for last 12.5 hrs = 21.4 ft/hr. Cutting cement with 3.75" PDC bit in 4.26" ID casing is leaving a cement sheath. During back reaming & wiper trips, the sheath is breaking up, falling down hole, & causing stickingproblems. 9 8/30/09 Back reaming with PDC bit to remove cement sheath. Took a 13 bbl gain at 2:51 hr. Pull out of hole & waited on orders. Performed maintenance &prepared to trip in hole with underreamer (UR) and cement mill. Recorded Ream down to 4120' and up with UR BHA. Ream and trip in hole, drop ball, circulate hole clean, and trip out. time and pressures. Opened well & trip into hole with underreaming BHA to 3458' 10 8/31/09 Wait on IRBP, modify plans to cement window, run injections nozzle to 4133', perform injection test at 1 & 2 bpm, pull out of hole, & remove injection nozzle. Decision is to squeeze old window with 15.8 ppg Class G cement. Make up cementing nozzle & trip in hole. 11 9/1/09 End of coil tubing at 4033' for squeeze #1. Safety meeting. Pump 5 bbls water ahead of 100 sacks Class G cement, displaced with 24.7 bbls of freshwater. Treating pressure rose from 2250 to 3065 psig. WOW 12 hrs. Pressure up & trip in hole. Did not tag any cement. Pick up & establish pumpin rate at 1 & 2 bpm. Start planning squeeze #2. Start with 5 bbls water. Mixed & pumped 28 bbls cement with no evidence of squeeze. Overdisplaced & started plans for cement squeeze #3. 12 9/2/09 Trip in hole to 3950' & start cement squeeze #3. Mixed & pumped 200 sacks Class G cement. Displaced to end of coil tubing with 24.7 bbls. Pulled outof hole. Started WOC while working on wellhead change. Hard line piping was not installed. Assembled hammer union piping. Started BOPE Test with AOGCC inspector on site. 13 9/3/09 Complete AOGCC inspection & testing of BOPE. Make up nozzle to trip in hole. Well is pressuring up. Pick up underreamer /cmt mill. Start in hole. Tagged hard cement at 3832.7'. Pull out of hole & lay down underreamer /cement mill. Trip in with PDC drill bit and drill down to 4090. LD PDC bit and pickup underreamer/ mill. Clean out sheath of cement to 4090 ". Welders are making changes to piping as directed by AOGCC rules. Moving equipment to install choke line. Hooking up gas buster. Small incident on opening cam -lock. 14 9/4/09 Rigged up Schlumberger & tried to get correlation log. Logging unit having problems with winch operations. Waited on mechanic/technician to trouble shoot problems. Got correlation log. Applied pressure to lubricator to perforate at 772 psig underbalanced. Perforated at 4072.8- 4074.8' withl2 holes. Very limited injection as pressure rose to 2800 psig. Shot second pert gun at 4072.8- 4074.8 with 12 holes. Still have limited injection. 15 9/5/09 Not able to establish an injectivity rate into perforatings from 4072 - 4074'. Make up whipstock & set on electric line from 4053 to 4065'. Rig down electric line, BOPE & crane truck. Change out hammer union pipe for flanged kill line & test to 5000 psig. Make up BHA and trip inhole to 4052'. Flow test MicroMotion flow sensor. Pump 5 bbls Class G cement into casing & pull up to 3157'. Pressure up to 4650 psig. Release pressure and pressure _ to 3500 psig. Pressure dropped to 2580 as 3.5 bbls cement was displace from 3955 to 4052'. Trip out with coil tubing holding 2500 psig. WOC. 16 9/6/09 WOC on cement squeezed over whipstock and thru perfs at 4072 - 4074'. Pick up Underreamer /mill BHA & ream to 3995'. Pull out for maintenance on coil tubing, to change on hydraulic drive motor on coil reel, & to work on MicroMotion flowlline sensors P &A for Ahtna 1 -19A is complete • • RUTTER & WILBANKS CORPORATION Sec 19, T4N, R3W AHTNA #1 -1 9A API No.: 50- 099 - 20005 -01 Current Wellbore Diagram RKB 2037.0 18.3 7/3/07 GL 2018.7 Depth Casing /Cement - 7 ' BGL 13-3/F 68 # L -80 Conductor I 8 G 150 'Diesel (3 bbls) Shoe Squeezed with 18.3 bbls 12 -1/4" 1,226 9 -5/8" 40# L -80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" Z 1,915 7" 26# L -80 BTC Intermediate 66 bbls Class G to surface 3,200 Top of cement (CBL) 3210' PBTD 3,210 PBTD (tagged on 7/2/07) Cement: 15.8 ppg Class G with 40 # /bbl CEMnet fiber, 1.5 gal /sk Gas Top of Whip Stock at 4129' Blok, & 0.1 gal /sk Accelerator 4,140 Top of Window Whip Stock Anchor at 4,153' 4,148 Bottom of Window ►� 4,154 Obstruction in hole Top of Bailed Cement 4,170 (tagged 6/14/07) Evaluate zone ±4,230 4,250' Mechanical Plug 4,220 E -Line Perfs: 4232 4250 —_ Drill Perf Tool Channels: 4382 —_ 4387 — End of Side track at 4341' E -Line Perfs: 4474 4490 4506 4530 Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner 4,635 Weatherford E -IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L -80 ST -L Intermediate Perforations: 4674 4680 = 53 bbls Class G 4922 4940 4923 4929 —_ 4932 4938 5010 5020 = 5076 5084 5,099 Top of cement 5,165 3 -1/2" 8.8 L-80 ST -L Prod. Liner Total Depth (MD & TVD) 5,165 • • • RUTTER & WILBANKS CORPORATION Sec 19, T4N, R3W AHTNA #1 -19A API No.: 50- 099 - 20005 -01 Current P&A Diagram Well No.: 207 -085 RKB 2037.0 18.3 9/5/09 GL 2018.7 Depth Casing /Cement 78' BGL 13 -3/8" 68# L-80 Conductor Shoe Squeezed with 18.3 bbls 12 -1/4" 1,226 9 -5/8" 40# L-80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" Z. 1,915 7" 26# L -80 BTC Intermediate 66 bbls Class G to surface 3,200 TOC (CBL) outside 5" casing P&A of Ahtna #1 -19A was completed on 9/5/09, as follows: 3995 1) Drilled cement 3210 - 4090', 4,053 Top of Whipstock - Start of Window 2) Perf 40718- 4074.8 (24 holes), 3) Whipstock at 4053 -4065' 4) Sqz perfs with 24 sacks Class G 5) Ream cement to 3995' & POOH 4,065 Bottom of Whipstock Squeeze Perforations to 4072.8 cement Whipstock in 4074.8 j place. Original sidetrack was cleaned out to 4133'. 4090 Original sidetrack was cemented with three 2007 Top of Whip Stock at 4129 squeezes to seal off original window and possible channel behind pipe. Squeeze #3 was 200 sacks Class G, Squeeze #2 was 128 sacks Class G, and Squeeze #1 was 100 2007 Window 4140-4148 4133' sacks Class G. 2007 Whip Stock Anchor at 4,153' : : : : •. 2007 obstruction in hole 4154' TOC (tagged 6/14/07) 4,170 Drilled with 175 x 4.125" bi- center bits Nelchina Formation Mechanical Plug 4,220 �r '' ?' ' ' ' '' ' ' ±4,230- 4,320' E -Line Perfs: 4232 4250 �_. Drill Perf Tool Channels: 4382 — — 3931 psig @ 4320' 4387 = - 17.5 ppg EMW E -Line Perfs: 4474 4490 = 2007 Sidetrack ■ _ 4506 4530 TD: 4341' Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner 4,635 Weatherford E -IRBP Infl able Ret. BP) A (Inflatable 4,639 5" 17.8k L-80 ST-L Intermediate Perforations: 4674 4680 _ _ 53 bbls Class G 4922 4940 4923 4929 _ _ 4932 4938 = — 5010 5020 5076 5084 5,099 Top of cement Total Depth (MD & TVD): 5165' 5,165 3 -1/2" 8.8 L -80 ST -L Prod. Liner PETROLEUM • • ENGINEERS MORNING DRILLING REPORT - ONSHORE Report # DATE 1 8/22/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 0 0 0 0 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Continue rigging up CTU, fluid circulating system, & tanks. NA 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD. TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA NA Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS. MIRU Schlumberger Coil Tubing Unit, check pressures on wellhead, rig up fluid circulating system. CURRENT WEATHER: Wind Direction Wind Speed Temperture BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FILT HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM! 0 D L B G O R #1 #1 #2 #2 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS CC /30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/19/09 Wednestay [ ] NO CHANGE (SEE PRIOR RPT) Schlumberger started loadout of equipment. [ ] NEW BHA 8/20/09 Thursday _ ROT. HRS SINCE INSPEC. Schlumberger equipment arrived on location and was offloaded. Some components were set in place. TOOL DESCRIP. LENGTH 8/21/09 Friday Schlumberger continued rigging up coil tubing unit and is working two 12 hr shifts. Vetco Gray was on site during the morning. Initial dry hole tree pressure gage reading was 500 psig. The 5 "x7" annulus gage showed 800 psig. The 7 "x9 -5/8" was on a vacuum. Bled pressure off the 5 "x7" annulus to zero with no build up. Bled pressure of the 5" casing to zero with no build up. Tested 5" casing void to 3,000 psig ( API collapse for 5" 17.93# L -80 ST -L is 10,500 psig). Closed 4 -18" 5K valve and tested valve up to blind flange to 5,000 psig. Removed blind flange, cleaned ring gasket seat, installed new ring gasket and installed CT Head. Bolted up the 4" 10K x 4" 5K spool and 4" 5K blind flange. Tested CT Head and tested to 5,000 psig. Removed spool and blind flange. Schlumberger began installed 4" 10K x 5 -1/8" 10K spool, 5 -1/8" 10K BOPE. Started rigging up CTU injector head. Set work tour around wellhead and BOPE. Layout hoses for flowlines. Called AOGCC at 1600 hrs for 24 -hr notice of BOPE test. Plan BOPE test during evening evening of 8/225/09. AOGCC representative requested update on morning of 8/22/09. Received Mud Motors, Bits, Office Bldg, three portable toilets, and first diesel fuel for site equipment. NOTE: Cumulative daily costs have been estimated, pending evaluation on all vendor delivery tickets. TOTAL LENGTH 0.00 NOTE: Daily Reports will run from Midnight to Midnight to match Schlumberger time interval. WEIGHT IN MUD DATE LAST BOP TEST 'TORQUE TROT S /0 IP /U PREVIOUS TOTAL COST $O OPERATOR "S REP Eddie Wright DAILY COST $156,197 cum TOTAL COST $156,197 PETROLEUM • ENGINEERS °y_ - � MORNING DRILLING REPORT Report # DATE 2 8/23/2009 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 1 0 0 0 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH MIRU Schlumberger Coil Tubing Unit NA 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD, TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS MIRU Schlumberger Coil Tubing Unit, conduct BOPE Test CURRENT WEATHER: Wind Direction Wind Speed Temperture BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FILT HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM # TYPE 1 2 3 4 OUT HR WT RPM! OD L B G 0 R #1 #1 #2 #2 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORDES PF MF HTHF MUD COSTS TIME WT VIS CC /30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/22/2009 Saturday [ ] NO CHANGE (SEE PRIOR RPT) 00:00 05:00 Continue to hook up control lines to Injector Head. Off load the office trailer and conex. [ ] NEW BHA 05:00 10:00 Work on Injector Head and off load drilling fluid chemicals. Install second 4 -1/8" 5M valve on wellhead. ROT HRS SINCE INSPEC. 10:00 11:45 Dozer on site to dress up location and level access road. Called Chuck Scheve with AOGCC to be avail- TOOL DESCRIP. LENGTH able about 20:00 hrs for BOPE and Choke Manifold testing. 11:45 15:00 Hook up steel lines from BOPE to choke manifold and tanks. 15:00 21:30 Continue to hook up control lines and set crane. Using STS flowback iron. Stab coil into Injector Head 21:30 22:20 Hook up water lines and fill stack. Check for leaks. 11:45 00:00 Start testing valves on the choke manifold to 250 psig low and 5000 psig high. 00:00 05:30 Completed testing choke manifold, kill manifold, and BOPs to 250 psig low and 5000 psig high. NOTE: Chuck Scheve with AOGCC arrived on location at 18:00 hrs and departed at 0530 hrs 8/23/09. TOTAL LENGTH 0.00 NOTE: Daily Reports will run from Midnight to Midnight which same time interval fr;;m Schlumberger WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 iTOROUE TROT IS/0 IP /U PREVIOUS TOTAL COST $156,197 OPERATOR'S REP Eddie Wright DAILY COST $69,940 CUM TOTAL COST $226,137 • PETROLEUM • • ENGINEERS MORNING DRILLING REPORT Report # DATE 0/ 3 8/24/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 2 0 0 0 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Rigging up mud system, work on Injector Head, make up CT connector NA 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD, TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO. NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS' Complete pressure testing BOPE. MIRU mud mixing equipment and perform maintenance on Injector head CURRENT WEATHER: Wind Direction Wind Speed Temperture BIT, WEIGHT, SPEED, AND HYDRAULICS — BIT SIZE MAKER/ NOZZLES DEPTH FILT. HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I OH) L B G 0 R #1 #1 #2 #2 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT. CAKE % % MBT CHLORIDES PF MF HTHP MUD COSTS TIME WT VIS CC /30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/23/2009 Sunday [ ] NO CHANGE (SEE PRIOR RPT) 00:00 05:30 Completed testing choke manifold, kill manifold, and BOPs to 250 psig low and 5000 psig high. [ ] NEW BHA 05:30 07:00 Move Injector Head off well. _ ROT HRS SINCE INSPEC. 07:00 08:00 Crew change. Perform equipment maintenance. TOOL DESCRIP. LENGTH 08:00 12:00 Perform equipment maintenance and repairs. 12:00 17:00 Fuel equipment, performance on Injection Head, review JSA on picking up Injector Head 17:00 19:00 Off load Baker Oil Tools tool box, cut off coil to make connection. 19:00 20:30 BOT service representative on site to make up connector. Check bit and DT undeneamer. 20:30 21:00 Set upc ontainment barrier and move in mud mixing tank. Start unloading trucks with MI equipment. Starter making up cement milling BHA. Need to change to 2 -7/8" motor due to height limitation on the SchlumbergE crane. 20:30 00:00 Spot the shale shaker pit. Need additional containment barriers to place mud hopper and tank. Waiting on third truck load with cutting boxes, containment barriers, hoses and valves. TOTAL LENGTH 0.00 NOTE: Daily Reports will run from Midnight to Midnight which same time interval from Schlumberger WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 ITOROUE TROT 1S/0 IP /U PREVIOUS TOTAL COST $226,137 OPERATOR "S REP Eddie Wright DAILY COST $75,033 CUM TOTAL COST $301,169 PETROLEUM • ENGINEERS MORNING DRILLING REPORT Report # DATE 4 8/25/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A _ Ahtna #1 -19B 3 0 0 0 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Rigging up mud system, work on Injector Head, make up CT connector NA 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS Waiting on 2 -7/8" mud motors. Completed hook up of mud mixing system. Received a denial on hammer unions in the choke line between the drilling spool and choke manifold. CURRENT WEATHER: Wind Direction Wind Speed Temperture BIT, WEIGHT, SPEED, AND HYDRAULICS — BIT SIZE MAKER/ NOZZLES DEPTH FILT HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM # TYPE 1 2 3 4 OUT HR WT RPM! OD L B G 0 R #1 #1 #2 #2 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/24/2009 Monday [ ] NO CHANGE (SEE PRIOR RPT) 00:00 22:59 Waiting on 2 -7/8" mud motors to be delivered from North Slope to location. [ ] NEW BHA Received and set up additional ground containment barriers. Set up Mud Mixing / Hopper Tank. Hooked up_ ROT HRS SINCE INSPEC electrical power to shale shaker, two centrifugal pumps, four agitators. Mud mixing system hoses and TOOL DESCRIP. LENGTH connections were laid to complete the mud mixing system from the mud mixing tank. the mud storage tank with four agitators, shale shaker tank, and to the CT high pressure pump. Mixed initial 70 bbls of gelled water to wash out 5" casing. Submitted list of concerns & proposed variances via email to AOGCC rules under Section 20 ACC 25.036, 20 ACC 25.037, and 20 ACC 25.066 for Ahtna #1 -19B. Received phone call at 14:34 hrs 8/24/09 & email at 14:36 hrs on 8/24/09 from AOGCC stating that our request for variances on the HCR valve & hammer unions on the choke line to the choke manifold & kill lines were denied. Proceeded with planning steps to meet these requirements prior to milling out the window for Ahtna #1 -19B. Anticipate receiving the 2 -7/8" mud motors by 0300 hrs on 8/25/09. Will proceed to assemble cement drilling BHA. make up injector head, pick up BHA, and trip into well. TOTAL LENGTH 0.00 NOTE: Daily Reports will run from Midnight to Midnight which same time interval fr.-:m Schlumberger WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 'TORQUE "ROT S/0 IP /U PREVIOUS TOTAL COST $301,169 OPERATOR "S REP Eddie Wright DAILY COST $78,708 CUM TOTAL COST $379,877 PETROLEUM • • ENGINEERS MORNING DRILLING REPORT Report # DATE 5 • 8/26/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 4 3,362 3,362 164 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Drilling out cement at x,xxx' Cement 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD. TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS Pick up Cement Drilling BHA with 2 -7/8" mud motor, under reamer, & 3 -blade cement mill. Drill from 3198' to 3162' in 10 hrs, Average ROP = 16.4 ft/hr Completed pump repairs and back on bottom at 01:10 hrs 8/26/09, Depth at 04:00 is 3392' CURRENT WEATHER: Wind Direction Wind Speed Temperture 45 -54 with rain to clearing skies BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FILT HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I 0 D L B G 0 R #1 #1 #2 #2 1 3.75 Cmt Mill -3,198 - MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS _ MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/25/2009 Tuesday [ ] NO CHANGE (SEE PRIOR RPT) 00:00 05:30 Received 2 -7/8" mud motor. Measure and talley cement drilling BHA = 21.27', 3.13" OD except for 3.38" [X] NEW BHA OD on HD. _ ROT HRS SINCE INSPEC. 05:30 06:30 PU BHA into lubricator. PU Injector Head and make up lubricator connection. TOOL DESCRIP. LENGTH 06:30 11:40 Start in hole. String started taking weight at 2640', work thru to 3198', tag solid. Lost prime on mud pump. CTC 0.94 Start pulling out slowly while replacing fluid filter. Started pump, stopped pulling up at 2600' & Start back in BPV 1.57 hole at 1.3 ft/min. Wash back down to 3198' with ROP 33.0 ft/hr HD 1.53 11:40 13:45 Drill to 3214.2', 2.5 bpm, 2010 psig PP with 310 psi across the motor, ROP 18.00 ft/hr DCS 1.15 13:45 14:30 Drill to 3223.7', 2.5 bpm, ROP 6.00 fUhr XO 0.70 14:30 15:50 Drill to 3250.0', 2.5 bpm, ROP 20.25 ft/hr MM 10.80 15:50 17:00 Drill to 3253.4', ROP 1.5 ft/hr UR/BIT 4.58 17:00 18:00 Drill to 3267.7', ROP 7.20 ft hr 18:00 19:00 Drill to 3287.0', ROP 9.60 ft/hr 19:00 20:00 Drill' to 3344', 2000 psig PP, 2.5 bpm, 0.95 fpm, String Wt 1750 #, Average ROP (3344 -3198) = 17.52 ft/hr 20:00 21:23 Drill to 3364', 2235 psig PP, 2.5 bpm, ROP 7.23 ft/hr 21:23 23:59 Start slow pull out while fixing tri -plex pump. Plunger leaking, replace packing. TOTAL LENGTH 21.27 NOTE: Received diesel storage tank and 1356 gal fuel.. WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 (TORQUE 'ROT 1S /0 IP/U PREVIOUS TOTAL COST $379,877 OPERATOR "S REP Eddie Wright DAILY COST $105,092 CUM TOTAL COST $484,969 PETROLEUM M • • • , ENGINEERS MORNING DRILLING REPORT : � A � ` Report # DATE 6 updated 8/27/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 5 3,458 3,458 96 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Tripping for 3.75" PDC bit. Cement 4,650 MD 4,650 TVD - LAST CASING AND SHOE TEST LINERS - OD, TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO. NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS - Milling cement form 3362 to 3442'. Found metal cuttings on magnets. Trip to repair underreamer. Two of three blades were damaged. Replaced all three blades and milled cement from 3442 to 3458'. Still having metal in retums. Trip for 3.75" PDC bit and clean up flowlines. UPDATED FOR MUD PROPERTIES AND CURRENT COSTS. CURRENT WEATHER: Wind Direction Wind Speed Temperture 45 -54 with drizzle to clearing skies BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM # TYPE 1 2 3 4 OUT _ HR WT RPM I 0 D L B G 0 R #1 #1 #2 #2 1 3.75 Cmt Mill 3,458 260 _ _ _ 2 3.75 PDC MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS CC /30 _ 32nds SAND SOLIDS ..., _ DAILY TOTAL 20:00 8.8 54 9 23 22 26 29 12.2 na 3.0 TR 6.0 ` 29_ 800 0.9 1.8 _ NA 2,840 10,846 14:00 8.8 50 9 20 23 11.8 na 2.0 tr 6.0 27 800 1.1 1.6 na DIRECTIONAL SURVEYS 26 MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/26/2009 Wednesday [X] NO CHANGE (SEE PRIOR RPT) 00:00 01:30 On line pumping & bacck on bottom milling at 3364.4' [ ] NEW BHA 01:30 02:40 Mill to 3376.4' for ROP = 10.3 ft/hr. Short trip. _ ROT HRS SINCE INSPEC 02:40 04:00 Mill to 3390.2 for ROP = 10.4 ft/hr TOOL DESCRIP. LENGTH 04:00 06:00 Short trip & back on bottom CTC 0.94 06:00 09:00 Mill to 3430.6' for ROP of 10.7 ft/hr. BPV 1.57 09:00 10:00 Circulate bottoms up, clean out flow cross, back on bottom HD 1.53 10:00 13:30 Mill / Stall to 3442.4' for ROP = 2.7 ft/hr DCS 1.15 13:30, 18:30 Noticed metal shavings in returns at shale shaker. Circulated hole clean & pull out of hole. Rig down Inject- XO 0.70 or Head and drop down BHA. Removed underreamer. Found 2 of 3 cutter blades were woren out. MM 10.80 Replaced all 3 cutter blades. Had 4.125" gage ring made. New cutters are in gage. Make up underreamer UR/BIT 4.58 to BHA. PU Injector Head & lubricator. Make up lubricator and trip in hole. 18:30 20:00 On bottom & start milling at 3442.4' 20:00 22:00 Crew change, Pre -tower Safety Meeting, shutdown pump to replace screen on rock catcher. Tried to start milling 3458'. Trouble shoot MicroMotion Out being plugged. 22:00 23:59 Still getting metal back with new cutters. Discuss options and decide to trip to lay down the Underreamer / cement mill. Pick up a 3.75" PDC bit. Circulate flowlines clean. TOTAL LENGTH 21.27 NOTE: Received diesel storage tank and 1356 gal fuel.. WEIGHT IN MUD DATE LAST BOP TEST l 8/23/09 TORQUE ROT IS/0 IP /U PREVIOUS TOTAL COST $484,969 OPERATOR "S REP Eddie Wright DAILY COST $107,812 CUM TOTAL COST $592,782 1 PETROLEUM • • ENGINEERS MORNING DRILLING REPORT Report # DATE 7 8/28/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 6 3,887 3,887 429 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Tripping for 3.75" PDC bit. Cement 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD. TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO. NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS: Milling cement form 3458 to 3887'. Milled 429 ft in 9.25 hrs for a IROP = 46.3 ft/hr. Average ROP for last 23 hrs = 18.6 ft/hr. Cutting cement with 3.75" PDC bit in 4.26" ID casing is leaving a cement sheath about 0.25" thick. Sheath is breaking up and falling down hole during wiper trips causing sticking problems ulling up and cutting build -up on bottom. CURRENT WEATHER: Wind Direction Wind Speed Temperature 48 -62 and sunshine. BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I 0 0 L B G 0 R #1 #1 #2 #2 1 3.75 Cmt Mill 3,458 260 2 3.75 PDC 429 9.3 46 1 -2 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS CC /30 32nds SAND SOLIDS PPM DAILY TOTAL 21:00 8.8 52 4 33 22 26 30 12.6 na 3.0 tr 7.0 29.0 750 1.4 2.1 na DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/27/2009 Thursday [ ] NO CHANGE (SEE PRIOR RPT) 00:00, 01:00 Continue trip to lay down underreamer /mill and pick up 3.75" PDC bit [ X] NEW BHA 01:00 01:40 Mill from 3458 to 3500' for ROP = roc.xx ft/hr. ROT HRS SINCE INSPEC. 01:40 10:00 Short trip, clean out rock catcher, having problems with pump, make repairs to pump TOOL DESCRIP. LENGTH 10:00 11:15 Mill to 3585.3' for ROP of 10.7 ft/hr. CTC 0.94 11:15 11:25 Wiper trip, bottoms up circulation, BPV 1.57 11:25 11:50 Mill to 3596.7 for ROP = 27.4 ft/hr HD 1.53 11:50 13:30 having problems with obstruction DCS 1.15 13:30, 15:45 Mill to 3654.9' for ROP = 25.9 ft/hr XO 0.70 15:45 16:40 wiper trip, check rocker catcher, pump on line, back on bottom MM 10.80 16:40 17:30 Mill to 3713.4' for ROP 69.0 fUhr PDC bit 0.70 17:30 17:40 Wiper trip 17:40 18:30 Mill to 3749.9' for ROP = 45.0 ft/hr 18:30 18:40 wiper trip 18:40 19:55 Mill to 3800.1 for ROP = 40.2 ft/hr 19:55 20:00 wiper trip 20:00 22:45 Milling at 3850' for ROP = 66.5 ft/hr 22:45 23:00 Wiper trip. TOTAL LENGTH 17.39 23:00 00:00 Milling at 3886.6' for ROP = 36.6 fUhr WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 'TORQUE TROT IS /0 IP /U PREVIOUS TOTAL COST $594,787 OPERATOR'S REP Eddie Wright DAILY COST $82,228 CUM TOTAL COST $677,015 PETROLEUM • ENGINEERS • MORNING DRILLING REPORT Report # DATE 8 8/29/09 LEASE AND WELL NO. AFE NO -SAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B _ 7 4,133 4,133 247 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Reaming with 3.75" PDC bit to break up cement sheath Cement 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS Milling cement form 3887 to 4133'. Milled 246.5 ft in 6.0 hrs for a IROP = 41.1 ft/hr. Lost 11.5 hours c leaningout the large cement cuttings in thicknesse from 0.25 to 0.5" thick and 2-4" in length. Average ROP for last 12.5 hrs = 21.4 ft/hr. Cutting cement with 3.75" PDC bit in 4.26" ID casing is leaving a cement sheath. During back reaming & wiper trips, the sheath is breaking up, falling down hole, & causing stickingproblems. CURRENT WEATHER: Wind Direction Wind Speed Temperature 48 -62 and sunshine. BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT _ HR WT RPM 1 OD L B G 0 R #1 #1 #2 #2 1 3.75 Cmt Mill 3,458 260 2 3.75 PDC 676 15.3 44.3 1 -2 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS. CC /30 32nds SAND SOLIDS PPM _ DAILY TOTAL 13:30 8.7 48 5 28 22 26 29 12.5 na 3.0 tr 7.0 29.0 850 1.3 2.1 na 3,120 14,967 DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/28/2009 Friday [ ] NO CHANGE (SEE PRIOR RPT) 00:00 03:45 Depth at midnight was 3886.6'. Short trip, mill on obstruction at 3620', mill thru cement stringers, & tight [ X] NEW BHA spot at 3620 - 3678', large chunks of cement sheath in returns. Return line plugged up, start out of hole _ ROT HRS SINCE INSPEC 03:45 05:00 Not able to establish flow thru choke to shale shaker pit. Safety meeting to discuss plugged line hazards. TOOL DESCRIP. LENGTH 05:00 05:30 Knock hammer unions loose and found cement sheath chunks 0.25 -0.5" thick & 2 -4" long. CTC 0.94 05:30 11:30 Clean out lines and flow test to tanks. Assemble lines and pressure test. Continue with wiper trip to 3200'. BPV 1.57 Returns continue to be long & slender cuttings. Still cleaning up HD 1.53 11:30 13:30 Back on bottom milling ahead to 3950'. Decision was made to drill cement to top of whipstock at 4129' DCS 1.15 Received verbal approval to drill ahead from AOGCC at 14:50 hrs pending confirmation in email. XO 0.70 13:30 17:00 Back reaming to clean up cement sheath for 3.75" bit drilling inside a 4.276" casing. Lost charge pump. MM 10.80 17:00 18:20 Mill to 4050' for ROP 75.0 ft/hr 3.75" od PDC bit 0.70 18:20 18:30 Wiper trip 18:30 20:00 Mill to 4099.3.0' for ROP = 32.9 ft/hr 20:00 20:10 wiper trip 20:10 21:10 Mill to 4125.1 for ROP = 48.6 ft/hr 21:10 21:20 Stall and recover at 4133 21:20 21:30 Milling at 4133.1, & stalled. Picked up & checked stall at 4133.1 twice. Should be pinch point between top of whipstock at 4129' & top of window at 4140'. TOTAL LENGTH 17.39 21:30 00:00 Back reaming to clean up cement sheath for 3.75" bit drilling inside a 4.276" casing WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 'TORQUE TROT IS 10 IPIU PREVIOUS TOTAL COST $594,787 OPERATOR'S REP Eddie Wright DAILY COST $102,837 NOTE: Received approval to postpone BOPE test until all piping changes have been made & rig ready to :rill window. CUM TOTAL COST $697,624 PETROLEUM • • ' , ENGINEERS '4-- -=� MORNING DRILLING REPORT _... Report # DATE 9 8/30/09 LEASE AND WELL NO AFE NO - DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 8 4,133 4,133 247 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Pull out of hole and wait on IRBP Cement 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS Back reaming with PDC bit to remove cement sheath. Took a 13 bbl gain at 2:51 hr. Pull out of hole and waited on orders. Performed maintenance anc prepared to trip in hole with underreamer (UR) and cement mill. Recorded time and pressures. Opened well & trip into hole with underreaming BHA to 3 Ream down to 4120' and up with UR BHA. Ream and trip in hole, drop ball, circulate hole clean, and trip out. CURRENT WEATHER: Wind Direction Wind Speed Temperature 46 -58 and rain BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM # TYPE 1 2 3 4 OUT HR WT RPM I 0 D L B G 0 R #1 #1 #2 #2 1 3.75 Cmt Mill _ 3,458 260 2 3.75 PDC 676 15.3 44.3 1 -2 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT. VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL 21:15 8.7 32 4 7 1 2 2 12.2 na 1.0 tr 3.0 6.0 22,000 0.6 0.2 na 3,911 21,810 DIRECTIONAL SURVEYS — MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/28/2009 Saturday [X] NO CHANGE (SEE PRIOR RPT) 00:00 02:45 Back reaming to clean up cement sheath for 3.75" bit drilling inside a 4.276" casing. [ ] NEW BHA 02:45 03:30 Finishing wiper trip when well kicked at 2:51 hrs with 13 bbl pit gain. Pull out of hole and close choke _ ROT. HRS SINCE INSPEC 03:30 05:00 Standby and monitor well pressures. Contact Houston offices, Midland office, and Lafayett office. TOOL DESCRIP. LENGTH 05:00 07:30 Monitor well and wait on orders. Discuss approach to original window and Nelchina evaluations. CTC 0.94 07:30 14:00 Contact AOGCC office on North Slope. Perform CTU maintenance on equipment and choke line. BPV 1.57 14:00 15:50 Open master swab valve, 14:09 2624 psig, 15:52 2355 psig HD 1.53 15:50 16:45 Trip in hole with underreamer /mill to clean off cement sheath DCS 1.15 16:45 21:05 Reaming down from 3458 to 4120', three wiper trips, and start back reaming out of hole. XO 0.70 21:05 23:45 Back reaming to clean up cement from 4120 to 3210'. Run in hole to bottom, drop 3/4" ball to divert flow out. MM 10.80 23:45 00:00 Circulate hole clean, pull out of hole. UR/BIT 4.58 Time & Wellhead Pressure.: 2:43 1958 psig, 02:52 2036 psig, 02:55 2229 psig, 0258 2249 psig, 03:30 Z TOTAL LENGTH 21.27 psig, 05.00 2312 psig, 05:54 2313 psig, 07:25 2313 psig, 14:09 2624 psig, 15:39 2355 K WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 I TROT 1S/0 'P!U PREVIOUS TOTAL COST $697,624 OPERATOR "S REP Eddie Wright DAILY COST $119,719 CUM TOTAL COST $817,342 PETROLEUM • ENGINEERS • MORNING DRILLING REPORT Report # DATE 10 8/31/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B I 9 4,133 4,133 247 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Tripping in hole with coil tubing. Safety meeting. Cement 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD, TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS Wait on IRBP, modify plans to cement window, run injections nozzle to 4133', perform injection test at 1 and 2 bpm, pull out of hole, remove injection & nozzle. Decision is to squeeze old window with 15.8 ppg Class G cement. Make up cementing nozzle & trip in hole CURRENT WEATHER: Wind Direction Wind Speed Temperature 48-62 and sun BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I OD L B G 0 R #1 #1 #2 #2 3 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL :00 8.7 35 4 7 1 2 2 12.1 nc 1.0 tr 3.0 _ 6.0 22,500 0.6 0.2 0:00 8.7 32 4 7 1 2 _ 2 12.2 nc na tr 3.0 6.00_ 0.6 0.2 4,063 _ 25,874 DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY 8/29/2009 Sunday [X] NO CHANGE (SEE PRIOR RPT) 00:00 11:00 Perform maintenance on equipment and wait on IRBP. Discuss plans with Rutter & Wilbanks about IRBP. [ ] NEW BHA Modify plans to squeeze window first. Makeup Wash Nozzle with coil tubing connection with dimple _ ROT HRS SINCE INSPEC. connector, crossovers, & check valves. TOOL DESCRIP. LENGTH 11:00 13:40 Stab injector head onto well. Test wash nozzle BHA, trip in hole, start pumping at 2.4 bpm and washed to 4133'. Worked coil tubing up & down with no success to get passed 4133'. Decided to run injection test. At 1 bpm, the pressure was 2538 psig on coil tubing circulating system & 2389 psig at the wellhead. At 2 bpm, the pressure was 2842 psig on coil tubing circulating system and 2423 psig on the wellhead. 13:40 20:15 Stop injection test & pull out of hole. Discuss results of injection with Bit Rutter Jr, Mick Francisco, and Ed Burrell. Decision forward is to squeeze window with approximately 100 sacks of Class "G" cement. Cementing personnel on location, Cement bulk trucks arrived and transferred cement to bulk tank. Review "Laboratory Cement Test Report, Ahtna #1 -19A, Squeeze Field Blend" indicate Class "G" cement will mix to 15.8 ppg with antifoaming agent, a dispersent, GASBLOK and accelerator. Field test show pumping time is 4 hrs for a 100 Bc consistency. 20:15 23:00 Assemble slick cementing BHA with coil tubing connector, crossovers and check valves. Pick up injector head and stab on top of wellhead. Trip into well for squeeze cementing job. 23:00 00:00 Trip into well with coil tubing. Discuss cementing operations with coil operator and cementer. TOTAL LENGTH WEIGHT IN MUD DATE LAST BOP TEST 8/23/09 'TORQUE IROT IS /0 IP /U PREVIOUS TOTAL COST $817,342 OPERATOR "S REP Eddie Wright DAILY COST $74,244 CUM TOTAL COST $891.586 PETROLEUM • • ENGINEERS ,: -- MORNING DRILLING REPORT _.. _.. Report # DATE 11 9/1/09 LEASE AND WELL NO AFE NO - DAYS MD TVD PROGRESS Ahtna 1-19A Ahtna #1 -19B 10 4,133 4,133 247 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Continue Squeeze #3 with 200 sacks Class G cement Cement 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD. TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS End of coil tubing at 4033' for squeeze #1. Safety meeting. Pump 5 bbls water ahead of 100 sacks Class G cement, displaced with 24.7 bbls of fresh water. Treating pressure rose from 2250 to 3065 psig. WOW 12 hrs. Pressure up and trip in hole. Did not tag any cement. Pick up & establish pump in rate at 1 & 2 bpm. Start planning squeeze #2. Start with 5 bbls water. Mixed & pumped 28 bbls cement with no evidence of squeeze. Overdisplaced & started plans for cement squeeze #3. CURRENT WEATHER: Wind Direction Wind Speed Temperature 48-62 and sun BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I 0 D L B G 0 R #1 #1 #2 #2 3 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHP MUD COSTS TIME WT. VIS. CC/30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY Monday, August 31, 2009 [X] NO CHANGE (SEE PRIOR RPT) 00:00 00:30 The coil tubing was set with end of tubing at 4033'. Conducted Pre -Job Safety Meeting [ ] NEW BHA 00:30 01:05 The coil tubing had 10 bbls of freshwater inside. The cementing program started with 5 bbls of freshwater _ ROT. HRS SINCE INSPEC. & 100 sacks (20.8 bbls, 15.8 ppg, yield 1.16) was mixed and pumped. The treating pressure slowly rose TOOL DESCRIP. LENGTH from 2250 to 3065 psig while wellhead pressure rose from 2320 to 2420 '. Cement displaced to the end of the coil tubing with 24.7 bbls. TOC was calculated to be 4020'. Notified AOGCC at 11:30 am for BOPE Test on 911109. 01:05 01:30 Start out of hole, stopped two times to displace the hole clean. Shut well in for WOC -12 hrs. 01:30 13:30 WOC and equipment maintenance. Pick up underreamer /mill BHA and pick up injector head with lubricator. 13:30 15:00 Make up injector head & lubricator to wellhead. Pressure lubricator to 2300 psig & open master valve. Trip in hole. Work coil tubing string at various depths to verify coil pickup and slack off weights. No tag from 4033 to 4100. Tag top of whipstock at 4129'. No evidence of cement in casing. 15:00 19:30 Pull up to 4,003', start pumping into well. No evidence of any cement in casing. Pumping mud into well with 1 bpm at 2500 psig and 2 bpm at 2550 psig. Pump water spacer for next cement squeeze with coil at 3950' 19:30 21:00 Start mixing cement and pumping squeeze #2. Having trouble pumping cement. Continue to pump total of 28 bbls cement. Displace cement to end of coil with 24.7 bbls. Have meeting to discuss shortage of cement & no increase in pressures at wellhead. Over displace cement to prepare for squeeze #3. 21:00 00:00 Work on identifying correct bulk trailer for Class G cement. Move trailer to location & transfer bulk cement TOTAL LENGTH to bulk tank. Add cement additives to mix water. Hold safety meeting & discuss cement squeeze. WEIGHT IN MUD DATE LAST BOP TEST I 8/23/09 'TORQUE ROT 1S/0 P U PREVIOUS TOTAL COST $891,586 OPERATOR "S REP Eddie Wright DAILY COST $111,101 CUM TOTAL COST 51,002,687 PETROLEUM • • ENGINEERS • ` --_ MORNING DRILLING REPORT ,, Report # DATE 12 9/2/09 LEASE AND WELL NO AFE NO. DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 11 3,950 3,950 247 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Successfully completed BOPE Test. Tripping in hole to tag top of cement. _ Cement 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS Trip in hole to 3950' & start cement squeeze #3. Mixed & pumped 200 sacks Class G cement. Displaced to end of cod tubing with 24.7 bbls. Pulled out of holle. Started WOC while working on wellhead change. Hard line piping was not installed. Assembled hammer union piping. Started BOPE weekly test with AOGCC inspector on site. CURRENT WEATHER: Wind Direction Wind Speed Temperature 48-62 and sun BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM # TYPE 1 2 3 4 OUT HR WT RPM 1 OD L B G 0 R #1 #1 #2 #2 3 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY Tuesday, September 1, 2009 (X] NO CHANGE (SEE PRIOR RPT) 00:00 00:15 Trip in hole to 3950' for squeeze #3. Pump 5 bbls of freshwater as spacer into coil. [ ] NEW BHA 00:15 00:38 Mix & pump 200 sack (41.5 bbls) Class G cement at 15.8 ppg. _ ROT HRS SINCE INSPEC. 00:38 00:54 Start displacement with freshwater down coil. Pump 24.7 bbls to have cement out of coil. TOOL DESCRIP. LENGTH 00:54 02:00 Pull out of hole with coil tubing to surface. Disconnect injector head off well. Rig down BHA. 02:00 07:00 Set injector head on peg and wait on cement. 07:00 17:45 Work on piping & move swab valve from below to above CT head with the two flanged adapers, studs & nuts. Start setting in the Gas Buster. 17:45 18:10 Install flanged valves on flow cross. Did not assemble flanged hard line for choke & kill lines. Need to replace elbows with flow cushion tees. Assemble 15,000 psig hammer union lines with valves & chicksons. Work on hooking up gas buster piping. 18:10 00:00 Fluid pack BOPs for BOPE Test. AOGCC inspector on site to witness pressure testing. Began testing choke manifold and wellhead BOPs. Note: BOPE Test successfully completed and AOGCC inspector departed location at 01:30 hrs on 9/2/09 TOTAL LENGTH WEIGHT IN MUD DATE LAST BOP TEST 9/2/09 'TORQUE 'ROT IS/0 IP /U PREVIOUS TOTAL COST $1,002,687 OPERATOR "S REP Eddie Wright DAILY COST $79,601 CUM TOTAL COST $1,082,287 PETROLEUM • ENGINEERS MORNING DRILLING REPORT Report # DATE 13 9/3/09 LEASE AND WELL NO.. AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 12 4,090 4,090 247 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Tested lubricator and starting in the hole with GR/CCUCliper log. NA 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD, TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS. Complete AOGCC inspection and testing of BOPE. Make up nozzle to trip in hole. Well is pressuring up. Pick up underreamer /cmt mill and start in hole Tagged hard cemetn at 3832.7'. Pull out and lay down underreamer /cement mill. Trip in with PDC drill bit and drill down to 4090. LD PDC bit and pick up underreamer /mill. Clean out sheath of cement to 4090 ". Welders are making changes to piping as directed by AOGCC rules. Strt moving equipmen to install choke line. Hooking up some of gas buster. Small incident on opening cam -Ion CURRENT WEATHER: Wind Direction Wind Speed Temperature 48 -62 and sun BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I OD L B G 0 R #1 #1 #2 #2 3 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT. VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL 23:00 8.6 12.1 21,500 2,625 33,748 DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY Wednesday, September 2, 2009 [X] NO.CHANGE (SEE PRIOR RPT) 00:00 01:30 Successfully complete BOPE testing. [ ] NEW BHA 01:30 04:00 Make up BHA and drift with 3/4" ball. Work on IN MicroMotion gage. Fluid pack and low pressure test. _ ROT HRS SINCE INSPEC High pressure test . Still having problems with MicroMotion gage. TOOL DESCRIP. LENGTH 04:00 05:00 Open well and pressure bled off from 2000 to 700 psig. Open well & start in hole. Wellhead pressure built up to 1000 psig in 15 ft into well. Shut down and pressure test well head to 3000 psig. Well held 3000 psig. 05:00 07:30 Lay down BHA and pick up Baker underreamer BHA. Pick up and make up to wellhead. Trip in hole & tag cement stringers, hit hard cement at 3832'. Start pumping at 2.5 bpm at 3621.4'. 07:30 14:45 drill cement from 3621 to 3832.7'. Pull out of hole, lay down UR BHA. Pick up 3 -3/4" PDC bit and drill to 4090'. Change to UR BHA. Clean out cement sheath with wiper trips. 14:45 21:00 At surface with UB BHA. Lay down tools. Welders making changes to choke and kill lines. Flush surface flow lines. Tear down piping from BOPE to choke manifold. 21:00 21:30 Un -hook hoses to allow fork lift access to Gas Buster. Incident with cam -lock fitting that still had pressure No one was injuried. Shut down and assemble worker for Safetly Meetg 21:30 00:00 Move equipment around on location. Work on gas buster. Work on setting up wireline crane and truck. Positionm wireline logging unit. Test master filed. TOTAL LENGTH Note: BOPE Test successfully completed and AOGCC inspector departed location at 01:30 hrs on 9/2/09 WEIGHT IN MUD _ DATE LAST BOP TEST 9/2/09 'TORQUE J TROT 1S/0 IP,U PREVIOUS TOTAL COST $1,082,287 OPERATOR "S REP Eddie Wright J DAILY COST $80,126 CUM TOTAL COST $1.162.413 PETROLEUM • ENGINEERS • MORNING DRILLING REPORT Report # DATE 14 9/4/09 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 13 4,084 4,084 0 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Preparing to set whipstock with bottom at 4065' NA 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS. Rigged up Schlumberger & tried to get correlation log. Logging unit having problems with winch operations. Waited on mechanic and technician to trouble shoot problems. Got correlation log. Applied pressure to lubricator to perforate at 772 psig underbalanced. Perforated at 4072.8- 4074.8' with 12 holes. Very limited injection as pressure rose to 2800 psig. Shot second perf gun at 4072.8- 4074.8 with 12 holes. Still have limited injection. CURRENT WEATHER: Wind Direction Wind Speed Temperature 29 with clear skies. BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I 0 0 L B G 0 R #1 #1 #2 #2 3 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL 23:00 8.6 12.1 21,500 2,625 36,374 DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY Thursday, September 3, 2009 [ ] NO CHANGE (SEE PRIOR RPT) 00:00 03:00 Rig up Schlumberger wireline unit for GR/CCUCaliper. Tested lubricator to 3000 psig. Start in the hole. [ ] NEW BHA Logging unit having problems controlling winch motion for travel up or down hole. ROT HRS SINCE INSPEC. 03:00 06:00 Waiting on Schlumberger repair man &/or second logging unit. Repair man & technician to fly to Glennallen TOOL DESCRIP. LENGTH 06:00 12:00 Waiting on Schlumberger technician & mechanic. Worked on unit. Logging unit did not get a GR/CCUCalip log. Metal cuttings on CCL. Ran 8" gas line off gas buster to east edge of location. Used an 8" hose to bend north. FESCO laid 8 "x2" crossover & 2" line to Northeast corner. FESCO rigged up flare stack. 12:00 19:45 The logging unit was finally able to get a correlation log with GR/CCUCaliper. Log was made from 4084' to surface. Caliper log showed a cement sheath from 3836 to TD. Made -up first perforating gun & tripped in hole. Applied 1591 psig to lubricator to perforate approximately 772 psig under balanced. Perforated at 4072.8- 4074.8' with 2 shots per foot (12 holes, 0.64" od) at 18:47 hrs. Lubricator pressure dropped from 1591 to 1330 psig. Pull slowly up passed 3836'. Stopped at 250' 19:45 20:15 Pull up into lubricator with perf gun, shut in well at swab valve. Started monitoring pressure below swab valve. Pressure was 1620 psig. 20:15 21:15 Pressure inside the 5" casing increased to 2091 at 20:25, 2291 at 20:31, 2250 at 20.35, 2266 at 20:40, 2271 at 20:45, 2274 at 20:50, 2275 at 20:55 & 2278 at 21:05. 21:15 21:30 Not able to get an injection rate as pump pressure increased to 2800 psig. Decided to shoot 2nd gun. 21:30 00:00 Picked up 2nd perf gun & trip in hole. Wellhead pressure was 2360 psig. Perforated 4072.8- 4074.8' with TOTAL LENGTH 6 shots per ft (12 holes, 0.37" od). Pressure dropped to 2215 psig, then increased '0 2222 psig. WEIGHT IN MUD _ DATE LAST BOP TEST 9/2/09 'TORQUE 'ROT IS /0 IP /U PREVIOUS TOTAL COST $1,162,413 OPERATOR "S REP Eddie Wright DAILY COST $139,356 CUM TOTAL COST $1.301,769 PETROLEUM ENGINEERS MORNING DRILLING REPORT Report # DATE 15 9/5/09 LEASE AND WELL NO AFE NO - DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 14 4,053 4,053 0 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Waiting on Cement (WOC) NA 4,650 MD 4.650 TVD LAST CASING AND SHOE TEST LINERS - OD, TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS. Not able to establish an injectivity rate into perforatings from 4072 - 4074'. Make up whipstock & set on electric line from 4053 to 4065'. Rig down electric line, BOPE & crane truck. Change out hammer union piping for flanged kill line & test to 5000 psig. Make up BHA and trip inhole to 4052'. Flow test MicroMotion flow sensor. Pump 5 bbls Class G cement into casing & pull up to 3157'. Pressure up to 4650 psig. Release pressure and pressure to 3500 psig. Pressure dropped to 2580 as 3.5 bbls cement was displace from 3955 to 4052'. Trip out with coil tubing holding 2500 psig. WOC. CURRENT WEATHER: Wind Direction Wind Speed Temperature 29 with clear skies. BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM TYPE 1 2 3 4 OUT HR WT RPM I 0 D L B G 0 R #1 #1 #2 #2 3 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS, CC /30 32nds SAND SOLIDS PPM DAILY TOTAL 23:00 8.4 27 2,625 38,996 DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY Friday, September 4, 2009 [ ] NO CHANGE (SEE PRIOR RPT) 00:00 01:30 Not able to establish an injectivity profile with 24 hole from 4072.8- 4074.8'. Make up whipstock [ ] NEW BHA 01:30 02:30 Open well and trip in hole on electric line with settting tool and whipstock. Set whipstock at 4053 -4065' ROT. HRS SINCE INSPEC 02:30 03:40 Pull out with electric line to surface. Verify that setting tool fired and released whipstock. Rig down the TOOL DESCRIP. LENGTH lubricator, crane truck, and wireline BOPEs. 03:40 06:00 Rig down the chicksons and hammer unions on the kill line. Bolted up flanged piping from pump skid to the outer flanged valve on the kill line. 06:00 08:00 Assemble cement BHA to squeeze cement around whipstock and thru perfs. Fluid back injector head. Conduct low pressure test to 250 psig for five minutes. Conduct high pressure test to 5000 psig for 30 minutes on flanged kill line piping. 08:00 12:45 Rigging up cement equipment. Testing lines. Safety meeting to discuss cementing operaitons. Trip in hole with coil tubing and cement BHA to 4048'. Trouble shoot MicroMotion flow sensor as compared to fluid volume pumped by Schlumberger cementing unit. 12:45 14:00 Pumped 5 bbls freshwater, 5 bbls of Class G cement (15.8 ppg, 1.16 yield, 24 sacks and additives. Displaced to cement BHA with 19.7 bbls freshwater. Pumped cement into casing while moving coil tubing up form 4052 to 3157'. Pressured up to 3000 psig, no movement of cement. Released pressure to zero & repressured at 0.25 bpm. Formation started taking fluid at 3500 psig. Pressure decreased to 2580 as 3.5 bbls cement were squeezed into perforations. Estimated top of cement at 3955'. TOTAL LENGTH 14:00 00:00 Pull coil tubing out of hole maintaining 2500 psig wellhead pressure. SI well with 2500 psig. WOC. WEIGHT IN MUD DATE LAST BOP TEST 9/2/09 (TORQUE TROT IS /0 IP /U PREVIOUS TOTAL COST $1,301,769 OPERATOR "S REP Eddie Wright I DAILY COST $293,347 CUM TOTAL COST $1.595,116 PETROLEUM ENGINEERS - ® MORNING DRILLING REPORT T 1 Report # DATE 16 9/6/09 LEASE AND WELL NO AFE NO - DAYS MD TVD PROGRESS Ahtna 1 -19A Ahtna #1 -19B 15 4057' ELM 4057' ELM 4 PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH Milling window at 4057' ELM (4067' CTM). NA 4,650 MD 4,650 TVD LAST CASING AND SHOE TEST LINERS - OD, TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO NA NA 0 Schlumberger CTU BRIEF DESCRIPTION OF OPERATIONS. WOC on cement squeezed over whipstock and thru perfs at 4072 - 4074'. Pick up Underreamer /mill BHA & ream to 3995'. Pull out for maintenance on coil tubing, to change on hydraulic drive motor on coil reel, & to work on MicroMotion flowlline sensors. Make up window milling BHA and trip into hole. Continue reaming thru cement. Started milling window at 21:07 hrs at 4054.3' ELM (4064.3 CTM). CURRENT WEATHER: Wind Direction Wind Speed Temperature 29 with clear skies. BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZE MAKER/ NOZZLES DEPTH FTG HOURS FT/ BIT ROT DULL CONDITION LIN SPM LIN SPM # TYPE 1 2 3 4 OUT HR WT RPM I 0 ID L B G 0 R #1 #1 #2 #2 4 3.80 7,125,418 4 3.0 1.33 MUD PROPERTIES, MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV YP GELS PH FILT CAKE % % MBT CHLORIDES PF MF HTHF MUD COSTS TIME WT VIS. CC /30 32nds SAND SOLIDS PPM DAILY TOTAL 23:00 8.4 38 8,681 47,680 DIRE CTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V DEPTH ANGLE TION VKB , SECT DEPTH ANGLE TION VKB SECT TIME OPERATIONS IN SEQUENCE (0000 to 0000) BOTTOM HOLE ASSEMBLY Saturday, September 5, 2009 [ ] NO CHANGE (SEE PRIOR RPT) 00:00 02:00 WOC on squeezed cement with estimated TOC at 3955' [X] NEW BHA 02:00 02:30 Open swab valve and bleed down pressure to 782 psig. Pumped pressure up to 3000 psig for 5 min & ROT HRS SINCE INSPEC. held good. Bled pressure to zero and monitor zero flow to tank for 5 min. Close swab valve. TOOL DESCRIP. LENGTH 02:30 05:00 Pick up underreamer /mill BHA and make up to well. Open swab valve & trip into 3840'. Tag cement at 384( 2 -3/8" CTC 0.95 as shown on the caliper log. Ream down to 3873.8' DFCV 1.56 05:00 14:00 Reaming to 3995', pull out of hole, work on MicroMotion flowline sensors & rigging down underreaming HLHD 1.50 BHA. Breakout tools and replace coil tubing connector. Work on MicroMotions flowline sensors. DCS 1.15 00:00 19:50 Replaced hydraulic motor on reel. Make up window milling BHA, open swab valve & hit obstruction at XO 0.77 3900', tag cement at 4029.7'. Displaced hole with new mud MM 10.80 19:50 20:00 Stopped reaming, mud not passing thru shale shaker screens. MI using pressure washer to clean screens. DIA MILL 1.18 20:00 21:00 Back on with pump at 2.5 bpm at 838 psig. Milling at 1 -1.5 ft/min, short trip, ROP increased at 4053'. DIA BIT 0.55 Coil depth at 4063. Find pinch point at 4064.5' 21:00 00:00 Start milling window at 21:07 hrs. Time milling, 22:20 milled 1 ft of window, continue milling window. Window at 4054.3' ELM - Electric Line Measurement (4064.4' CTM -Coil Tubing Measurement). Will make approximately 10 -ft correction to coil tubing depth on next report. TOTAL LENGTH 18.46 00:00_ Note: Correction to SLB Costs for perforating, setting whipstock, & standby. WEIGHT IN MUD DATE LAST BOP TEST 9/2/09 'TORQUE TROT IS /0 IP /U I PREVIOUS TOTAL COST $1,590,316 OPERATOR'S REP Eddie Wright DAILY COST $23,311 CUM TOTAL COST $1,613,627 PETROLEUM NEWS • WEEK OF SEPTEMBER 27, 2009 • E X P L O R A T I O N & P R O D U C T I O N End of the road Rutter & Wilbanks finally gives up on its attempt to find ^ 0) c new gas resource at its Glennallen gas exploration well � By ALAN BAILEY It is unclear at this point CD0"1-05-C Petroleum News whether Rutter & Wilbanks N early five years after starting its will do any further exploration gas exploration drilling project in the Glennallen region. f• near Glennallen in Alaska's Copper t River basin. with something in excess the find. One purpose of drilling the (� b c i S of S20 million now expended, and second sidetrack was to determine having made multiple attempts to whether the water carne from the gas prove out what appeared to be a reservoir or from somewhere higher pi omisnng natural gas resource, in the well. perhaps at a location in Texas -based Rutter & Wilbanks has the well that could be sealed off. finally thrown in the towel on its Ahtna 1 -19 wildcat well. Gas in the Nelchina The company is plugging and When Rutter & Wilbanks drilled abandoning the well, Bill Rutter 11 . the Ahtna 1 -19 well in 2005, it failed Rutter & Wilbanks vice president, to find gas at the target depth o p told Petroleum News Sept. 23 7.500 feet but suspected the existence, e ' Aftei a two -yeas pause in drilling of a gas resource in the Nelchina at activity. while Rutter & Wilbanks around 4.300 feet. Unfortunately. tried to secure the use of a suitable however. the use of heavy drilling drilling rig for continued testing at mud as a consequence of exceptional - the well. a Schlumherger coiled tub- ly high formation pressures at a depth mg unit has been drilling a sidetrack of about 1,200 feet had damaged the well, the Ahtna 1 -1915. into Nelchina Nelchina reservoir around the well sands. to test what Rutter believes to After an unsuccessful attempt in be a gas resource in the range of 50 2006 to penetrate the damaged sec - billion to 150 billion cubic feet. An non of reservoir rock using a Cad earlier sidetrack. the Ahtna 1 -19A, Pressure Central snubbing unit, had found the gas in 2007. but execs- Rutter & Wilbanks returned in 2007 sive water flow from the well had raised questions over the viability of see GLENNALIEN WELL page 15 continued from page 5 But testing of the well, rendered diffi- ' GLENNALLEN WELL cult by the narrow diameter of the coiled tubing and requiring a special perforat- to drill the Ahtna 1 -19A sidetrack with ing gun to be brought up fiom Texas. resulted m the production of more water the same coiled tubing unit that it has front a high - pressure, underground been using this year But this year's attempt to prove the source. viability of the 2007 gas find has come "Once 1 saw that pressure 1 knew we to naught. were tied," Rutter said. ". There's no After auguring down through the rework you can do inside of 2 -inch tub - cement that had been used to plug the ing. so 1 gave up" well in 2007 and then using fresh cement It is unclear at this point whether to "squeeze" the subterranean channel, Rutter & Wilbanks will do any further thought to be the source of the pesky exploration in the Glennallen region. • water inflow, the drillers ran out the new sidetrack about 40 to 50 feet from the The Copper River Record contributed old well. to this story. • Safety Lift Hoists 4 • Proof Load Certification roaszwlik. [11. • glit ;O ra every winter,* sound environmental management system and quality nonce between success and falure. onpany delivering a wide range of technologies, services and equipment iainly throughout the global oil and gas industry. • • ir -A (Ti) ri I A R \ u ir t" _ 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 Mr. Eddie Wright Project Consultant Rutter 85 Wilbanks ‘ 301 S. Main Street, Suite B O�] Midland, TX 79702 p� i Re: Exploratory Field, Exploratory Pool, Ahtna # 1 -19A Sundry Number: 309 -300 Dear Mr. Wright: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Sea_mount, Jr. Chair DATED this 2 day of September 2009 Encl. 9 " a 'd � KA STATE OF ALAS k � ` i d ` R ALAS�IL AND GAS CONSERVATION COMMIS N ``- ,N _ � - if j COV q APPLICATION FOR SUNDRY APPROVALS , ,; a „ G ;J , y ,„ C 20 AAC 25.280 `c ; „ j �, 1 1. Type of Request: Abandon El Suspend ❑ Operational shutdown ❑ Perforate 0 Waiver ❑ Other 51 After casing Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Underbalanced / Change approved program ❑ Pull Tubing ❑ Perforate New Pod ❑ Re -enter Suspended Well ❑ Operations 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Rutter & Wilbanks Corporation Development ❑ Exploratory frA 207 -085' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 301 S. Main St, Suite B, or Box 3186, Midland, TX 79702 50-099- 20005 -01- 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: Ahtna #1 -19A - Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation: ,- -s',. 7 7 driedr KB Elevation (ft): 11. Field/Pool(s): - Ail. Sec. 19, T-4 -N, R -3 -W 110. 2037' KB e'r' �' y Ai 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): PBTD 4536' ELM (TOC) IPBTD 4536' ELM I I 1 - (99) 4536-4635' Casing Length Size MD TVD Burst Collapse Structural Conductor 78' BGL 13 -3/8 78' BGL / 78” BGL Surface 1226 9 -5/8 1226 / 1226 5,750 3,090 Intermediate 1915 7 1915 7 1915 7240 5410 Production 4639 5" 4639 4639 10,140 10,490 Liner 588 3 -1/2 5165 r 5165 10,160 10,540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4341' 4341' NA 1 NA NA Packers and SSSV Type: Packers and SSSV MD (ft): N NA NA 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ig - Development ❑ Service ❑ Ai" 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 8/29/2009 J Oil ❑ Gas ❑ Plugged Abandoned 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 1,..-1. A4 vt 'f 2 q 1 Teo? 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Eddie L. Wright Title Project Consultant Signature / io r ` /'Phone 713 - 301 -2216 Date 8/29/2009 COMMISSION USE ONLY ' Conditions of approval: Notify Commission so that a representative may witness 'Sundry Number: „ v ! ""✓( /d Plug Integrity ❑ BOP Test 13d Mechanical Integrity Test ❑ Location Clearance ❑ Other: --r'P,S f $ o f t t o soo p t ,,, . Subsequent Form Required: 1 0 -- 4 0 7 t 0 „_ ,,,,,o, (( ex /4 T ; 0 0 ✓ at' 14 a �' �'�'Ct . 4 i j APPROVED BY Appro `` COMMISSIONER THE COMMISSION Date: 7/ 1 ��b`fm 10-403 Revised r • /2006 / Submit in Duplicate ORIGINAL 4 - 8 zoo • . Sundry Notice for Underbalanced Operations Rutter & Wilbanks Corporation Ahtna #11 -19A Description of Operations Continuing to clean out the casing under pressure is critical to our operations of the Ahtna #1- 19A well. Our efforts to maintain communications with the window from 4140 -4148' is vital to our determination of the formation pressure of the Nelchina formation. The window will be isolated with an Inflatable Retrievable Bridge Plug (IRBP) set above the window. Then we will perforate and squeeze the channel leading to the high pressure water above the window. Our safe operations are supported by the following equipment and people during these underbalanced operations for Nelchina Formation evaluation and abandonment: 1. Our Coil Tubing Unit (CTU) has bi- directional slips in the injector head to maintain i control of the coil tubing. 2. We have a quad combination of BOPs to allow blind/shear rams and pipe rams above and./ below the flow cross. 3. We have a hydraulic operated choke and a manual choke to regulate the flow in the choke line as well as by -pass line. 4. We are using the MircoMotion flow line sensors on the pump inlet and choke line discharge to monitor density, rate, and temperature. 5. We have the option to shut the well in and maintain well control. We are in a Plug and Abandon mode on a high pressure water source. 6. Weighting up the mud could present a problem with the high pressure water influx. We could plug up the window with barite and not be able to test the Nelchina Formation. 7. Leaving the window and Ahtna #1 -19A sidetrack hole open to the high pressure water flow from above could compromise the Nelchina Formation. 8. Our crews are experienced Schlumberger coil tubing workers with an onsite Schlumberger CT manager. 9. Our initial SICP of 2043 and Stabilized SICP of 2280 psig are less than 50% of the rated/test pressures of our 4 -1/8" 5,000 psig master valves. To accomplish this effort, we need to proceed with the following steps: 1. Continue cleaning out the cement sheath from 3458 -4133' while allowing the well to have partial flow from the formation. Operating underbalanced is critical to keeping the formation open through the window. This cement sheath was caused by our 3.75" OD PDC bit drilling through the 5" casing (4.276" ID). We have recovered cement pieces that are 0.25 - 0.50" thick and 1 -3" long. Leaving this cement sheath is not an acceptable risk for running the IRBP. 2. Run an IRBP on coil tubing and set the IRBP at 4100' which is above the window. This will isolate the pressure from the high pressure water. Cover the IRBP with sand or calcium carbonate up to a depth of 4070'. 3. Perforate at 4065 -4066' with a minimum of 6 spf on a 60 degree phasing with an underbalanced pressure of 800 psig (1100 psig). With the initial SICP pressure of 2043 psig / and initial mud weight of 8.8 ppg, the formation pressure at 4065 ft is 3903 psig. With 15.0 • • ppg wellbore fluid, the applied pressure will be 732 psig. ' The applied pressure will be based on the weight of the fluid in the hole at the time of perforating. This will be affected by the formation water and our ability to circulate heavier mud weight 4. Establish an injection rate at 0.5 bpm and record the pressure. Continue to increase the injection rate in 0.25 bpm increments until an equivalent mud weight of 20 ppg is obtained or the rate is 2.5 bpm. 5. The squeeze cement volume wil ; based on the injection rate. The higher the rate the larger the volume. The minimum is 00 ks for a 0.5 bpm injection rate and the maximum is 200 sacks fora 2.0 bpm. 6. Initially displace 50% of the cement volume through the perforations, shutdown and evaluate the squeeze pressure. Pump an additional 25% of the cement. Volume. Leave the last 2.0 bbls of cement in the casing displacing the cement. 7. If a squeeze pressure of 500 -1000 psig is not reached, pump cement away and mix a larger volume of cement and start squeeze process over 8. When squeeze pressure is seen, pull up and flush out the coil tubing while holding back pressure on cement. Then shut well in with the squeeze pressure. 9. Wait on cement for 18 -24 hours or as determined by surface samples and recommendations from the cement provider. ( t '- 10. While WOC, conduct BOPE test. W ith the IRBP and the cement in place we have the well bore isolated. We can shut two 4 -1/8" 5000 psig master valves and test BOPE above these valves. 11. Trip in and drill out the cement, wash out the sand, and retrieve the IRBP. Hold sufficient , surface pressure to balance the pressure below the IRBP. 12. Perform flow tests and shut in test until the SICP is established. 13. If the SICP is lower, then evaluate additional testing needs to evaluate the gas and water from the Nelchina Formation. 14. If the SICP is the same or higher, plan to squeeze the window with sufficient cement to fill the side track hole. This is approximately 3.3 bbls based on a distance from 4140 to 4341'. 15. Establish a series of injection rates. Mix and pump a sufficient volume of cement to allow the top of cement to be approximately 3950' 16. Proceed with original PTD program with a window at approximately 3940 - 3948'. • RUTTER & WILBANKS CORPORATION Sec 19, T4N, R3W AHTNA #1 -19A API No.: 50- 099 - 20005 -01 Current Wellbore Diagram Well No.: 207 -085 RKB 2037.0 18.3 ; z r y GL 2018.7 SI Wellhead Pressure = 2043 psi, i Depth Casing /Cement 150 'Diesel (3 bbls) 78' BGL 13 -3/8" 68# L -80 Conductor Shoe Squeezed with 18.3 bbls 12-1/4" 1,226 9 -5/8" 40# L -80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" 1,915 7" 26# L -80 BTC Intermediate 66 bbls Class G to surface 3,200 Top of cement (CBL) 8.8 ppg 3,210 PBTD (tagged on 7/2/07) urrearned with ,zed with 3.75" PG... : Cement: 15.8 ppg Class G with 40 # /bbl CEMnet fiber, 1.5 gal /sk Gas co Top of Whip Stock at 4129' Blok, & 0.1 gal /sk Accelerator Cleaned out to 4133.1 11(8-29-09) 4,140 Top of Window Whip Stock Anchor at 4,153' � 4,148 Bottom of Window its__ 41 r_4 4,154 Obstruction in hole Top of Bailed Cement 4,170 z- (tagged 6/14107) Evaluate zone 14,230 4,250' Mechanical Plug 4,220 �— E -Line Perfs: 4232 4250 Drill Perf Tool Channels: 4382 4387 End of Side track at 4341' E -Line Perfs: 4474 4490 4506 4530 Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner F 4,635 Weatherford E -IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L -80 ST -L Intermediate Perforations: 4674 4680 = 53 bbls Class G 4922 4940 4923 4929 4932 4938 5010 5020 5076 5084 5,099 Top of cement 5,165 3 -1/2" 8.8 L -80 ST -L Prod. Liner Total Depth (MD & TVD) ; 5,165 Page 1 of 1 • Aubert, Winton G (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Saturday, August 29, 2009 2:29 PM To: Aubert, Winton G (DOA) Cc: Bill Rutter Jr Subject: Sundry Notice to Evaluation Nelchina Formation thru Existing Window Attachments: 10-403 Sundry Notice for Underbalanced Operations.xls; Sundry Notice for Underbalanced Operations.doc; 2009 Ahtna #1- 19A_WBD_8- 29- 09.pdf Winton, Attached are a Sundry Notice and a Description of Operations for the Ahtna #1 -19A wellbore. Our choice to cleanout the cement and test the existing isolation at the existing window is a prudent and necessary effort to evaluate the Nelchina Formation and to the resolution of the high pressure water flow from above. The opportunity to isolate the window with an Inflatable Retrievable Bridge Plug (IRBP) and squeeze the behind pipe channel is critical to our evaluation of this well and our decision tree to continue with a new sidetrack effort. With the chance of high pressure water diluting the heavy kill weight mud, the barite could settle out and plug off the window. Similar efforts to use heavy weight kill fluids on the high pressure water flow were not successful due to our restricted pump rates with the 2 -3/8" coil tubing. Our cement sheath reaming operations will take approximately 4-8 hours to clean the casing from 3458 to 4133'. When this is complete we will shut the well in and evaluate the pressures. Our IRBP must come from the slope and will not be here until tomorrow. At that time, we will assemble the IRBP and TIH. We will set the IRBP at 4100' which is above the existing window. We will spot 30 ft of sand or calcium carbonate on top of the IRBP. We will trip out, rig up electric line, and perforate the casing. We will perform the squeeze job immediately after the perforating. Wrth the squeeze in place, we will shut the well in and monitor the casing pressure. While waiting on the cement, we will conduct our BOPE test which should be on Sunday. A 24 -hour notice will be provided. Our plan to isolate the high pressure water from above is critical to our evaluation of the formation pressure in the Nelchina Formation. A successful squeeze will lead to an initial testing of the gas from the Nelchina. If the squeeze does not eliminate the high pressure water, we may retum to our or plan to have the Ahtna #1 -19B sidetrack operations. With your verbal permission, we would like to clean out the cement sheath using underbalanced operations as described in the attached Sundry Notice and Description of Operations. If you have any questions, please call my cell phone. I do not have access to the intemet without traveling into Glennallen. Regards, Eddie Wright Project Consultant Rutter & Wilbanks Corp Cell: 713- 823 -7789 9/1/2009 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMIS N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Mi Suspend ❑ Operational shxddowm ❑ Perforate © Waiver ❑ Other MI After casing ❑ Repair well ❑ Plug Perforations ❑ Stknulate ❑ Time Extension ❑ Underbalanced Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Wen ❑ Operations 2. Operator Name: 4. Current Well Class: 5. Permit to Drti Number: Rutter & Wdbanks Corporation Development ❑ Explorgory fri 207 -085 '3 . Address: Stratigraphic ❑ Service ❑ 6. API Number. 301 S. Main St., Suite B, or Box 3186, Midland, TX 79702 50- 099 - 20005 -01 7. If perforating, closest approach in pools) opened by this operation to nearest 8. Well Name and Numbeer property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ Ahtna-19A 9. Property Designation: 110. KB Elevation (ft): 11. Field/Pool(s): Sec. 19, T-4 -N, R -3 -W I 2037' KB 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 'Total Depth TVD (ft): 'Effective Depth MD (ft): 'Effective Depthh TVD (ft): 'Plugs (measured): IJunk (measured): PBTD 4536' ELM (TOC) PBTD 4536' ELM 1 - (99') 4536-4636 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' BGL 13-3/8 78' BGL 78" BGL Surface 1226 9-5/8 1226 1226 5,750 3,090 Intermediate 1915 7 1915 1915 7240 5410 Production 4639 5" 4639 4639 10,140 10,490 Liner 588 3-1/2 5165 5165 10,160 10,540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 'Tubing Grade: !Tubing MD (ft): 4341' 4341' NA NA NA Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal © 14. Well Class after proposed worts Detailed Operations Program ❑ BOP Sketch ❑ Exploratory El Development ❑ Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Operations: 8/29/2009 Commencing perations: Oil ❑ Gas ❑ Plugged fi Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the be of my knowledge. Contact Printed Name Eddie L. Wright Title Project Consultant Signature Phone 713-301-2216 Date 8/29/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness 'Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 Submit in Duplicate • • Sundry Notice for Underbalanced Operations Rutter & Wilbanks Corporation Ahtna #11 -19A Description of Operations Continuing to clean out the casing under pressure is critical to our operations of the Ahtna #1 -19A well. Our efforts to maintain communications with the window from 4140 -4148' is vital to our determination of the formation pressure of the Nelchina formation. The window will be isolated with an Inflatable Retrievable Bridge Plug (IRBP) set above the window. Then we will perforate and squeeze the channel leading to the high pressure water above the window. Our safe operations are supported by the following equipment and people during these underbalanced operations for Nelchina Formation evaluation and abandonment: 1. Our Coil Tubing Unit (CTU) has bi- directional slips in the injector head to maintain control of the coil tubing. 2. We have a quad combination of BOPS to allow blind/shear rams and pipe rams above and below the flow cross. 3. We have a hydraulic operated choke and a manual choke to regulate the flow in the choke line as well as by -pass line. 4. We are using the MircoMotion flow line sensors on the pump inlet and choke line discharge to monitor density, rate, and temperature. 5. We have the option to shut the well in and maintain well control. We are in a Plug and Abandon mode on a high pressure water source. 6. Weighting up the mud could present a problem with the high pressure water influx. We could plug up the window with barite and not be able to test the Nelchina Formation. 7. Leaving the window and Ahtna #1 -19A sidetrack hole open to the high pressure water flow from above could compromise the Nelchina Formation. 8. Our crews are experienced Schlumberger coil tubing workers with an onsite Schlumberger CT manager. 9. Our initial SICP of 2043 and Stabilized SICP of 2280 psig are less than 50% of the rated/test pressures of our 4 -1/8" 5,000 psig master valves. To accomplish this effort, we need to proceed with the following steps: 1. Continue cleaning out the cement sheath from 3458 -4133' while allowing the well to have partial flow from the formation. Operating underbalanced is critical to keeping the formation open through the window. This cement sheath was caused by our 3.75" OD PDC bit drilling through the 5" casing (4.276" ID). We have recovered cement pieces that are 0.25 - 0.50" thick and 1 -3" long. Leaving this cement sheath is not an acceptable risk for running the IRBP. . • 2. Run an IRBP on coil tubing and set the IRBP at 4100' which is above the window. This will isolate the pressure from the high pressure water. Cover the IRBP with sand or calcium carbonate up to a depth of 4070'. 3. 4. Perforate at 4065 -4066' with a minimum of 6 spf on a 60 degree phasing with an underbalanced pressure of 800 psig ( ±100 psig). With the initial SICP pressure of 2043 psig and initial mud weight of 8.8 ppg, the formation pressure at 4065 ft is 3903 psig. With 15.0 ppg wellbore fluid, the applied pressure will be 732 psig. The applied pressure will be based on the weight of the fluid in the hole at the time of perforating. This will be affected by the formation water and our ability to circulate heavier mud weight 5. Establish an injection rate at 0.5 bpm and record the pressure. Continue to increase the injection rate in 0.25 bpm increments until an equivalent mud weight of 20 ppg is obtained or the rate is 2.5 bpm. 6. The squeeze cement volume will be based on the injection rate. The higher the rate the larger the volume. The minimum is 100 sacks for a 0.5 bpm injection rate and the maximum is 200 sacks for a 2.0 bpm. 7. Initially displace 50% of the cement volume through the perforations, shutdown and evaluate the squeeze pressure. Pump an additional 25% of the cement. Volume. Leave the last 2.0 bbls of cement in the casing displacing the cement. 8. If a squeeze pressure of 500 -1000 psig is not reached, pump cement away and mix a larger volume of cement and start squeeze process over 9. When squeeze pressure is seen, pull up and flush out the coil tubing while holding back pressure on cement. Then shut well in with the squeeze pressure. 10. Wait on cement for 18 -24 hours or as determined by surface samples and recommendations from the cement provider. 11. While WOC, conduct BOPE test. With the IRBP and the cement in place we have the well bore isolated. We can shut two 4 -1 /8" 5000 psig master valves and test BOPE above these valves. 12. Trip in and drill out the cement, wash out the sand, and retrieve the IRBP. Hold sufficient surface pressure to balance the pressure below the IRBP. 13. Perform flow tests and shut in test until the SICP is established. 14. If the SICP is lower, then evaluate additional testing needs to evaluate the gas and water from the Nelchina Formation. • • 15. If the SICP is the same or higher, plan to squeeze the window with sufficient cement to fill the side track hole. This is approximately 3.3 bbls based on a distance from 4140 to 4341'. 16. Establish a series of injection rates. Mix and pump a sufficient volume of cement to allow the top of cement to be approximately 3950' 17. Proceed with original PTD program with a window at approximately 3940- 3948'. II RFCEIVED Petroleum Engineers, Inc. Three Riverway, Ste 1500 AUG 3 1 2_009 Houston, TX 77056 Alaska pa, A Gt. Con;), , xsTtt'riission i;:;;;; i r1 .e August 29, 2009 Winton G. Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Mr. Aubert, This letter is to submit the Form 10 -403, Sundry Notice for the Ahtna #1 -19B to use underbalance operations while reaming cement inside the production casing. We are using Schlumberger Coil Tubing Unit with bi- directional slips that is complete with blind/shear rams and pipe rams above and below the flow cross. These are operations in support of the plug and abandonment of the Ahtna #1-19A and in support of our sidetrack operations for Ahtna #1 -19B. This form was emailed to you during the weekend. / If you have some questions, please give me a call at 713- 823 -7789 or email to ewright @peiinc.com. Thanks, ,,,,_ 4 4. - Eddie L. Wright, P.E. Project Consultant for Rutter & Wilbanks Corporation cc: Bill Rutter, Jr., Rutter & Wilbanks Corp., P.O. Box 3186, Midland, TX 79702 • • J � _ ( � [ I l i yam -� -mg ,{� °µ� �'' .�;` p ° � `¢ E 11 6 ft SEAN PARNELL, GOVERNOR co urt4uki L= 1) Li w L, Lni i ALASKA 0114 AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Eddie Wright Project Consultant Rutter & Wilbanks Corporation 010 -1,,,.0 S 5' 301 Main Street, Suite B or Box 3186 Midland, TX 79702 Re: Exploratory Field, Exploratory Pool Ahtna #1-19A Sundry Number: 309 -286 Dear Mr. Wright: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 9 Daniel T. Searnount, Jr. Chair DATED this Z 0 da of August, 2009 Encl. / 0, 1 STATE OF ALASKA "$� r e/ RECEIVED or, 20 ALASK/L AND GAS CONSERVATION COMMIS AUG 1 7 2009 war V C APPLICATION FOR SUNDRY APPROVALS 8/i7itooy 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon 0 - Suspend ❑ Operational shutdown ❑ Perforate Waiver ❑i''.,,n, „°4 r. ,n Other E, Alter casing Repair well ❑ Plug Perforations Stimulate ❑ Time Extensior. 0 Sidetrack Change approved program ❑ Pull Tubing _J Perforate New Pool ❑ Re -enter Suspended Well 0 PrLP ,4 2. Operator Name: 4. Current Well Class: 5. Permit /to Drill Number: Rutter & Wilbanks Corporation Development ❑ Exploratory 0, 207 -085 3. Address: Stratigraphic ❑ Service ❑ 6. Al P' Number: 301 S. Main St., Suite B, or Box 3186, Midland, TX 79702 50-099-20005-01' 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 El No Ahtna #1 -19A 9. Property Designation: / 4,77,04 611 10. KB Elevation (ft): 11. Field /Pool(s7: Sec. 19, T-4 -N, R -3 -W 2037' KB lo.e.,■917,e), ” 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVI7(ft): Plugs (measured): Junk (measured): PBTD 3210' (TOC) PBTD 3210' (TOC) 1 - 3210 -4148' (938') Whipstock (4129 -53') Casing Length Size MD TVD Burst Collapse Structural Conductor 78' BGL 13 -3/8 78' BiL 78" BGL Surface 1226 9 -5/8 1126 1226 5,750 3,090 Intermediate 1915 7 1915 1915 7240 5410 Production 4639 5" 4639' 4639 10,140 10,490 • Liner 588 3-1/2 3-69" 5165 10,160 10,540 Perforation Depth MD (ft): (Perforation Depth (ft): u6iny Size: Tubing Grade: 'Tubing MD (ft): 4232 -4387' (Abandon) 4232 -4387' (Abandon) None Packers and SSSV Type: Packers and SSSV MD (ft): . NA NA 13. Attachments: Description Srllnmaryr of Pro.osal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory E Development ❑ Service ❑ 15. Estimated Date for -—fr 16. Well Status after proposed work: Commencing 174947 00q W Oil ❑ Gas —F4--• Plugged / Abandoned m r w*A 17. Verbal Approval: Data WAG ❑ GINJ ❑ WINJ ❑ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true 9nd correct to the best of my knowledge. Contact Printed Name Eddie Wright / Title Project Consultant Signature • e 73- 823 -7789 Date 8/13/2009 i l s /� COMMISSION USE ONLY Conditions of approval: Notiijf Commission so that a representative may witness ( Sundry Number: 3o9- 7s6:, Plug Integrity ❑ BOP Test " Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1 tSi DO PE 1-o S000 eft". Subsequent Form Required: 10 — 07 �. �z ;' /f! /,,, ' APPROVED BY �® Approved by '* IIII ` . / COMMISSIONER THE COMMISSION Date: ile Form 10-403 Revise606 /2006 0 R 1 G 1 N A L .7fisumsEIFL - 2 4 200 Submit in Duplicate • Petroleum Engineers, Inc. RECEIVED Three Riverway, Ste 1500 AUG 17 2009 1 Houston, TX 77056 Alaska Oil 8 Gas Cons. Commission Anchorage August 14, 2009 Winton G. Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Mr. Aubert, This letter is to submit the Form 10 -403, Sundry Notice for the Abandonment of the Ahtna #1- 19A by re- entering the well, drilling out cement, perforating, squeezing perforations, drilling out excess cement, and setting a whipstock. Verbal permission is requested to allow equipment and materials be mobilized to location starting 8/21. Initially, pressures will be recorded and additional wellhead equipment will be installed by Vetco Gray. The Schlumberger CTU will begin arriving on 8/21 and will be rigged up by 8/23 with BOPE testing. Actual well operations will begin o 8/2 when we open the 4" 5M master valve and start into the 5" casing with the cement drilling and 2 -3/8" coil tubing. Operations should be completed by 9/20/09. If you have some questions, please give me a call at 713- 823 -7789 or email to ewright@peiinc.com. Thanks, —/ Eddie L. Wright, P.E. Project Consultant for Rutter & Wilbanks Corporation cc: Bill Rutter, Jr., Rutter & Wilbanks Corp., P.O. Box 3186, Midland, TX 79702 • • RECEIVED Ahtna #1 -19A AuG i 7 2009 Workover Plan Alaska Oii & Gas Cons. Commission to AnchoraJe Re -Enter Well for Sidetrack Operations Revison 0 August 14, 2009 The following Workover Plan to Sidetrack the Well will be the second attempt and designated at Ahtna #1 -19B. These sidetrack operations are planned to a depth of ±4500' TVD as follows: I. Begin with recording pressures on the Dry Hole Tree and Wellhead wing valves. II. MIRU Schlumberger Coil Tubing Drilling Unit, complete with BOPE, choke manifold, pump(s), and tanks. Test BOPE and choke manifold. Set up mud mixing equipment and water storage tanks. Set up a gas buster for testing the Nelchina formation. III. Drill out the cement in the 5" casing from 3210' to ±3941'. Perforate and squeeze cement to isolate water. Drill out cement. Pickup and set whipstock. Note: See Attachments #1 for the current wellbore diagram, #2 for pictorial view of the Proposed Drilling Plan #1 and #3 to view the Proposed Drilling Diagram #2. Current Condition The original well, Ahtna #1 -19, was drilled to a total depth of 3,705' when the drill string became stuck. The well was plugged back and bypassed to a depth of 4,640' where a 5" casing was set and cemented at 4,639'. Drilling continued to 5,165' where a 3 -1/2" liner was set and cemented on 6/25/05. Perforations from 4,674 - 5,084' were tested with no success in the summer of 2005. In 2006, attempts to re- complete the well utilizing a Perf Drill tool were unsuccessful at milling windows at 4,387' and 4,382'. By an amendment letter, dated 10/18/06, a zone from 4,232- 4,250' was perforated, but did not flow. The well did build pressure to 2,100 psig in 4 hours, but bled to 0 after 1/3 of a barrel flow back. On 10/25/06, a single joint of tubing was landed in the tubing spool to spot a diesel. Operations were suspended until 6/11/07 when a workover began to plugback the open perforations in the Ahtna #1 -19. These operations were successfully completed on 6/14/07. On June 14, 2007, a workover was started to sidetrack the Ahtna #1-19A with a Schlumberger Coil Tubing Drilling Unit. The well was sidetracked through a window (4140- 4148') and drilled to 4341'. Efforts to go back to bottom were not successful as an obstruction was found at 4154'. Permission was received to plug back the well to 3210' on 6/30/07. Plug back operations were completed on 7/3/07. Attachment #1 shows the Current Wellbore Diagram, dated 7/3/07. Operations have been suspended while multiple scenarios were evaluated to sidetrack the well with a CT Drilling Unit, Well Service Rig and conventional Drill Rig. Efforts to Page 1 of 20 • • solve the mixing and pumping of high mud weights and availability of equipment have been researched from early summer until now. Reservoir Conditions The zone of interest (4,230- 4250') was originally drilled with 19.4 ppg mud in the by- pass hole due to the high pressure water zones enco below the 7" casing shoe at 1,914'. Estimated pore pressure of the Nelchina is 7.5,pg. The extra 2 ppg mud weight created an overbalance that forced mud solids into e pore spaces and inhibited any production. The mud logger recorded a drilling break with an ROP increase from 5 fph to 10 fph at 4,320'. The pore pressure in the zone of interest is estimated 17.5 ppg EMW (3931 psig at 4,320'). I Page 2 of 20 • IP Proposed Sidetrack Operations Plan I. Initiate Workover Plan by Record Pressures on tree and wellhead 1. File necessary forms to plan and execute a sidetrack drilling operation with a CT Drilling Unit. 2. Send out notice of start date to all vendors on the Vendor List. ,.-3' Receive notification of approval of Form 10 -401, Permit to Drill the Ahtna #1 -19B Sidetrack. 4. Notify the AOGCC of a start date including the start of moving equipment to location. 5. Notify AOGCC 24 hrs in advance of starting well operations. ` 6. Check pressure on 5" casing with the gauge on the dry hole tree. a. Approximately 300 -500 psig of pressure may be on the 5" casing based on the positive pressure pump into the well at the end of the plug back operations in 2007. b. Attachment #4 shows pictures of Dry Hole Tree, Wellhead and Valves. c. Attachment #5 is a diagram of the Vetco Gray Wellhead. d. Attachment #6 shows the proposed CT Hanger wellhead. e. Verify and /or close the 4" 5M valve on the Dry Hole Tree. f. Close needle valve and remove gauge. Verify that gauge is reading zero. If gauge does not read zero, replace gauge with 0 -5000 psig. g. Add nipples, tee and second needle valve to monitor the pressure and to bled off pressure to an empty drum. h. Close valves and monitor well for pressure buildup. DRY HOLE TREE Needle Valve #2 Nipples, Tee, & gauge T Tubing to drum • I 1 to collect fluid Needle Valve #1 I--. Blind Flange on 4 -1/8" valve i. Open the 4 -1/8" valve and Needle Valve #1 to let pressure to gauge. Record pressure. j. Open downstream Needle Valve #2 to bleed off pressure /fluid to an empty drum. Measure and record the pressure and fluids as the pressure is released. Record pressure each minute. Page 3 of 20 11 k. If pressure does not bleed to zero, contact office for discussion and direction. 1. If pressure bleeds off, close Needle Valve #2 and monitor gauge for any build up of pressure. 7. Check first set of wing valves on the wellhead. These valves have the same pressure as the 4" valve on the dry hole tree. a. Verify both valves are closed. b. Verify that one wing valve has a bull plug with a needle valve and pressure gauge. i. If neither valve has a bull plug, needle valve and gauge, remove the bull plug slowly. Clean out the valve. Replace with a tapped bull plug, needle valve and gauge. ii. If the wing valve has a needle valve and gauge, remove the gauge and verify the gauge reads zero. If gauge is bad, replace with new gauge that reads 0 -5000 psig. iii. Open the needle valve to remove trapped pressure. Remove the bull plug. Clean out the wing valve, needle valve and bull plug. Replace the bull plug, needle valve, and gauge. c. Open the wing valve slowly. Open the needle valve. Verify that the pressure is the same as the pressure on the dry hole tree. 8. Check the second set of wing valves. These valves allow access to the annulus between the 5" and the 7" casing strings. a. Verify both valves are closed. b. Verify that one wing valve has a bull plug with a needle valve and pressure gauge. i. If neither valve has a bull plug, needle valve and gauge, remove the bull plug slowly. Clean out the valve. Replace with a tapped bull plug, needle valves, and gauge. ii. If the wing valve has a needle valve and gauge, remove the gauge and verify the gauge reads zero. Replace gauge, if necessary. iii. Open the needle valve. Remove the bull plug and clean out the wing valve, needle valve and bull plug. Replace the bull plug, needle valve, and gauge. c. Open wing valve slowly. Open the needle valve and verify that the pressure is the same as the pressure on the dry hole tree gauge. 9. Record the pressure on the 5" x 7" casing annulus. a. If the pressure is zero, continue with the next step. b. If the pressure is not zero, begin to bleed the pressure off into an empty drum. c. Monitor the pressure drop with the volume of fluid collected in the drum. Record the pressure for each increment of 3" of fluid collected until the drum is full or the pressure is zero. Page 4 of 20 d. Plot the recorded pressure with the volume of fluid collected. Determine from the graph how much fluid will need to be collected until the pressure is zero. e. Shut in the needle valve when the pressure is zero or the drum is full. f. Record the pressure build -up every minute for the first 30 minutes, then every five minutes for the next hour. Continue to monitor the pressure every 15 minutes for the next three hours or until the pressure has stabilized. g. Report the results of these tests on the Daily Drilling Report. h. If the well had bled to zero, then continue to the next step or as directed by the office. 10. Nipple down and remove the Dry Hole Tree. 11. Nipple up second 4" 5 M valve and the CT Head. The connections on the CT Head are 4" 5M on the bottom connection and 4" 10M top connection. 4" 10M Top Connection (4- 1/16" bore) � , 1 II FRGFA ;F6 �� �,• II i E t� a -: :3 sr 1 :or ExilTIN a: ,'wE +' - .. II. MIRU Schlumberger Coil Tubing Drilling Unit and support equipment Note: Contact the AGOCC Inspectors Office at least 24 hours in advance at / 907 - 659 -2714 by voice, 907 - 659 -2717 by fax, or 907 - 659 -3607 by pager to allow sufficient time for an inspector to be schedule to witness work. 1. Clean up location for coiled tubing operations. 2. Mobilize 2 -3/8" coiled tubing unit. Attachment #7 is the vendor's Equipment List. Attachment #8 the 2 -3/8" coil tubing specifications. Attachment #9 is the BOPE layout. Page 5 of 20 r 3. Rig up 2 3/8 unit on wellhead and test BOPs to 250 psig low and ,000 psig. A coil tubing run may be required to establish correlation to PBTD. 4. Set up mud mixing equipment and water storage tanks. 5. Set up a gas buster for testing the Nelchina formation. This step must be completed before the window is milled. 6. Mobilize 2 -3/8" coiled tubing unit. Attachment #8 is a listing of the vendor equipment and the 2 -3/8" coil tubing specifications. Attachment #9 is the BOPE / layout. 7. Rig up 2 3/8" unit on wellhead and test BOP and choke manifold to 250 psig low and 5,000 psig high. 8. Coil tubing run may be required to establish correlation to PBTD. III. Drill out Cement, Log, Perforate, Squeeze, drill out cement and Set Whipstock 1. Make up cement drilling BHA with a bit, XO, stabilizer, XO, mud motor, XO, connector to the coil tubing bundle. 2. Verify the Whipstock length, Outside Diameters and Inside Diameters. Estimated length is 20 ft. 3. Drill cement from 3210 to 3941', based on collars at 3831, 3877, 3914 an 3956'. If the correlations are off, then drill only to 3900' 4. Run GR/CCL to find collars and get on depth. Position perforation shots at 3932- 3936', with 6 spf on 60 deg phasing for 2 ft (total of 12 holes). Attachment #11 is GR/CCL /CBL log and Attachment #12 and 13 are open -hole composite logs. 5. Evaluate the current mud weight. a. Calculate the additional pressure to pump on the lubricator to allow for a 800 psig under balance. b. Estimated formation pressure is 3540 psi. c. With 9.5 ppg in hole, the pressure is 1940 psig. d. If this gives a 1600 psig under balance, then pump 800 psig of pressure on the lubricator. If values are different, recalculate applied surface pressure. 6. Record surface pressures and mud weights on the Daily Drilling Report. 7. Perforate and observe SI surface pressure. 8. If necessary, POOH and RD E -Line, then trip in the hole to drill additional footage based on GR/CCL log. 9. Circulate hole clean with minimum mud weight in a range of 8.8 -9.5 ppg. 10. If necessary, rerun CCL log for correlation, then perforate 3932 - 3936'. 11. Establish pump in rates at 00.25, 0.50, 0.75, and 1.00 bbls/minute. Review and decide on the cement squeeze volume. Tentative plans are for a0 sack Class G (18.0 ppg, 0.90 yield, 180 ft3, 32 bbls) cement squeeze with GasBlok and additives. Page 6 of 20 NOTE: Actual volume of cement and squeeze pressures will be discussed with Schlumberger, PEI, and office of Rutter & Wilbanks. 12. Mix and spot the cement with the coil tubing. Pull up and perform a braiden head squeeze. 13. Displace 16 bbls into the formation and check squeeze pressure. Limit pump pressure to a value that is less than the estimated fracture gradient of 22 ppg EMW. Limit surface pumping pressure to 1,000 psig. 14. Continue to pump in 4 bbls and check squeeze pressure. If squeeze pressure is above 500 psig. Stop. If not above 500 psig, continue to pump another 4 bbls and check pressure. 15. TIH and drill out the excess squeeze cement and down to a depth of 3941' or based on the GR/CCL log correlation depth and whipstock setting length/depth. 16. Circulate hole clean and have mud weight at 10.0 ppg. 17. Pick up and run BOT whipstock on coiled tubing per service company procedures. Attachment #14 is the BOT milling procedure, the BOT schematic of the Thru- Tubing, CT Mono -Bore RWS whipstock with dimensions and the recommended milling BHA. 18.Space out and set whipstock to start window at a depth of of ±3932'. / This is the end of the Abandonment of the Ahtna #1 -19A Sidetrack Operations. Page 7 of 20 ID • Attachment #1 Current Wellbore Diagram RUTTER & WILBANKS CORPORATION Sec 19, T4N, R3W AHTNA #1 -1 9A / API No.: 50- 099 - 20005 -01 Current Wellbore Diagram RKB 2037.0 18.3 T3107 GL 2018.7 Depth Casing'Cement 150 ' Diesel (3 bbls) iel ji L BGL 13 " # C Shoe 318 Squeezed 68L 80 with 18.3 onductor bis b 12-1/4" 1,226 9 -5r8" 40# L -80 BTC Surface 20 bbls Permaforst & Class G 8-112" 1,915 T 26# L -80 BTC Intermediate 66 bbis Class G to surface 3,200 Top of cement (CBL) 3210' PBTD 3,210 PBTD (tagged on 712'07) Cement: 15.8 ppg Class 0 with 40 #.'bbl CEMnet fiber, 1.5 gaisk Gas Top of Whip Stock at 4129' Blok, & 0.1 galisk Accelerator 4,140 Top of Window Whip Stock Anchor at 4,153' � 4,148 Bottom of Window ----- 4 o 4,154 Obstruction in hole Top of Bailed Cement 4,170 (tagged 6 +14 :07) Evaluate zone ±4,230- 4,250' Mechanical Plug 4,220 E -Line Perfs: 4232 4250 Drill Perf Tool Channels: 4382 = 4387 - End of Side track at 4341' E -Line Perfs: 4474 4490 4506 4530 s Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -112" Liner 4,635 W eatherford e BP ZI":17,S (Inflatable Ret. Ret. BP) 4,639 5" 17.8# L -80 ST -L Intermediate Perforations: 4674 4680 = - 53 bbls Class 0 4922 4940 4923 4929 4932 4938 5010 5020 = = 5076 5084 5,099 Top of cement 5,165 3 -112" 8.8 L -80 ST -L Prod. Liner Total Depth (MD & TVD) 5,165 Page 8 of 20 • Attachment #2 Proposed Ahtna #1 -19A Abandonment RUTTER & WILBANKS CORPORATION sett 1�+, T414. R3W AHTNA #1 -19A / API No.: 50. 098. 20005 -01 Proposed Abandonment Diagram Well No.: 207 - 085 RKB 2037.0 113.3 8 i4'08 GL 2018.7 Depth Casing Cement d 78' BGL 13.3;8' 684 L-80 Ccsrductar Shoe Squeezed with 113.3 teas 12- 1:4' 1.226 9-&8' 400 L-80 BTC Surface 2l teas Permafr.44 & Class G 8-1 2" L 1.415 7' 260 L-80 BTC Intermediate 66 bbls Class G to surtaoe C+3 lnent to be citified out, casing perforated, squeezed with 3.200 TOG iCBL} outside 5' casing cement, & drilled out to prepare 3.210 PBTD 'Tagged in 2007i for Abandonment of #1 -19A 393 PBTD:3940' 3936' 6, Squeeze Perforations � TOC inside 6 casing: 3940' Ij� 2037 Top of% hip 5bods. at 4128 / � 2007 Cement: 1s.6 pap Class G with 40tn'bbl CEMstiba, l.3pat'ak Gas PIA 4.1 :8" hole Drilled with 3.75 x 4.125" bi•centsr bits 2007 Windom 4140.4148 2007W143 Sinds. Anchor at 4,153 20R' abt1ruction in hole 4154' 1�! 1 4 .47.• . TC•� ?6ia4adfi'14b71 4,170 Nelchina Formation MaahaniralPlug 4,230 ► -� ;4,230- 4,320' E•Lns Ports: 4232 4250 - Cril Pad Tod Charndk: 4382 4i 25 psig i 4320° 4397 18.3 ppg EMW Elio Porto: 4474 4490 x007 Sidetrack 4506 4530 — TD: 4341 Tap of canent 4,536 ;placed with .sr bake' 4,''7 Top 00-VT Lie \ '► 4,E35 Wooh r$ d 6 MP 1 ►�� ► +:WAauda Rai 2Ps 4,639 5' 17.99 LAO ST -L hoar madam, Pxbsations: 4674 4990 53bbb Sass G 4922 4940 4923 4929 4932 4938 5010 5020 5776 5084 5.040 Tip of cement. 5.165 3-1:2' 8.8 L -80 ST -L Prod. Liner Total Depth s;MD & TYC1i 5.166 Page 9 of 20 1110 • Attachment #3 Dry Hole Tree, Wellhead & Valves iif rrr 1111! t i ll Y0 0 i H11 L` rrf i! N! , 111 5�.. �� r 1 � '� ' r 7flf r m141 iir� 7` _ ` lrrrrlf "MIA v 1 1 � E - 1y 4 Ffr+; r1 he Nil it rC ; 1x111 , y , .. ^' i 1 /t!!ff f1 J ' llJl ;;i _ ��� r aw 5111 tr1111111 11111 / f11IIJ 1 i \1 11` \ A' ;Willi ^.411140,41 V%4,14�+ i ¼1 �t\� Il t►' ial MIDI \\\' \,, I 1 ' I!N' :i11 {�1 U A \\ti\ti . Vll!llII ∎, i tl ` . ' »� ; . 1 t r 1.) Dry Hole Tree with gauge facing the rear of valve. 2.) Dry Hole Tree with 4 -1/8" valve, Blind flange, Needle Valve #1 (NV #1), and red handle. 3.) Wellhead showing two lower sections with wing valves. ii:$ I r Pi o, t ,' • 4 Ifik. IF i r Upper & lower wellhead valves on left N: ll ow, '' .741/1 P r ' IMP \IIY'' 444044 .00n 0110i 11/44460 . li r Api . ..It Ne 4 111 iv Sr Upper & lower wellhead valves on the right sided. Page 10 of 20 • Attachment #4 Vetco Gray Wellhead 101 � I - I.? I 1 iw . ; I7 LC 11 t •d L /v \ ,. f ) f-' -f�oa' ' "1 ................. mop 2 aliIiii 11 .#o 181 ! ' ,,, , _•r" �Sif' '' I r r , L w 1 " I s7 I 11. a41.,1 1 ► : f f 1111! r : 1 M .%'----- I _' LL ia�I '� �' I111 - I° -� r i , , I "L . 1. / wo • MI alai 4 • 1 0 I ! i i1P !i YT I I •NI - --- 1I ...�,� N . • L3-5e S.1 . A' I • I ,.•.- • N. • � � i � I. I . �r� �I , I , P3:11'" , . . iii 7, ..i , i -,i 1. W 3a # r? a - ,. 0!1 .r. _ 9 -3.6" n* rr.sr. 2-7.e0. ar TOG-- -- -y��� tsG Page 11 of 20 • • Attachment #5 Proposed Vetco Gray Wellhead 4" 10M Top Connection (4-1/16" bore) rr Im t-1 "Et 54 II I 11 PRCPCSFD y if I 1. r 1 ‘4 P- .111r, V4IVI • I • W II gi ‘ :\ 1/4 ' • - L- :1 : 1,1 - ,11101 I Mr-. .1. 13P X3S TING 1.11PMEN' Page 12 of 20 • • Attachment #7 Schlumberger Equipment List 2.375 CT Services: 1071'n 520 5 :ay Unit, 8 t - m inmrn, per dad' 11a73 10712 Ea Hr Unit, aid o,al hoer (land; 10713E930 1E030 F: Pipe Four 7 i_ Charges per run, per it 10713E+370 "a Ea 2 3,8' Cyx a :harge oiler cycle 107139170 Ea httttnr.1r Change, per 3a' 107139770 1 E3 'lector Head or lope Cr r ae'slon, eacri 107139830 1 E3 za:lor Chaff. _ 3d & Jrtoaa per irlU CT Fluid Pumping Servicee: 107995x0 5 1a;r° Fluid Pimp Less than 20C -1HP i9 hr rrlrlrnum. per day, lard) 103034030 1 Jcb h'FctlllzatIcn -Load and Lrlioad unit. per job 1030331330 S .ay iron Ba$ .e1, per day :Irci .dee 109' :r 2' 1-oh) 102996030 E0 Hr Fluid Pump Less than 23E 'iHP, admdorral hours, per hr, 10299C+730 1 :ay Ntrogen Unit i9 hr minimum, per day ) 1091030 1 :ay 23E0 gal Tank, per day 102933070 1 Job Mcbltza11cn -Load and Unt ad Unit, per jcb Personnel: 10313E030 122 Hr Service Supe'.lscr. Lard, per lir i3 hr M P'n n) 103112070 367 Hr Serdce Te irIclar Lard. per Pr (9 iv rifinirnum) 10312E030 Hr Crew Try we h' 103127021 6 :ay Wells to Jct oacr^Ira1or, per day 103121030 20 Ea Sutsls1enoe, per Jay , per man Page 13 of 20 r - • Other Equipment: 11E049320 1 Job CclICAT 103056020 5 :; Clots. Marittidd 1 C' 1, oEr za 107 E50 3 5 :. 3 1 =' or 4 1 10.1 FIZ* Coo- vex (13y 1 1030E.0:0 s "Lay lector Stand. per day 103042031 5 Jay 3 "1f' tar 41;15' 10 \4 or 51.1 Dcoal. per clay, per spool 103017030 5 :ay Itir3LIlc Crane. per day 1072E51330 5 "Lay 2 - .1E' of 4 "15' 1 OSJ QUM BCF. Oer cay (CAT 2 Bottom Hole 4se : TC LS 1 Job W and wi1ndom Ming au:err Iy IBTTi NC- 1 EA Orli 7q b: S_8 1 EA Orli 7g ric`o1 s 5 Expentllablea: 103047031 Ea IR - S 61s=ts 4 1w 16' or greater, each 1030 7030 =_a Z =1Ffi_r Eler : Ireert. rrlr 1 per we I 1032 :E 3 :0 1 Ea IPae 1a, yE Packing 10713370:0 2 Ea 5 - .1E' or 41 +"16' QLad EC'' Expeidaties. per Job 53 032 2103 MIe Mleage charge, equiprnem 5320203,E 1403 Mle Meese change. Fickr ps 0 1 Job Fictinact eguIprr+ent 1,0]2 -0O3 303 cot N rogen ilar'L : J313 20 gal J313 - Ftlodort Recdong Ager: MI 303 BBL Drilirtg Mud sss. em 1.111 %lc: Page 14 of 20 • • Attachment #7 2 -3/8" Coil Tubing Specifications PRECISION COIL TUBING DATA -3/8 "' 0.n. TUBE TECIi OLOGY Available Grades: HS-90 CMT ,i OR HS -90 WTM (CONTINUOUSLY- MILLED TUBING (BUTT- WELDED TUBE SECTIONS) DIMENSIONS TUBE BODY LOAD INTERNAL (Inches) Nominal (Lbs.) PRESSURE (psi) O.D. Wail Wall I.D. Weight Yield Tensile AydroTest Internal Specified Specified Minimum Calculated Lbs. / it. Minimum Minimum 90% Yield Min 2.375 0.125 _ 0.118 2.125 3.011 79.500 85.700 8,000 8,900 2.375 _ 0.134 0.128 2.107 3.215 84.9 91.500 8.700 9,600 2,375 0.145 0.138 2085 3.462 91,400 98,500 9,300 10,401 2.375 0.156 0.148 2.063 3.706 97.900 105,500 10,000 11,100 2.375 0.175 0.167 2.025 _ 4.122 108,900 117,300 11,200 12,500 2.375 0,190 0.180 1.995 4.445 117,409 126,500 12,100 13.40 Tube Body Load: Yield & Tensile Minimum calculated on Specified Wall. Hydro Test: Test Pressure Value is 905£ of the Minimum Internal Yield Pressure Rating, Internal Yield: Internal Pressure to cause yielding using Minimum Yield Strength and Minimum Wall Thickness, Maximum Working Pressure is a function of tube condition and is determined by the user, DIMENSIONS TUBING AREA TORSIONAL INTERNAL EXTERNAL (Inches) (sq. in.) YIEI.I) CAPACITY DISPLACEMENT 0.i). Wall w/ Wail Internal (ft. / lbs.) per 1000 ft. per 1000 ft. Specified Minimum Min. Min. Yield Ultimate Gallons Barrels Gallons Barrels _ 2.375 0.1)8 0.837 _ 3.593 3.894 4,090 184.24 4.39 230.14 5.413 2.375 4 0.128 0,904 _ 3.527 . 4,170 4,398 181.13 4.31 230.14 _ 5.48 2.375 0,138 0,970 3.460 4,438 4,700 177.37 4.22 230,14 5.48 2.375 0.148 1.035 3.395 4,699 4,997 173.64 4.13 230.14 5.48 2,375 11.167 1.158 3.272 5,175 , 5,545 167.31 3.98 230.14 5.48 2.375 0.180 1.241 3.189 5,485 5,908 162.38 3.87 230.14 5.48 Torque Values Calculated Using Minimum Wall Thickness and Minimum Yield Strength. Other sizeslwall thickness available on request. 'NOTE; ABOVE DATA IS FOR NEW TUBING AT SPECIFIED MINIMUM STRENGTHS.] Page 15 of 20 • PRECISION MATERIAL SPECIFICATIONS - HS -90TM TUDETECH4'OLO(:v HS -90 CMTM (CONTINUOUSLY MILLED TUBING) HS -90 WTM (BUTT WELDED TUBE SECTIONS) PHYSICAL PROPERTIES: MINIMUM YIELD STRENGTH - 90,000 PST MINIMUM TENSILE STRENGTH - 97,000 PSI MINIMUM ELONGATION - 25% MAXIMUM HARDNESS - 22C ROCKWELL CHEMICAL COMPOSITION - .5: CARBON 0.10 - 0.15 RANGE MANGANESE 0.60 - 0.90 RANGE PHOSPHORUS 0.025 MAX SULFUR 0.005 MAX SILICON 0.25 -0.40 RANGE CHROMIUM 0.55 - 0.70 RANGE COPPER 0.20 - 0.40 RANGE ALUMINUM 0.040 MAX NICKEL 0.14 - 0.30 RANGE MOLYBDENUM 0.10 - 0.15 RANGE STEEL. ALLOY DESCRIPTION: A -606 Type 4, Molly Page 16 of 20 . • Attachment #8 Schlumberger BOPE Layout j 1 i ft ! 4 rt x 1 g+ l q 1 ! Cr w .17 v , 'e • ' ' ' ": 1 ' ! ' '' ' / teas- ir. +' k m err ! -. - 7 II - t 149 A d tk Sill \ t y • ' � f( II ' 1d" *4 e / r f4 : ... .4 au, , li .. *. 4 ( 1 1 . ,1' \ Yir ,..._, - {. it k . i k l',1Pqr i ce. .. ' - h . o ,:I - 11 -I ; �1 7 f 111 I a !Ia. 1 AR il„ i 4: I ( k y Atilli , . -A . .. - Page 17 of 20 • • 1.31',1 „._M__, -I --f MIMI Ili i" lir _awl Gel 4( FLI3w- t 1:1,1335 31,:t ri , jr-oallvilal- Ana ,S.L. II ivi-r-a05-541vEct • i n i tl 'i • " _ Iii Page 18 of 20 • s Attachment #9 Schlumberger Choke Manifold Gs:a'og rob, Manifolds NISI I:NORI ; iti011itth PESCRW.1C -N . _ .; - . � ' c MH1 -.2k.) - 8PPF1' -00 �.. 9�' �.;.. " ..a: { } .. { sofoo M) ►2fi PL iS. �ia+tx?r i t���:tll:fr 6'i CiQ • . , r_ f y r • �. t 1. 1.a s. i∎ ; up , 1 c di 1 .f rwt . . -' '1°1 .-I: "11 fill . ,aI t 0 • a — 4 10111. --, 1 - • 1010 ,.... ..-, - a • ' J ill 1.46.111111erir wool' r 1 : 1 Page 20 of 20 0 0 • 1 �t �. , ' r a I. �� ' �i �' r '. : (0 1 ,,7 � �. w 1 r h � r r` , . $ r1 ' r, 0 r P y I , • rp w r d A l I , +� * 1 ,, ' 7 11 A rr r A` r : A �, r r r y` Ill k. R' r 1 r !r 014; I .�..C.:A. 'a" ' ' 0, PPS or 4o, ■ I I r r + a... r.;,., ,, ..., w ■ t ►rti rte �. • 57ir r. t ' � � �t n ` 5 p i 1' « 'i ` � v . � c ' Page 19 of 20 • S \ ■ 7 }t IP\ 1 L CO 5/4 it \ \ !-\ -1 \ 1 ■ SEAN PARNELL, GOVERNOR 01 E t LY 0":" b (L) A_ ALASKA OIL AND GAS / 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Eddie Wright Project Consultant — Rutter 86 Wilbanks Corporation a07 03 301 S. Main Street, Suite B, or Box 3186 Midland, Texas 79702 Re: Exploratory Field, Ahtna #1-19A Sundry Number: 309-261 Dear Mr. Wright: Enclosed is the unapproved Application for Sundry Approval (Form 10-403) relating to the above referenced well. We are returning this Application for Sundry Approval unapproved since it was cancelled at your request. If you have any questions, contact Winton Aubert, PE at 793-1231. Sincerely, O Daniel T. Seamount, Jr. Commissioner 04 , - t - C DATED this day of August, 2009 End. RECEIVED AUG 1 0 2009 Petroleum Engineers, Inc. Alaska Or9 & Gas Cons. Commission Three Riverway, Ste 1500 nclnot.a Houston, TX 77056 August 10, 2009 Winton G. Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Mr. Aubert, 309 1 This letter is to request the cancellation of the Form 10 -403, Sundry Notice for the Ahtna #1 -19B to pull test the casing. This is requested because the availability of a drill rig or a well service rig to sidetrack this will is not available in an appropriate time frame. This letter is to submit the Form 10 -401, Permit to Drill for the Ahtna #1 -19 well. This well will be re- entered and sidetracked from a window at 3930' to a total depth of 4500' MD/TVD. Verbal permission is requested to allow equipment and materials be mobilized to location starting 8/21. Initially, pressures will be recorded and additional wellhead equipment will be installed by Vetco Gray. The Schlumberger CTU will begin arriving on 8/22 and will be rigged up by 8/25 with BOPE testing. Actual well operations will begin on 8/26 when we open the 4" 5M master valve and start into the 5" casing with the cement drilling BHA and 2 -3/8" coil tubing. Operations should be completed by 9/20/09. If you have some questions, please give me a call at 713- 823 -7789 or email to ewright @peiinc.com. Thanks, is Eddie L. Wright, P.E. Project Consultant for Rutter & Wilbanks Corporation cc: Bill Rutter, Jr., Rutter & Wilbanks Corp., P.O. Box 3186, Midland, TX 79702 • • . RECEIVED JUL 2 8 2009 Petroleum Engineers, Inc. Alaska Oil & Gas Cons. Commission Three Riverway, Ste 1500 Anchoraia Houston, TX 77056 July 27, 2009 Thomas Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, • Enclosed is the 10 -403 Sundry Notice for the Ahtna #1 -19B well owned by Rutter & Wilbanks, Midland, TX. This notice is to request permission to perform a pull test and remove the 5" 17.93# L -80 ST -L production casing. I would like to start this work next week, if possible. If you have some questions, please give me a call at 713- 823 -7789 or email to ewright dpeiinc.com. Thanks, / Eddie L. Wrigh . Project Engineer for Rutter & Wilbanks \ STATE OF ALASKA c ` / (� / ALAS•IL AND GAS CONSERVATION COMMI•N RECEI v �° Zo � — 1 � � � APPLICATION FOR SUNDRY APPROVALS JUL 2 8)00 ? 20 MC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Alasktiiiikaastons. CoThk141S610 1 Alter casing LE var kpair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension Z c h orage Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well/0 Pull 5" casing 2. Operator Name: 4. Current Well Class: 5. Permit to ,Dill Number: Rutter & Wilbanks Corporation Development ❑ Exploratory o / G o?D9Df$ 3. Address: Stratigraphic ❑ Service ❑ 6. APl� dumber: 301 S. Main St., Suite B, or Box 3186, Midland, TX 79702 50-099-20005-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name nd Numbed q/1,, property line where ownership or landownership changes: /1 (� Spacing Exception Required? Yes 1=1 No ❑ 'Om #1 -19 SiE1Etr 9. Property Designation: d eE ` ' ,44/ . 10. KB Elevation (ft): 11. ool(s):,' , J ` C Sec. 19, T-4 -N, R -3 -W WELL 2037' KB c ,�i) /ar /' </ 12. PRESENT ELL CONDITIONS MI A Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effe iv Dr TVD (f): (Plugs (measured): Junk (measured): PBTD 4536' ELM (TOC) IPBTD 4536' ELM I 32101 3210 1 - (944') 3210-4154" Casing Length Size MD TVD Burst Collapse Structural Conductor 78' BGL 13 -3/8 7 ' B L . ' 78" BGL / Surface 1226 9 -5/8 226 / 1226 5,750 3,090 Intermediate 1915 7 1915, , 1915 7240 5410 Production 4639 5" 39 pi of 4639 10,140 10,490 Liner 588 3 -1/2 ; ' 1 5 I - I 5165 10,160 10,540 Perforation Depth MD (ft): Perforation Depth TVD (ft) 1 • ng ,•e: Tubing Grade: Tubing MD (ft): None None N I I ' Packers and SSSV Type: , a rs a SSSV MD (ft): NA NA 13. Attachments: Description Su mary Propoal ,- . Well Class after proposed work: Detailed Operations Program El BOP h ` Exploratory 0 , Development ❑ Service ❑ 15. Estimated Date for 'M. Well Status after proposed work: 8 3/2069 i Commencing Operations: Oil ❑ Gas El ' Plugged ❑ Abandoned ❑ ./(,) 17. Verbal Approval: Date: / WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: . s 18. I hereby certify that the foregoing is true and co e e best of my knowledge. Contact Printed Name Eddie L. Wright Title Project Engineer Signature fI Phone 713 Date 7/27/2009 (' COMMISSION USE ONLY / 369-.016f ,1 Conditions of approval: Notify Commission so that a representative may witness 'Sundry Number: v Plug Integrity ❑ /80P Test 0 Mechanical Integrity Test ❑ , Location Clearance ❑ Other: / / 62 E F :'U ,I �I 2000 Subsequent Form equired: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10 -403 Revised 06/2006 ORIGINAL Submit in Duplicate 'APPLICATION FOR SUND•APPROVALS • Rutter & Wilbanks Corporation Ahtna #1 -19B Pull test for free point & remove 5" casing Descriptions of Operations Our primary plan is to sidetrack the well with a complete drilling operation. Prior to moving in a rig and equipment, we would like is to determine the length of free 5" casing and to remove the 5" casing. With this answer, we can complete our sidetrack operational plan. The steps to be accomplished during this Sundry Notice are as follows: 1) determine pressures on well, 2) bleed off pressures to zero so well is dead, 3) remove the wellhead sections to expose 5" casing stub, 4) rig up BOPE and choke manifold & test, 5) determine 5" casing free poin tretch readings, Note: Operations may be sUspen d until rig and equipment are on location. 6) perforate at free point, 7) circulate 18.5 ppg mud down 5" casing and up annulus, 8) cut 5" casing, 9) pull casing out one joint at a time and lay down until all joints are out of hole, and 10) RDMO when well is secured and location is clean. See attached detailed plan dated 7/27/09, Rev 2. • • Ahtna #1 -19 Workover Program Pull Test & Remove 5" Casing July 27, 2009, Rev 02 I. Move in and Set up Equipment 1. Send out notice of start date to all vendors on the Vendor List. 2. Notify the AOGCC of start date including the start of moving equipment to location. 3. Notify AOGCC 24 hrs in advance of starting well operations. II. Rig down Wellhead, Prepare to pull 5" casing, Nipple up BOPE 1. Check pressure on 5" casing thru the gauge and needle valve on top of 4" flange of dry hole tree. Approximately 300 -500 psig of pressure may be on the 5" casing based on the last steps of the plug back operations in 2007. a. Verify and/or close the 4 -1/8" valve. b. Close needle valve and remove gauge. Verify that gauge is reading zero. If gauge does not read zero, replace gauge with 0 -5000 psig. c. Add nipples, tee and second needle valve to allow pressure to be monitored and pressure to be bled off through tubing to an empty drum. Close all needle valves. DRY HOLE TREE Needle Valve #2 Nipples, Tee, & gauge T Tubing to drum to collect fluid Needle Valve #1 �— I Blind Flange on 4 -1/8" valve d. Open the 4 -1/8" valve slowly. e. Open Needle Valve #1 to allow pressure to gauge. Record pressure. f. Open downstream Needle Valve #2 to allow flow to empty drum and collect fluids as the pressure is released. Record pressure every 30 seconds. g. If pressure does not bleed to zero, contact office for discussion and direction. h. If pressure bleeds off, close Needle Valve #2 and monitor gauge for any build up of pressure. Ahtna #1 -19, Workover Plan Page 1 of 6 • • 2. Check first set of wing valves below the dry hole tree. These valves allow access to the 5" casing similar to the 4 -1/8" valve on the dry hole tree a. Verify both valves are closed. b. Verify that one wing valve has a bull plug with a needle valve and pressure gauge. i. If neither valve has a bull plug, needle valve and gauge, remove the bull plug slowly. Clean out the valve. Replace with a bull plug that is tapped for and has a needle valve and gauge. ii. If the wing valve has a needle valve and gauge, remove the gauge and verify the gauge reads zero. If gauge is bad, replace with new gauge that reads 0 -5000 psig. iii. Open the needle valve to remove trapped pressure. Then remove the bull plug and clean out the wing valve, needle valve and bull plug. Replace the bull plug, needle valve, and gauge. c. Open wing valve slowly. Open the needle valve and verify that the pressure is the same as the pressure on the gauge on the dry hole tree. 3. Check the second set of wing valves below the dry hole tree. These valves allow access to the annulus between the 5" and the 7" casing strings. a. Verify both valves are closed. b. Verify that one wing valve has a bull plug with a needle valve and pressure gauge. i. If neither valve has a bull plug, needle valve and gauge, remove the bull plug slowly. Clean out the valve. Replace with a bull plug that is tapped for and has a needle valve and gauge. ii. If the wing valve has a needle valve and gauge, remove the gauge and verify the gauge reads zero. If gauge is bad, replace with new gauge that reads 0 -5000 psig. iii. Open the needle valve to remove trapped pressure. Then remove the bull plug and clean out the wing valve, needle valve and bull plug. Replace the bull plug, needle valve, and gauge. c. Open wing valve slowly. Open the needle valve and verify that the pressure is the same as the pressure on the gauge on the dry hole tree. 4. Record the pressure on the 5" x 7" casing annulus. a. If the pressure is zero, continue with the next step. b. If the pressure is not zero, begin to bleed the pressure off into an empty drum. c. Monitor the pressure drop with the volume of fluid collected in the drum. Record the pressure for each increment of 3" of fluid collected until the drum is full or the pressure is zero. d. Plot the recorded pressure with the volume of fluid collected. Determine from the graph how much fluid will need to be collected until the pressure is zero. e. Shut in the needle valve when the pressure is zero or the drum is full. Ahtna #1 -19, Workover Plan Page 2 of 6 • • f. Record the pressure build up every minute for the first 30 minutes, then every five minutes for the next hour. Continue to monitor the pressure every 15 minutes for the next three hours or until the pressure has stabilized. g. Report the results of these tests to the office. h. If the well had bled to zero and has not built up any pressure for 2 hours, then continue to the next step or as directed by the office. 5. Nipple down the dry hole tree, the first and second sections of the wellhead. 6. Weld on a 5" 18# N /L -80 LTC casing landing joint to the top of the 5" 17.93# L -80 casing stub. If a landing joint is not available, plan on using a casing spear to pull test the 5" production casing. 7. Tack weld the 5" casing slips to the casing. 8. Nipple up a double studded adapter or drilling spool. Will need to have an 11" 10K flange down and a 11" 5K flange looking up. 9. Nipple up an 11" 5K double BOP. Have one set of blind rams on top. The second set of rams will be either 5" casing rams or rams that will shut in on the shaft of the casing spear. 10. Rig up a choke manifold to the BOPs and flow back iron to small tank. U '- 11. Pressure test the BOPS and choke manifold to 250 psig low and 5,000 psig high. v .) I CX „a�i 12. Engage the spear or pick up on the landing joint. If the landing joint is used, have a pump in sub, full- opening low- torque valve and crossover for 5” 17.8# L -80 LTC casing. If the spear is used, close the rams on the shaft. - 13. Pressure)st the 5" casing to 2,800 psig or Leak Off. Test pressure is based on a AS OIL The MASP calculation is based on a gas gradient of 0.1 psi/ft, and tfi e of 2780 psig. g g p I= . o`Ze � original hole being drilled with 18.3 ppg mud weight at 3107 ft III. Pull 5" test casing to determine free point. 1. Start picking up on the casing in 5,000 lb increments. Record the pull in 5000 lb increments and length of stretch in inches to the nearest 1/8 ". Do not exceed 75,000 lbs without discussing with the office. 2. Casing was initially set with 25,000 lbs on the slips. Estimated string weight in air is approximately 36,000 lbs if the free point is at 2,000 ft and 54,000 lbs if the free point is at 3000 ft. 3. Graph the pick up weight against the length of stretch. 4. Use the following equation to determine the free point and the length of free casing that might be recoverable. 5. Report test results to the office. Discuss with the office the next steps to take. NOTE: Operations may be suspended until rig and equipment are on location. IV. Establish circulation 1. Rig up mud mixing equipment and storage tank. Ahtna #1 -19, Workover Plan Page 3 of 6 • • 2. Rig up and perforate the casing at the free point. 3. Mix and circulate 19.5 ppg freshwater -based drilling fluid down the 5" casing and up the annulus. Continue to circulate the drilling fluid until the weight out is 18.5 ppg. 4. Check well for flow on the 5" and the 5 "x7" annulus. Well should be dead. 5. TIH with E -line and cut the casing at the free point. 6. RD E -line and start reciprocating casing while circulating. V. Pull and lay down 5" casing 1. Pull up to the first connection on the casing. Estimated length of each joint is 44 ft. 2. Install casing clamp at least 3 ft below the casing connection. 3. Cut off joint below the box connection approximately 12 -16 inches. 4. Continue cutting and pulling the casing out of the hole. Total number of joints is estimated at 50 joints for 2,000' and 80 joints for 3,200'. 5. Keep hole full of drilling fluid by filling hole after pulling two joints of casing out of hole. Approximate fill up for two joints is 0.57 bbls based on 88 ft for two joints with 75 psi pressure change. 6. Fill up hole and close the blind rams. 7. Release equipment. RDMO. Secure well. Clean up location. Ahtna #1 -19, Workover Plan Page 4 of 6 • • RUTTER & WILBANKS CORPORATION Sec 19, T4N, R3W AHTNA #1 -1 9A API No.: 50-099-20005-01 Current Wel lbore Diagram RKB 2037.0 18.3 73107 GL 2018.7 Depth Casing/Cement 150 ' Diesel (3 bbls) 41] k 78' BG L 13h-03e Squeezed Le8d with 13 bbls Shoe bis 12-1.4 20 Obis Permaforst & Class G " , 8-1.2" 1,915 7" 26# L-90 BTC Intermediate 66 bbls Class G to surface 3,200 Top of cement (CBL) 3210 P8TD 3,210 PBTD (tagged on 7'2'07) Cement: 15.8 ppg Class G with 40 #:bbl CEMnet fiber, 1.5 gaLsk Gas Top of Whip Stock at 4129' Blok. & 0.1 gal Accelerator 4,140 Top of Window Whip Stock Anchor at 4,153' 4,148 Bottom of Window _11■••= ■ gr l 4,154 Obstruction in hole Top of Bailed Cement 4,170 (tagged 6:14 07) Evaluate zone ±4,230 Mechanical Plug 4,220 1 E-Line Pens: 4232 4250 Drill Perf Tool Channels: 4382 4387 End of Side track at 4341' E-Line Perfs: 4474 4490 4506 4530 Top of cement 4,536 (placed with dump bailer; 4,577 Top o13-1'2" Liner 4,635 Weatherford E-IRBP 110-7-.7.1111_ /Inflatable Ret. BP 4,639 5" 17.8# L-80 ST-L Intermediate Perforations: 4674 4680 53 bbls Class, G 4922 4940 4923 4929 4932 4938 5010 5020 5076 5084 5,099 Top of cement 5,166 3-12" 8.8 L-80 ST-L Prod. Liner Total Depth IMD & TVD; 5.165 Ahtna #1-19, Workover Plan Page 5 of 6 RUTTER & WILBANKS CORPORATION Sec 19„ T41\1 R3W AHTNA #1-19B API No.: 50-099-50005-02-00 Proposed Wellbore Diagram RKB 2037.0 18.3 6110109 GL 2018.7 Depth Casing/Cement k ,, BGL 13-3/8" 68# L-80 Conductor Shoe Squeezed with 18.3 bbls 12-1/4" 1226 9-5/8' 40# L-80 BTC Surface 20 bbls Permaforst & Class G • 18.5 ppg 8-1/2" 1,915 7" 26# L-80 BTC Intermediate • 66 bbls Class G to surface 1 1 3,200 Top of cement (CBL} 3,200' Est. Top of 5" casing 3210' PBTD 3,210 PBTD (tagged on 712107) Top of Whip Stock at 4129' :; Cement: 15.8 ppg Class G with 40 #113b1 CEMnet fiber, 1.5 galisk Gas Blok, & 0.1 gal sk Accelerator ] 4,140 Top of Window Whip Stock Anchor at 4,153' 4,148 Bottom of Window : II 4,154 Obstruction in hole Top of Bailed Cement 4.170 (tagged 6:14:07) Evaluate zone t4,230-4,250' . : Mechanical Plug 4.220 E-Line Perfs: 4232 4250 DriU Perf Tool Channels: 4382 4387 End of Side track at 4341' E-Line Perfs: 4474 4490 4506 4530 Top of cement 4,536 (placed with dump bailer1 4,577 Top of 3-1.2" Liner 4,635 Weatherford E-IRBP L' (Inflatable Ret. BPI 4.639 5" 17.8# L-80 ST-L Intermediate Perforations: 4674 4680 53 bbis Class G 4922 4940 492 4929 =_— 4932 4938 5010 5020 7= 5076 5084 5,099 Top of cement 5,165 3-12" 8.8 L-80 ST-L Prod. Liner Total Depth ilvlD & Di . I. I 5.165 Ahtna #1-19, Workover Plan Page 6 of 6 r "----- 1 11" SM ANNULAR STD TOP /FLG BTM HEIGHT: 48 " ....... 11" 5M DRILLING SPOOL OSA 4^ 5M x 2" 8M I ill 1111 2' 5M OTL HEIGHT 23'" 1 aN •uai" IV t. CM , - .-6O� MY AM W CMf1Kf f 11 5M DRL GATT ., '' BLIND:i I STD HEIGHT 33" _ ,. ✓ ~/ 1. .44:1 14- . 1111- : j -- _ 1 _ s "_ troolo 04l ill 't 5M DRILLING SPOOL 4" 6M OTL HEIGHT 23" _ 2" ncrnlnal . � � � ., DSA 4' 514 X 2"' SM " � �1' 2" 8M OTL In!pt _ E .._ - " o f „ �� 11 �L L 11" 5M DRILLING SPOOL '" nrminal HEIGHT 23" i^ -owYJ gar I :- "'� J 11 11 11" 5M BOP Stack with an Annular & Double Ram „:'..... ,. Pa. Arm :" w® °"°' (look up of the OOP Stack with the Ghoko Manifold will use 21' Series 1502 I)amrner Unions ►fvewlwufae CHOIR 2" 50 00 psi Chok e Manifold 2 " 5M Choke Manifold Hook up of the BOP Stack iti> the Choke Manifold will use 2" Series muter Unions Ahtna #1 -19A - 11" 5M BOP with 2" 5M Choke Manifold r 1 1 R 1[ : i rj;, y ';ND BA NK3 C DRP RATIO '3 PL. Box 3186 OFFICE Midland, e,Cas 797? FAX :437 583-3_R-L4 6 !32) 633 -1 732 July 14, 2009 Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 Dear Sir: This letter is to authorize access to AOGCC files for the Rutter & Wilbanks well files for the Ahtna #1 -19 (AOGCC file 205 -015) and Ahtna #1 -19A ( AOGCC file 207 -085) for Robert Hunter with ASRC Energy Services. Access should also include the well log and mudlog /gas detection log files and other associated digital data. Mr. Hunter is working with the Alaska Natural Gas Development Authority to assess the oil and gas potential of the Copper River Basin area with specific reference to these data. Very truly yours, RUTTER AND WILBANKS CORPORATION j � {.Y A.W. Rutter, Jr. Vice President AWRJR /rob • 111 Page 1 of 5 Maunder, Thomas E (DOA) From: Hunter, Robert [Robert.Hunter @asrcenergy.com] Sent: Tuesday, July 14, 2009 10:41 AM To: Maunder, Thomas E (DOA); Saltmarsh, Arthur C (DOA) Subject: FW: Ahtna approval to release Ahtna #1 -19 well data Attachments: Letter for Bob Hunter.pdf Tom & Art, The attached letter and below correspondence documents Operator /data -owner permission for me to access well file & log data for the Ahtna #1 -19 and #1 -19A at AOGCC. Please let me know if there are any additional requirements. Thanks, Bob Robert B. Hunter, Senior Geologist Vice President, E &P Technology ASRC Energy Services 3900 C Street, Suite 702 Anchorage, Alaska 99503 robert.hunter(asrcenergy.com 907 - 339 -6377; Cell 907-301-9265 Fax 907 - 339 -6253 From: Rob Buelna [ mailto:rob @ruttercompanies.com] Sent: Tuesday, July 14, 2009 7:25 AM To: Hunter, Robert Subject: RE: Ahtna approval to release Ahtna #1 -19 well data Bob, Let me know if the attached letter will work. Rob From: Hunter, Robert [mailto:Robert.Hunter @asrcenergy.com] Sent: Monday, July 13, 2009 5:41 PM To: Rob Buelna Subject: RE: Ahtna approval to release Ahtna #1 -19 well data 7/16/2009 • Page 2 of 5 Rob, Thank you. Sorry I did not think of writing the letter before. I think for access to the AOGCC data that documentation similar to that with signed letter provided for Eddie Wright will suffice. A picture of that letter is attached along with a draft letter for your consideration. For the additional data such as the log analyses information that may be in your files, we could work directly together at a later date. I appreciate your efforts. Bob Robert B. Hunter, Senior Geologist Vice President. E &P Technology ASRC Energy Services 3900 C Street, Suite 702 Anchorage, Alaska 99503 robert.hunter(a) asrcenergy. c om 907- 339 -6377: Cell 907 - 301 -9265 Fax 907 - 339 -6253 From: Rob Buelna [mailto:rob @ruttercompanies.com] Sent: Monday, July 13, 2009 11:17 AM To: Hunter, Robert Subject: RE: Ahtna approval to release Ahtna #1 -19 well data Bob, All we provided for Eddie was an email. Write the letter requesting what you want and send it to me as a word document. I will put in Mr. Rutter's letterhead and signature block and any changes he might have. As soon as I get it from you I will have it signed and sent back to you. Rob From: Hunter, Robert [ mailto :Robert.Hunter @asrcenergy.com] Sent: Friday, July 10, 2009 3:35 PM To: rob @ruttercompanies.com Cc: Kirsten Sikora; Harold Heinze Subject: FW: Ahtna approval to release Ahtna #1 -19 well data Rob, 7/16/2009 • • Page 3 of 5 Very good to talk with Bill Rutter, Jr. and yourself this morning regarding the Ahtna #1 -19 well data. As- discussed with Mr. Rutter, he is fine with our accessing this information as long as Ahtna's Ken Johns has also consented. Per the below correspondence, Mr. Johns' approval is also evident. Kirsten may have an additional update to this correspondence, if needed. Thank you for your assistance in this effort and I look forward to receiving a signed letter of consent allowing me to view and use the Alaska Oil and Gas Conservation Commission (AOGCC) files on this well for our study. The signed form can either be scanned and attached to email or faxed to me at 907 - 339 -6253. You may also want to fax or email the letter to Tom Maunder at the AOGCC, similar to what you recently provided for Eddie Wright, or I can bring my copy to AOGCC next week. The study I am working with the State of Alaska (Alaska Natural Gas Development Authority - ANGDA) is on the oil and gas potential of the Copper River Basin with specific reference to the Ahtna #1 -19 gas discovery. The State remains keenly interested in this gas discovery as it could influence plans for gas pipelines and infrastructure in Alaska. As- discussed, we will keep you informed on the study findings and recommendations as they may be useful to your operations planning for well re -entry and testing later this year. Further details of our project with ANGDA are in the attached copy of the contract. ANGDA representatives Harold Hines and Kirsten Sikora are also copied in this correspondence. In addition to the AOGCC files, when I met with Ahtna's consultant, David Scolman, in Denver on June 11th, he mentioned that you contracted for professional log analyses (with NewTech ?) for additional evaluation of Ahtna #1 -19 log data. If this information is available from your files, it would also be very useful to our study as it is likely not within the AOGCC files. If you are aware of any additional information that might also be useful, your input would be welcome. Best Regards, Bob Hunter Robert B. Hunter, Senior Geologist Vice President, E &P Technology ASRC Energy Services 3900 C Street, Suite 702 Anchorage, Alaska 99503 robert.hunter a. asrcenergy.com 907 - 339 -6377; Cell 907- 301 -9265 Fax 907 - 339 -6253 From: Kirsten Sikora [mailto:KSIKORA ©jpo.doi.gov] Sent: Thursday, June 04, 2009 1:50 PM To: Hunter, Robert Subject: Doh! Robert, They are having their Annual meeting on Saturday so they are tied up a bit but here is the go ahead from Mr. John's assistant. I have attached the letter that we sent to Mr. Johns for your reference. I should have the new contract over to you this afternoon. All the best, 7/16/2009 • Page 4 of 5 Kirsten Sikora Administrative Officer Alaska Natural Gas Development Authority -- ANGDA "Creating energy solutions for Alaskans" 411 W. 4th Avenue, First Floor Anchorage, Alaska 99501 (907) 257-1393 Fax: 257 -1394 ksikora @j_po.doi.gov »> On 6/3/2009 at 4:19 PM, "Billy Hunt" <bhunt @ahtna.net> wrote: Kirsten, Thank you for the email. I just spoke to Ken and he gave the go ahead to proceed on this. Let me know if you need a more formal letter regarding this for your files. However at this time please use this email as permission to do so. Thank You, c A11i# &dint Operations Analyst Ahtna, Incorporated 406 W. Fireweed Lane Suite 103 Anchorage, AK 99503 Office: 907 - 868 -8217 Cell: 907- 529 -5209 Fax: 907 -868 -8273 www.ahtna - inc.com From: Kirsten Sikora [mailto:KSIKORA @jpo.doi.gov] Sent: Wednesday, June 03, 2009 4:12 PM To: Billy Hunt Subject: Doh! I spoke with Harold and if you could have Mr. Johns make a note right on Harold's letter that it is okay to proceed that would be great. Or an email from you or someone letting the consultant know that this work is approved. Let me know if you need anything. Thanks Billy -- I owe you big time. 7/16/2009 Page 5 of 5 1 (so much for this being slower than the hotel biz, huh ?) 7/16/2009 1 Page l of l 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright©peiinc.com] Sent: Saturday, June 13, 2009 10:48 AM To: Maunder, Thomas E (DOA) Subject: FW: Authorization Letter Importance: High Attachments: Authorization Letter.pdf Tom, The phone call was a nice surprise on a Saturday morning. I am forwarding an email form Rutter & Wilbanks with the Authorization letter attached. Looks like this email was originally addressed to jody.colombie @alaska.gov. Not real sure about the "Ma'am ". If this is not acceptable, please respond to this email and I will fax the letter on Monday. Regards, Eddie Wright Petroleum Engineers, Inc. From: Rob Buelna [mailto:rob @ruttercompanies.com] Sent: Tuesday, June 09, 2009 11:30 AM To: jody.colombie @alaska.gov Cc: 'AW Rutter Jr'; ewright @peiinc.com Subject: Authorization Letter Ma'am, As per our conversation this morning I have attached the authorization letter in this email. If there are any questions please do not hesitate to call me. Respectfully, Rob Buelna Rutter and Wilbanks Corporation P.O. Box 3186 Midland, Texas 79702 (432) 683 -1824 - Office (432) 638 -8846 - CeII (432) 683 -1732 - Fax 6/13/2009 • • RUTTER AND WILBANKS CORPORATION P.O. Box 3186 Midland, TX 79702 Office: (432) 683 -1824 Fax: (432) 683 -1732 June 9. 2009 © o Dth'05s Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 Dear Sir: This letter is to authorize access to the Rutter & Wilbanks files for the Ahtna #1 -19 to Eddie Wright with Petroleum Engineers, Inc. He will be in the Anchorage area from June 16 through June 24, 2009. Eddie Wright will be our point of contact for the upcoming work on the Ahtna #1 -19 sidetrack operations and the potential re -entry of the Moose Creek Unit #1. Sincerely yours, l* 8(0"_00 � RUTTER AND WILBANKS CORPORATION A.W. Rutter. Jr. Vice President • • Page 1 of 2 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Friday, May 15, 2009 5:44 AM To: Maunder, Thomas E (DOA) Cc: 'Michael S. "Mick" Francisco' I— kc Subject: RE: Alaska Projects - Ahtna # Moose Creek Unit #1 I worked with Armstrong to get environmental assessments for properties. Did not work on the well. I plan to visit with Ed Teng about their success and equipment used. I was busy working for Cimarex Energy in Tulsa, OK. Did some horizontal drilling for Granite Wash and Shale gas. Set up four drilling programs for wells in SW Wyoming to drill into 70% CO2, 5% H2S, 15% Methane, and 0.5% Helium. Very expensive wells with Corrosion Resistant Alloy materials for casing and tubing, H2S Saftey Plans, and limited calendar drilling time. Eddie From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, May 14, 2009 6:55 PM To: Eddie Wright Cc: Michael S. "Mick" Francisco Subject: RE: Alaska Projects - Ahtna #1 -19 & Moose Creek Unit #1 Hi Eddie. I will look forward to seeing you when you get up. Interesting choice to use Aurora. Pressure ratings could be an issue. They normally only operate a 3000 psi system. Might have used 5000 for Armstrong last summer. Tom Maunder, PE AOGCC From: Eddie Wright [mailto:ewright @peiinc.com] Sent: Thursday, May 14, 2009 3:51 PM To: Maunder, Thomas E (DOA) Cc: 'Michael S. "Mick" Francisco' Subject: Alaska Projects - Ahtna #1 -19 & Moose Creek Unit #1 Hello Tom, After a long silence, Rutter & Wilbanks is authorizing additional work on the Ahtna #1 -19. This will include bringing in an Aurora Well Service Rig to sidetrack and complete this well. With good luck, we will move to the old P &A'd Moose Creek Unit #1 which is across the highway, re- entry /side track, and complete this well. Both wells will be looking for the Nelchina Formation. I will have well plans and forms prepared within the next week to be submitted to the State of Alaska. I am planning a trip to Anchorage to visit with your department to resolve questions and make changes as required. will visit with various vendors and verify that the equipment is available and that this equipment meets our requirements for these operations. Just wanted to send an early nntP N��o ��� :� • ��� 6/13/2009 , III • 0 Petroleum Engineers, Inc. Three Riverway, Suite 1500 Houston, TX 77056 RECEIVED January 20, 2008 . 1�i ?qI�B Alaska 0i1 & :41 C 30:70mrnieeian Mr. Steve McMains Anchorage Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 . Dear Mr. McMains: I have enclosed two complete sets of the following items which have been documented in reverse chronological order from the most recent information to the oldest information: 1. Overview of Future Operations and potential plans to evaluate the success of the ) f) CTU sidetrack operations and plan a new Drill Rig -based directional sidetrack to tj recover the 4230' Nelchina Sand. Then to complete and test the sand. 0 2. Pictures taken on 8 -9/07 and 7/4/07 to show the Inspection by Wildlife, the ! equipment removed, and the location cleaned up. l --- 3. 10 -403 for the Ahtna #1 -19A to Suspend Operations. The Operations were 0 suspended on July 4, 2007 when the Coil Tubing Operations (CTU) plugged back (b the well with cement to 3,210'. 4. 10 -407 for the Ahtna #1 -19A for CTU sidetrack operations as shown in the final completion diagram dated 7/3/07, operational summary, and DECCA daily reports . ; - 17 for the Ahtna #1-19 as shown in completion diagram dated 6/26/07 wi - ,_ the well was 1 . I ack to 4,170' as shown in the operational s u : ■ and DECCA daily reports 1-4. 6. 10 -407 for the Ahtna #1 -19 work per e :.. shown in diagrams dated 10/28/06 and in Cudd daily reports 7. 10 -407 for t s - na #1 -19 as shown in the completion diagram . . : ' ' /05 and :. • mg Fairweather daily reports. • 0 At this time, I am not working on the Ahtna project with Rutter and Wilbanks Corp. Furthermore, I have not worked on this well since operations were shutdown on 7/4/07. Any future operational plans should be received from Rutter and Wilbanks Corp directly. Sincerely yours, /60."— .- ,°:,--'/ Eddie L. Wright, P.E. Petroleum Engineers, Inc. Office: 713- 479 -7000 Cell: 713 - 823 -7789 Email: ewright(apeiinc.com cc: Thomas Maunders (letter only) Bill Rutter Sr. Rutter & Wilbanks Corp. P.O. Box 3186 Midland, TX 79702 Michael S. Francisco 440 Pinehaven Dr. Houston, TX 77024 -3725 Overview of Future Operations Ahtna #1 -19 Well Site We could not estimate the quantity of gas that was produced during this operation under these circumstances but noted the fact that even when in communication with a high - pressure water zone and with well bore circulation, the gas continued to enter the wellbore. Both the high - pressure water and the circulation should have severely limited the gas production. I believe these results are very encouraging and another conventional sidetrack should be considered. The root failure of the #1 -19A well was the fact that immediately upon drilling out of the 5" casing we were in communication with high - pressure water. The key to making a successful completion in the gas zone is to set casing at approximately 4,200' - just above the Nelchina Sand. This casing string could isolate the higher - pressure water and allow the gas zones to be drilled with lower weight fluids. We proved in the coil tubing sidetrack that we could use water to drill the gas by utilizing water and surface pressure to balance formation pressures. This technique did not require weighting agents or solids in the mud so there was no damage to the Nelchina formation. Consideration needs to be given to utilizing this technique because the 2005/2006 drilling and testing results indicate the gas zones may be sensitive to weighted mud. The Ahtna #1 -19A well is a good candidate for another conventional sidetrack to test the gas zones. The #1 -19A well has 7" casing set at 1,915' and the top of the cement behind the 5" casing has been measured at 3,200'. We have plugged the inside of the 5" casing and have cement up to 3,210'. The Ahtna #1 -19B can be accomplished by rigging up a conventional drilling rig and cutting /recovering the 5" casing from approximately 3,200'. An open hole sidetrack plug can be set and the well sidetrack below the 7" casing at a depth of approximately 2,800. The fishing operations will have to take place in a mud environment sufficient to balance formation pressure. Drilling in 2005 indicated that 19.5 ppg may be required. Conventional directional drilling would then continue to a depth of 4,200', still in the heavy weight mud environment. At this depth, logging could be accomplished, then a string of casing run and cemented in place. The Ahtna #1 -19 well had 5" casing but consideration should be given to running 5 -1/2" flush joint to allow greater hole size when drilling out. Once the casing is cemented, one could use the drilling rig and drill the Nelchina conventionally using lighter mud ( -16 ppg) to drill to total depth of 4,600'. Another option is to release the drilling rig and utilize the techniques we just used on the sidetrack (i.e. coiled tubing drilling, lightweight fluid and surface pressure) to drill the Nelchina. Although an added cost to the overall operation, we have successfully shown that this technique can drill the gas zones and leave them uncontaminated which should allow higher production rates. Ahtna #1 -19A 8/9/07 • C'^ Looking at the North edge of location Man Lift picked up by local vendor the next day • Wildlife coming on location 7 Ahtna #1 -19A 8/9/07 • 1 " - ;� _ , az Location looking at Wellhead and NE corner 0 Wildlife not our responsibility 8 as ' � e A4,- ., , : * " i .= t4 :::°'3:,,,' c� a. ' . To r •0, o ,M Z _ , �._, O _ �[qq o tt y L \V '1/ . , x x , x O t - ■ O o -.0. — • r• yy t 1 F r Pk j g „1 # 3 t .11' „f':,5'... ''''' - ,t44'''' " ' ' . - ' 0 ' e= v� CO D n x e p m" -. .. +k mot y 0. I ■ , wp F:. ..acv S» ■ ■ • • I Ahtna #1-19A 7/4/07 „......, , I, ,.. i 0 , 0 . 1 ' * i ■ 1 : , = - r - ... o 0 L king from access road to West .., ., . edge of lo cation r -'.- p icked by l vendo • Man Lift to be p • -.... • . , , , — %,..‘,- ' .4. , ., : 't. ',...i.` i - "' -t .- 1 1 ' ' 4::* "‘'Zil.iNer,,,,,t. •4" 4-if% . '''' , : ' ,°.."'":-:- . - i - .., %...,..„. .4.-..-*4,',,'- •--,),..- , ,,,r,,,,,,,I,,--4`.-,. ,. rikNo.. i z, -- ;.., „„,- --. 4....„ . ,'-, A -1-, 7 ,, - - k. , J-04 ,. l' - ltt". - ''` , ' „. -- ''' t, „ ' 44 .r..* , ,, , IirkfT, gaiv. ,.. * .4 0., ,,,. 4 j"Ilk.r1:.' .. "' 4'''' ' 0 ' 4. '''. 4 ./ if,:r 4, . 1,—.P,t,,,Z. '.,,,i4S•S ' ' : 4 4 : '''' ,,t, s ;,. /yr ,k , ,'''Ti s. , s. t , - ., 1 -.-- . ,gtfr,",‘,.- 7.,...'-' t 411Nr* -, ; , ,,,'" . 4.; ..,- '''. 11, ".. * , ", -4)***.e.,..* ' 2 Ahtna #1 -19A 7/4/07 • 1. ° a. E; F S s E t? }`i `§ . Looking a the NE corner of location an Wellhead • y 4 s ce r ag 3 Ahtna #1 -19A 7/4/07 k ,.. • ■ �r� .�; < »e �, Looking at the SE ed of lo cation • z x„,. �+ r. a ...,,, ''. ' ,' s' �,°' ^ + .,. '7,..,-,,:,/.'"a� �' +�.». ,, ; +w ' �. .. „ "°�, mo w'` § , , ,, fi - P" y, ' i`� " ,.. y , t ; r a , , z' 't w. - � '' , -., *' `" f 4,,-...:.17,4t,,..." '' > � a- x ,� " .: sk +t; a,� �. ,^' �- T 4 �,., '' ^.e' :` r,. -, "' XJ .a " e, ;. + - y t` ��," .., , . ,, i..ok 3 ems° t yKr ,' 1 s" -fit z e �x :yz ..'r a a� «. .v- +r w. + r a a a y . ',+ ti.",4'" a 5wk ) `y' `� ,, . � r , r . . 44 ' 's , '.* ` .. "` . n .. `mss F ,? ,w , a ; � . ^), i s, x ?' SF , Litt -t" z" , Y , ; "` - ; + - ' ' e er y .', . ° r .:. • 2 xiaM .'' : ' 3e. �'x 4 a -s w "'� z ° , -1.4 �t , *' ' r, . ' ., .'` to , ,, . * ' �4 '''''''4---'''4'''''''' o- ;,�- " . C zt. 0 _ 44 " #' ;- ,.3e� +..._ x" `�. "i . . ' """S.` ' " `; �r,.'." w>'za ' "S;,ww``' . w� ° _ avl&T'^, . 'fi � ' k £ t 'S _ e si;"`. e .. ,.. ..�, *, 4 ■ Ah tna #1 -19A 7/4/07 i ii, r �t w ` t ., e ,. • �� ���� ^gyp. s � . Leaving Location toward Hi ghway 1 , ; a ' s : , '�'a `;�.° a. ' .M.,,- "' �° a �. - ▪ *'? <v ,� "Y �+ 3 y a' ` 3q, '.. a �sx "w+'",__ r *, r ` ` 7 "ys, 4^"s ✓ ',9t § `5� 3 ,, ' �t ` "" ;� 'a rC ^,a � . r ".%:'. # ,. , , 442, ,,, ,,_, x ' , , p ▪ "'r . �w m `,, k -;, , . ; ` r ._: , ,, "' -.� -' Y , �t: - •' '. w.v --,, v u . t .. , ,,, ' �* .�„ „ i:L. . #A°" y. "Y' ".8,° p , ' ',' � y � � *' '. ; r"-r"' y `° * L g # ,t s ...z u 'C� � g , _ i « ",` r .� v �""E , „ t" ` „,,t1 .s i„ d ;�a " w,,.' ,.«` - �^ i '- `°`. `` 46- rte' a «sr:° ..r --, r- k :' , . , '`:. ° a ' ..�. 4 '3." � rt „_ _ ar x ''',0- y ` : a ..ms ,, ' ..,- . €' ,�„ ,',4-7;(4, is `'€' . � ..,^ r „zr- x' a �' ; ' , 9 o .- '`�''' ,� -•' het " * € r � 'fr ` r 99 :;. r „" ..s. a , � -d' °a. �. p ry Py k' w. z ' ^ 1»r ".iv,.�z . 5 STATE OF ALASKA 7-4-0 ALASKA COIL AND GAS CONSERVATION COMMISSIC A APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend U Operational shutdown ❑ Perforate ❑ Waiver Other ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Suspend Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ Operations 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Rutter & Wilbanks Corporation Development Exploratory Ei 15 ad 't ' O' S 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 301 S. Main St., Suite B, or Box 3186, Midland, TX 79702 50- 099 - 20005 -01 -09 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 El No El Ahtna #1 -19A 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): Sec. 19, T -4 -N, R -3 -W 2037' KB 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5,165' 5,165' PBTD 3210' (TOC) PBTD 3210' (TOC) 1 - (944') 3,210- 4,154' Casing Length Size MD TVD Burst Collapse Structural Conductor 78' BGL 13 -3/8 78' BGL 78" BGL Surface 1226 9 -5/8 1226 1226 5,750 3,090 Intermediate 1915 7 1915 1915 7240 5410 Production 4639 5" 4639 4639 10,140 10,490 Liner 588 3-1/2 5165 5165 10,160 10,540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory i0 Development ❑ Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Summer 2008 Commencing Operations: Oil ❑ Gas i0 Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Eddie L. Wright Title Project Engineer Signature Phone 713 - 301 -2216 Date 1/21/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness (Sundry Number: — 0 d. 7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 Submit in Duplicate • 0 APPLICATION FOR SUNDRY APPROVALS Rutter & Wilbanks Corporation Ahtna #1 -19A Operational Shutdown Descriptions of Operations Operations were shutdown on 7/3/07 when the well was plugged back to 3,210' in preparation for future sidetrack operations. The operational shut down was required to evaluate the CTU sidetrack success and to plan for the next phase which may include bringing back a drill rig to cut and pull the 5" casing, re- drill a directional sidetrack to ±4,600', set 5" casing to 4600' and perforate the 4,230' Nelchina sand. Then possibly run production tubing and packer for future well testing operations. Estimated operational start up may begin in the summer of 2008. STATE OF ALASKA ALASKA OtAND GAS CONSERVATION COM ISSION W. 7th Ave. Suite 100 ANCHORAGE, ALASKA 99501 -3192 REQUEST FOR EXAMINATION OF AOGCC RECORDS I, the undersigned, request that I be authorized to examine the AOGCC records listed below, I agree not to remove or alter the contents of records and I agree not to remove the records from the room designated for examination. I, certify that lam neither a party, nor representing or acting on behalf of a party, involved in litigation in a judicial or administrative forum with the State of Alaska or public agency to which these records are relevant. i Signature: ��''�'�` Printed name: c l�c 4-`9 A i. Company /Firm: � � 2r / W /•,/ s Z:, ��ze� -s _Zn c • Address: Phone No: 7 / -7 - 73 AOGCC RECORDS REQUESTED 2 o7 - d�S" Q-as— b /S" FOR AOGCC USE ONLY: Date and Time Records Requested (6 AAC 96.320): Date and Notice of Receipt of Request Sent (6 AAC 96.310): Date Additional Information Requested (6 AAC 96.315): Date and Time Records Provided for Review: Date and Time Records Returned: Name of AOGCC Employee Handling Request: AOGCC will respond to this request as soon a practicable, but no later than the 10th working day after the request is received (6 AAC 96.325) This request is a public record. (6 AAC 96.320) \\ Common \Library\Request for Examination of Records Form.doc ... r. 0 7 ! STATE OF ALASKA UlL AND GAS CONSE VAT ON COMMISSION W ELL COMPLETION OR RECOMPLETI N REPORT A1p 8 0.0 la. Well Status: Oil Li Gas U Plugged U Abandoned U Suspended lb. Well Class: • 20AAC 25.105 20AAC 25.110 Oaf Lr1 li ailig CIOfl$49 GINJ❑ WINJ WDSPL❑ WAG ❑ Other❑ No. of Completions: Service ❑ A fC t * aphic Test❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Rutter and Wilbanks Corporation Aband.: 7/3/2007 p � , � 2070850 3. Address: 6. Date Spudded: M13. API Number: 301 S. Main St., Suite B, OR PO Box 3186, Midland, TX 79702 20er 6 jo -o`1 50- 099 - 20005 -01 -09 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1139.4' FEL & 2224.2 FSL Sec 19, T4N, R3W, CRM 6/28/2007 Ahtna #1 -19A Top of Productive Horizon: 8. KB (ft above MSL): 2037' 15. Field /Pool(s): 4230' Ground (ft MSL): 2018.7 NA Total Depth: 9. Plug Back Depth(MD +TVD): 3210' MD / TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x - 527867 y- 2964256 Zone- 3 4341' MD / TVD % Sec 19, T4N, R3W, CRM TPI: x - y- Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x - y- Zone- NA Ahtna Surface 18. Directional Survey: Yes LJ No a 19. Water Depth, if Offshore: 20. Thickness of Permafrost (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): None 22. 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 13 -3/8" 68# L -80 0 78 0 78 18.3 bbls Class G 9 -5/8" 40# L -80 0 1226 0 1226 20 bbls Perafrost & Class G 0 7" 26# L -80 0 1915 0 1915 66 bbls Class G 0 5" 17.8# L -80 0 4639 0 4639 53 bbls Class G 0 3 -1/2" 8.8# L -80 4577 5165 4577 5165 5 bbls Class G 0 23. Open to production or injection? Yes NoU If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) NA None 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED None 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NA NA Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas-Oil Ratio: NA Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 27. CORE DATA Conventional Core(s) Acquired? Yes No U Sidewall Cores Acquired? Yes U No U 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. o REJONAS BFI. A 2 0 7009 , rutiti IU-'}U/ RCVIDCU L /LUU/ ()RIG A �III 1 IINUCU VIN RCVCRJC t./ • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes U No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Nelchina 4230 4230 Formation at total depth: Shale 4341 4341 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: '7/7 — $? — ' 769 Printed Name: ,�� ', e , `� NYitiq Title: �j•o o6 i 4,e Signature: 406 Phone: Date: r o 2/-08 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 1 njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 • 0 RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -1 9A API No.: 50- 099 - 50005 -01 -09 FINAL Completion Wellbore Schematic RKB 2037.0 18.3 7/3/07 GL 2018.7 Depth Casing /Cement Completion: BGL 13 -3/8" 68# L-80 Conductor I Is 78 G 150 ' Diesel (3 bbls) Squeezed with 18.3 bbls 12 -1/4" 1,226 9 -5/8" 40# L-80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" 1,915 7" 26# L -80 BTC Intermediate 66 bbls Class G to surface 3,200 Top of cement (CBL) 3210' PBTD 3,210 PBTD (tagged on 7/2/07) Cement: 15.8 ppg Class G with 40 # /bbl CEMnet fiber, 1.5 gal /sk Gas Top of Whip Stock at 4129' Blok, & 0.1 gal /sk Accelerator 4 :: ...... 4,140 Top of Window Whip Stock Anchor at 4,153' 4,148 Bottom of Window �► • • 154 Obstruction in hole Top of Bailed Cement 4,170 Evaluate zone ±4,230-4,250' 6/14107 (tagged ) Mechanical Plug 4,220 E -Line Perfs: 4232 4250 Drill Perf Tool Channels: 4382 — 4387 — — End of Side track at 4341' E -Line Perfs: 4474 4490 — — 4506 4530 = — Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner (P p ) p 4,635 Weatherford E -IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L-80 STL Intermediate Perforations: 4674 4680 — — 53 bbls Class G 4922 4940 — _ 4923 4929 — — 4932 4938 — _ — 5010 5020 = 5076 5084 — — 5,099 Top of cement ............. 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner .. .................. Total Depth (MD & TVD) 5,165 • 0 RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19 API No.: 50- 099 - 50005 -01 -09 Current Completion Wel!bore Schematic RKB 2037.0 18.3 6/26/07 GL 2018.7 Depth Casing /Cement Completion: 150' Diesel (3 bbls) 78' BGL 13 -3/8" 68# L -80 Conductor Shoe Squeezed with 18.3 bbls 12 -1/4" 1,226 9 -5/8" 40# L -80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" Z 1,915 7" 26# L -80 BTC Intermediate 66 bbls Class G to surface 3,200 Top of cement (CBL) Top of Whip Stock at 4129' Top of Bailed Cement 4,170 (tagged 6/14/07) Mechanical Plug 4,220 E -Line Perfs: 4232 4250 ~ _ Drill Perf Tool Channels: 4382 — — 4387 — — E -Line Perfs: 4474 4490 ■ 4506 4530 Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner 4,635 Weatherford E-IRBP (Inflatable le Ret BP) 4,639 5" 17.8# L -80 STL Intermediate Perforations: 4674 4680 — — 53 bbls Class G 4922 4940 — — 4923 4929 —_ '_ 4932 4938 5010 5020 — 5076 5084 — 5,099 Top of cement 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 • The Ahtna #1 -19A Well Per our Intent to Drill Permit #2070850, side track operations were started and the well was re -named the Ahtna #1 -19A. 6/13/07 to 6/16/07 Move in and rig up Schlumberger Coil Tubing Drilling Unit with 2- 3/8" coil tubing (1.995" ID). Conduct first BOP Test successfully. 6/17/07 TIH with whipstock and tag cement at 4140'. Pick up and set at 4129- 4153'. Mill from 4137- 4138.4' 6/18/07 Leak developed in coil tubing at approximately 4075'. Shutdown operations until Schlumberger can get replacement reel. 6/23/07 Change out reels and get ready to continue milling window. Conduct second BOP Test successfully. 6/24/07 Mill on window from 4126 to 4140'. Shut in well to evaluate pressure. Well SICP stabilized at 2146 psig. This depth coincided with the depth at which the mill cut into new formation. Log analysis indicated the formation at this depth is shale, but pressure information indicated that we were in communication with a permeable interval with a pore pressure of approximately 16 ppg EMW. The zone would produce approximately 60 barrels per hour of salt water when allowed to flow. Began to weight up drilling fluid to 15.6 ppg. 6/25/07 Continued to mill window from 4140 to 4144'. Drill new formation from 4144 to 4154'. Lost drilling mud with salt water intrusion. 6/26/07 Leak Off Test indicated formation taking fluid at 2000 psig at various low pump rates. Attempts to control the well with mud weight resulted in the Toss of the drilling mud. Began increasing back pressure at surface to 2000 psig to drill ahead with water. Started • to maintain bottom hole pressure by adjusting choke. Control flow out equal to with flow in. Observed small amounts of gas and gas bubbles in open top tank at a depth of 4183'.. Drilled to 4222'. 6/27/07 Repair choke and drill from 4222 to 4236. Drilling topped the Nelchina Sand at 4,230' where gas indications became stronger to the point of washing out surface chokes. Conduct flow test and observe gas break out in open top tank. These strong indications of producible gas continued as drilling continued to 4245'. Repair choke and pump packing. Drill 4254- 4337'. 6/28/07 Jril1 from 4,337 to 4341'. POOH to check bit and motor. Bit had crack in body and broke while breaking connection. Repair and pressure choke manifold. Trip in hole with new bit and new motor. • of et throw. h window. POOH and check bit. TIH and still r to get into old o e. 6/29/07 Change to old motor and new bit. Still not able to get into old hole. Trip in and out to try to aet into old hole. Checked ODs and motor angles. No success. 6/30/07 PU and run window mill, reamer, and straight motor. Work window area and still not able to get into old hole. POOH. Try 2 -3/8" wash nozzle and not able to •et into old hole. PU new bi- center bit and new motor. Still not • - • • • ' g • • • o • — II- '45- • • • • • 'Is operations and plug sidetrac . 7/1/07 Mixed Class G cement with 40 Ibs /bbl CEMnet fiber, 1.5 gal /sk Gas Blok, and 0.1 gal /sk Accelerator. Pumped 16 bbls cement in hole and began retracting the coil tubing, keep end of coil tubing in the good cement. To of cement at 3200'. Continue to displace coil tubing with water and pull out of hole. Pressured to 2500 psig on cement for squeeze into open hole. Lost 75 psig in 30 min. Increased squeeze pressure to 3000 psig. 7/2/07 Well pressure bled off to 2550 psig in 12 hours. Tagged top of cement gt 3210'. Conduct positive pressure test to 3000 psig. Spot 3 bbls diesel in freeze zone. Bled off pressure to 0 psiq to conduct , negative pressure test. Pressure still 0 psig after 4 hours. Apply 500 psig to well. Rig Schlumberger Coil Tubing Drilling equipment at 1430 hrs. Rig down equipment and depart location. 7/3/07 Install Vetco wellhead plate and • au • e. Open valves and pressure, on well dro • •ed to 300 • ' • - .d 300 • si • after 12 hrs. ose va ves and secure well head. Clean up location. Clean out frac tanks. Trucking company will pick up frac tanks tomorrow. END OF REPORT SUMMARY • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 1 WELL NAME Rutter and Wilbanks Corporation DATE 14- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280 FT OPERATION (06:00 hrs) Rig up rig AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY DESCRIPTION COST ($) Hotels &Food 5,000 supervisor 3,000 schlumberger 18,423 contingency 10,000 Rain for rent 1,500 Rig up Schlumberger coil tubing rig. Mud Products & Mud Van 0 TOTAL DAY 37,923 TOTAL CUMULATIVE 103,759 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg/m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) - COST COST ($) $0 MUD COMPANY I I MUD TYPE I I CUMULATIVE COST $0 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m/hr) (daN) I I 0 0 1 1 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m/min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spin) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 2 WELL NAME Rutter and Wilbanks Corporation DATE 15- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Prepare to test BOP's AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 600- 1700pm Rig up coil tubing rig and surface tanks,swaco tanks DESCRIPTION COST ($) mix up mud, laydown christmas tree valves and spool,install new valves, Schlumberger 4-day Rig total 58,056 1700 -600am install BOP's to fit bird cage. Supervisor 1,500 MI swaco 9,600 Rain for rent 757 Hotel &food 1,500 Contingency 7,000 water truck 650 Mud Products & Mud Van 0 TOTAL DAY 79,063 TOTAL CUMULATIVE 182,822 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST (5) $0 MUD COMPANY I I MUD TYPE I I CUMULATIVE COST $0 BIT DATA BIT # SERIAL# SIZE - TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m/hr) (daN) I 0 0 1 1 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m/min) ANGLE (°) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 - DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5 - 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 1 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE/FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1- 713 - 823 -7789 . • Decca Consulting LTD. DAILY DRILLING REPORT DAY 3 WELL NAME Rutter and Wilbanks Corporation DATE 16- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) install whip stock wait on computor parts AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 600- 1400 pm Finish rigging up, Function test BOP's DESCRIPTION COST ($) 1400- 1730pm Test BOP equipment all valves ,2 -blind rams,2 -pipe ram Supervisor cost 1,500 2- man chokes,2x2 hammer unions,lines to tanks,inside reel valves, Rain for rent 757 accumulator system 2500 start,1200 left after function test,nitgon test Hotel &food 2,000 all bottles 1000 psi, Schlumberger 25,204 1730 - 180 -pm make up x/o on coil line and mud motor Water truck 700 1800- 2000pm rig down computor dead on rig ,no controls at all code #8 Mi Swaco 5,000 it looks like hard drive is gone we will have to wait until morning to fix Baker Tools 2,500 2000- 0600am pick up mud motor ream to bottom to clean up Trailor &Gen 300 casing, tag cement pull up and circulate, and change over to mud, pull Contingency 4,500 coil hook up and install whip stock and wait on computor parts before Vetco Gray 7,507 we set whip stock. Mud Products & Mud Van 0 TOTAL DAY 49,968 TOTAL CUMULATIVE 232,790 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST ($) $0 MUD COMPANY IMI I MUD TYPE I I CUMULATIVE COST $0 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (mlhr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3/min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT move rig down time on rig 2.00 CASING DEPTH (m) BELL SUB RIG UP 8.00 SURVEY LEAK -OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM make up whip 3.00 MUD RING HALF SPEED PUMP RATE (spm) 1 - DRILL Rig up mud motor HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE 4.00 WELD ON BOWL KELLY D Ream 3.50 NIPPLE UP BOP CEMENT TEST BOP 3.50 TOTAL 0 TOTAL 24.00 LEASE/ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE/FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 4 WELL NAME Rutter and Wilbanks Corporation DATE _ 17- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. _ 4280FT OPERATION (06:00 hrs) Milling window AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 600 -830 Rig up whip stock DESCRIPTION COST ($) 830 -930 RIH to flag point to MD 4140FT pickup 17Ft off bottom Supervisor cost 1,500 930 -1030 Set MD 1011 am pump up and shear pin on whip stock Rain for rent 757 at 3200psi,pressure drop to 0 looks good no problems Hotels &food 2,000 1030 -1130 POOH and displace to 8.5 ppg mud Schlumberger 46,913 1130 -1330 make up milling assembly and 3.80 bit Mi swaco 12,522 1330 -1530 wait on computor hard drive on location 1530pm 1530 -1930 Repair computer. 2000 RIH tag top of whip stock at 4135' Trailer &gen 150 2000 -2130 Establish flow rates 1- barral per min -250 psi on choke, Contingency 7,200 300psi on well head, 469psi on coil, then 2.5 barrels per min. well head travel &site aogcc meeting 9,600 309 psi coil 1030psi, choke 750psi hold back press. 2130 -1130 RIH to top of whip stock tag at 4135'. Start to cut window at 4137- 4137.4Ft Mud Products & Mud Van 1,694 1130 -0030 vac truck problems. Rig up transfer pump. TOTAL DAY 82,336 0030 -0600 Mill F/4137.4- T/4138.4Ft Stop to check depth problem. TOTAL CUMULATIVE 315,126 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal (s/I) (cc/30 min) (mm) mg/I (Pa) (mPas) Ib/100ft2 ( %) ( %) ( %) barrels barrels 8.5 46 9 200 12 0 0 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT clean up defoam x duo-vis asph-supremE MUD VAN DAILY AMOUNT (sx or I) 1 1 20 12 COST COST($) 698 145 676 175 $1,694 MUD COMPANY IMI Swaco I MUD TYPE IPolymer I CUMULATIVE COST $1,694 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM FT inches FT (m) _ (m) (m/hr) (daN) 1 7116071 4 window mill 3 x 25 4137 0 I 1200 400 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi gallons (m/min) 1 Gardener /Den 3.75X5 1230 2.5 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) 2 3/8x2 /38 ctc 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) WGT BAR WFT 3.98 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) HYD DISC 7/8B 1.53 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) DUAL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) ORIENTER 30 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP HCC - BIT 0.82 CEMENT TEST BOP TOTAL 26.06 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 I 0 0 Decca Consulting LTD. DAILY DRILLING REPORT DAY 5 WELL NAME Rutter and Wilbanks Corporation DATE 18- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4138.4 AFE NUMBER 0 PROGRESS 1.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Look at hole in coil tube AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0900 Work on depth tracker on coil tube and inspect crack in DESCRIPTION COST ($) coil tubing drill line, Ed burrell called office of schlumberger they Supervisor cost 1,500 said that it was going to take 5 -7 days to replace coil tubing spool Rain for rent 757 had to come from the north slope. Shut down send men home and Hotel &food 2,000 wait on new coil tubing drill line. Trailor &gen 150 Baker tools 5,000 Schlumberger 25,204 Mi swaco 4,000 Mud Products & Mud Van 0 TOTAL DAY 38,611 TOTAL CUMULATIVE 353,737 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal (s/) (cc/30 min) (mm) mg/I (Pa) (mPas) lb /100f12 ( %) ( %) ( %) (m3) (m3) 8.5 46 9 200 12 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST ($) $0 MUD COMPANY IMI Swaco I MUD TYPEIPolymer I CUMULATIVE COST $1,694 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM INCHES (mm) FT FT (m) FT /H (daN) 1 7116071 4 window mill 3 x 25 4137 4138 1 6 0 G I IN I 1200 400 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) psi barrels (m/min) ANGLE ( °) 1 Gardener /den 3.75x5 1230 2.5 KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). 23/8x2 3 /8ctc 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK GRADIENT (kPa/m) WGT BAR WFT 3.98 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) HYD DISC 7/88 1.53 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) DUAL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREITNER 30 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP HCC - - BIT 0.82 CEMENT TEST BOP TOTAL 26.06 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE/FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1 -713- 823 -7789 • • Decca Cosulting LTD. DAILY DRILLING REPORT DAY 6 WELL NAME Rutter and Wilbanks Corporation DATE _ 23- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) wait on day lights AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0300 Coil tubing on location DESCRIPTION COST ($) 0300 -0600 Remove and install new coil tubing reel 0600 -1800 Rig up coil in stab into injector reel 1800 -2400 test connectors and test BOP,s all valves,blind rams, pipe ram, accumutalor, low test 250psi,high test 5000psi 2400 -0100 clean up wait on day lights we only have one crew so there will be no night shit. Ed burrell said that they will have one for tommorow night. Note= I will get with men and get accumulated cost for down time and pull on tommorows report. Mud Products & Mud Van 0 TOTAL DAY 0 TOTAL CUMULATIVE 353,737 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg/m3) (ml) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST ($) $0 MUD COMPANY I MI Swaco ( MUD TYPE [Polymer I CUMULATIVE COST $1,694 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) ( m) (m/hr) (daN) 0 0 I I PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m/min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE/ROAD CONDITION WEATHER/TEMPERATURE (°C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1- 713 - 823 -7789 • Decca Cosulting LTD. S DAILY DRILLING REPORT DAY 7 WELL NAME Rutter and Wilbanks Corporation DATE 24- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4140.0 AFE NUMBER 0 PROGRESS 4.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Weight up mud system AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0900 -1000 Make up BHA DESCRIPTION COST ($) 1000 -1100 Displace coil tube to mud 9.2 barrels Supervisor 1,500 1100 -1130 RIH @ 100ft/hr w /milling assembly Schlumberger 118,798 w /with no pump 4700pounds w /pump on 5300pounds Mi swaco 12,000 1130 -1230 Tag @ 4126FT made depth correction to 4136FT Trailor &gen 1,050 1230 -1630 Start pump record pressures @ 2.4 BPM,923psi on pump Contingency 6,000 73psi on wellhead,begin milling @ 4136FT,drill to 4140Ft Baker Tools 71,400 1630 -1800 Encounter pit gain, stopped pump,pull up and monitored Hotels &food 1,500 well flow back to surface 1- barrel per minute for 10 minutes,shut well in RAIN for rent 5,299 30 minutes pressure build up to 2146psi, clhorides at 16,000 1800 -2000 Decision with town and Bill, decision was made to weight up 2000 -0600 mix barite and build up weight to 15.6 ppg mud, pump and displace hole to hold back salt water influx. Pump at reduced rate .8 Mud Products & Mud Van 7,146 barrels per /min, shut well in w /600psi on choke read and record shut in TOTAL DAY 224,693 pressures.Mix up surface tank to 15.6 ppg. TOTAL CUMULATIVE _ 578,430 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES LB /GAL s/qt (cc/30 min) 1/32" (ppm) (Pa) cp Ib /100ft (%) ( %) ( '5) (m3) (m3) 15.6 52 2/ 9 16000 18 23 41 0/59 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT m-I bar DOU -VIS MUD VAN DAILY AMOUNT (sx or I) 660 8 COST COST($) 5794 1352 $7,146 MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $8,840 BIT DATA BIT# SERIAL# SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inches inches FT Ft Ft BARREL (daN) 1 7116071 4 window mill 3 x I 0 4136 4140 4 2 I I 1200 400 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi barrels FT/MIN 1 Gardener /Den 3.75x5 1230 2.4 164.77 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). 2 3/8x2 3/8 ctc 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK - OFF GRADIENT(kPa/m) WGT BAR WFT 3.98 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) HYD DISC 7/8B 1.53 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) DAUL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTNER 30 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP HCC - - BIT 0.82 CEMENT TEST BOP TOTAL 26.06 TOTAL 0.00 LEASE /ROAD CONDITION GOOD WEATHER/TEMPERATURE ( °C) 65 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907- 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 8 WELL NAME Rutter and Wilbanks Corporation DATE 25- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4154.0 AFE NUMBER 0 PROGRESS 14.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Perform leak off test AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -1200 Shut in well and read and record pressures shut in at start DESCRIPTION COST ($) 600psi finshed at 1200psi.Mix surface tanks up to 15.6 w /barite. Supervisor 5,500 1200 -1400 RIH at 100FT per /min to 4111Ft circ at 1.9 barrels per /min Schlumberger 42,265 salt water coming back at a weight of 8.5ppg. Displaceed 140 barrels of Rain for rent 757 15.6 mud before we got returns back.Dropped down to 14 ppg and Contingency 10,000 returns came back. Loses about 60 barrels of weighted mud Hotel &food 2,000 1400 -1800 Build volume in mud tank and tranfer old mud from holding Baker tools 4,000 tank , hock up tranfer tank. Trailor &Gen 150 1800 -2230 RIH to 4139.2 start to cut window, establish new pump MI -SWACO 9,793 pressure of 2662 on pump and 1050 on well head at 2.4 barrels pre /min to make sure that we do not build volume. 2230 -0300 Drill open hole from 4144FT- 4154FT wellhead Press 1674 psi,pump 2636psi Mud Products & Mud Van 7,674 0300 -0500 POOH F/4154 -TO Ft TOTAL DAY 82,139 0500 -0600 Perform leak off test on formation. TOTAL CUMULATIVE 660,569 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal s/qt (cc/30 min) (mm) (ppm) (Pa) cp lb /100ft ( %) ( %) ( %) barrel barrel 11 42 9 9 8 14 60 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT barite soda -ash DUA -VIS ASPHASOL RESINEX POLY -SUPR MUD VAN DAILY AMOUNT (sx or I) 654 2 5 2 2 4 COST COST($) 5690 50 845 175 214 700 $7,674 MUD COMPANY IMI Swaco I MUD TYPE 'Polymer J CUMULATIVE COST $16,514 BIT DATA BIT# SERIAL# SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inches inches (m) (m) (m) (m/hr) (daN) 1 7116071 4 window 3 I x I 0 4139 -4139 0 12 400 ' PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) psi B /MIN FT/MIN 1 Gardener /Den 3.75x5 2560 2.4 164.77 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). 2 3/8x2 3/8 ctc 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) WGT BAR WFT 3.98 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) HYD DISC 7/8B 1.53 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) DAUL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTER 30 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP HCC - - BIT 0.82 CEMENT TEST BOP _ TOTAL 26.06 TOTAL 0.00 LEASE/ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 65 CONTRACTOR TOOLPUSH Ed burrell TELEPHONE/FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX* 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 9 WELL NAME Rutter and Wilbanks Corporation DATE 26- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4222.0 AFE NUMBER 0 PROGRESS 68.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Change out choke on manifold AFE Cost Estimate _ 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0630 Preform leak off test on formation started at 1 /4bbl at a time DESCRIPTION COST ($) then we pumped at 1 -bbl /per min stayed the at the same at 2000 Hotel& food 2,000 wellhead pressure we just pumped it into the formation. Schlumberger 44,000 0630 -1130 POOH w /milling assembly and laydown tools (mill still in gage) rain for rent 757 Pick up drilling BHA . Install Ptlubricator Supervisor 1,500 1130 -1300 RIH w /new BHA to 4154FT ,flag pipe make depth correction Mi -swaco 7,600 1300 -1500 Drill F/4154- T/4175FT Trailor and Gen 150 1500 -1600 Repair washed out choke on manifold Baker tools 3,500 1600 -1930 Drill F/4175- 4183FT incountered drilling break small influx Contingency 5,000 of gas to surface drill to 4210FT 1930 -0600 Start to control drill F4210- 4222Ft and control water flow to surface, pressure 3029psi,wellhead 1962psi, we are having small amounts of gas flow spikes to surface. Mud Products & Mud Van 0 TOTAL DAY 64,507 TOTAL CUMULATIVE - 725,076 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES ppg (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 9.5 42 9 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST ($) $0 MUD COMPANY IMI Swaco 1 MUD TYPE 'Polymer I CUMULATIVE COST $16,514 BIT DATA BIT # SERIAL# SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM - Inches (mm) Ft (m) Ft (m/hr) (daN) 1 4 PDC 6 I x 25 4154 68 0 I 5000 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3/min) (m /min) 1 Gardener /Den 3x3.75 3029 164.7 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5 - 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE/ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 65 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # !- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907- 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 10 WELL NAME _ Rutter and Wilbanks Corporation DATE 27- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4337.0 AFE NUMBER 0 PROGRESS 115.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Drill ahead AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0630 Repair choke on manifold DESCRIPTION COST ($) 0630 -0930 Drill ahead F/4222- 4251FT Supervisor 1,500 0930 -1100 Repair computor on rig crashed Schlumberger 43,128 1100 -1200 Drill ahead F/4251- 4254FT Rain for rent 757 1200 -1900 Stop drill pull up into casing and install new choke parts Mi -Swaco 4,000 and Repair wash out paking in mud pump. Trailor &Gen 150 1900 -0600 Control Drill F/4254- T/4337Ft Hotels &Food 2,000 Having Good gas to surface and it is building as we drill deeper Contingency 5,000 Good gas spikes last night. Baker tools 1,500 Mud Products & Mud Van 1,690 TOTAL DAY 59,725 TOTAL CUMULATIVE 784,801 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg/m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 9.2 45 8.5 15000 6 - 15 4.5 60 MUD PRO_ DUCTS USED (Past 24 hrs) PRODUCT DUO -VIS MUD VAN DAILY AMOUNT (sx or I) _ 10 COST COST($) 1690 $1,690 MUD COMPANY IMI Swaco I MUD TYPETPolymer I CUMULATIVE COST $18,204 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inches inches FR (m) (m) (m/hr) (daN) 1 4 PDC 6 x 25 4154 0 I 5000 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m/min) ANGLE ( °) 1 Gardener /Den 3x3.75 3029 2.4 164.7 KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). coil conn 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) bpv 1.57 RIG UP SURVEY LEAK -OFF GRADIENT(kPa/m) hyd disc 1.53 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 3/4 circ sub 1.15 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) wt bar 3.14 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) oreintor 4.86 CIRCULATE WELD ON BOWL motor 11.2 RUN CASING NIPPLE UP BOP mill 0.83 CEMENT TEST BOP TOTAL 25.23 TOTAL 0.00 LEASE/ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 70 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907- 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 11 WELL NAME Rutter and Wilbanks Corporation DATE 28- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4341.0 AFE NUMBER 0 PROGRESS 4.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Wait on bit AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0730 Drill F/4337 -4341 Ft DESCRIPTION COST ($) 0730 -1500 POOH to inspect motor and bit. Bit had crack in body and Schlumberger 43,128 broke when we attempt to take off the motor. Supervisor 1,500 1500 -1630 Test all valves on choke manifold. Test 250 psi low & 5000 Hotels &Food 2,000 high. Tested good with no problems. Baker Tools 3,500 1630 -1830 RIH with new bit and new directional motor. Tag up at Rain for Rent 757 at whipstock trying to orient bit & motor thru window. Contingency 6,000 1830 -2030 Change orientation Trailor &Gen 150 2030 -2300 RIH. Attempt to get thru window into open hole MI -swaco 4,000 2300 -2400 Still having problems at window or just into open hole. POOH No marks or damage to 3 -3/4" bit. 2400 -0400 Remove new motor & try old motor. Bit stopped at 4154ft. May have window or hole problem. POOH and check bit ODs. Mud Products & Mud Van 328 0400 -0600 POOH. Still having problems at window or with hole. TOTAL DAY 61,363 TOTAL CUMULATIVE 846,164 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb/gal s /qt (cc/30 min) (mm) mg/I (Pa) cp lb /10082 ( %) ( %) ( %) (m3) (m3) 9.2 43 8.6 16000 6 14 4 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT Dou -vis MUD VAN DAILY AMOUNT (sx or I) 2 COST COST ($) 328 $328 MUD COMPANY IMI Swaco I MUD TYPE !Polymer I CUMULATIVE COST $18,532 BIT DATA BIT# SERIAL# SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM lnnches (mm) (m) (m) (m) (m/hr) (daN) 1 10022786 418 PDC 6 I x I 25 4341 0 I 1200 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi bbl /min (m/min) 1 Gardener /Den 3x3.75 3029 2.4 164.7 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) COIL CONN 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) HYD DISC 1.53 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) CIRC SUB 1.15 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) WT BAR 3.14 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTOR 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP BIT 0.52 CEMENT TEST BOP TOTAL 24.92 TOTAL 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 70 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7789 SUPERVISOR Ed Scott TELEPHONE /FAX # . 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 12 WELL NAME Rutter and Wilbanks Corporation DATE 29- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. _ 4280FT OPERATION (06:00 hrs) POOH to look at bit AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -1130 RIH to window and mill window. Work thru window & tag DESCRIPTION COST ($) at 4154 ft. Ream 4154 to 4162. Large cuttings plugged Schlumberger 43,128 choke. Cutting appear to be sandstone. Rain for Rent 757 1130 -1230 POOH w /milling assembly and laydown BHA MI -Swaco 4,000 1230 -1330 Cut 110 ft of 2 -3/8" coil to move stress point. Hotel &Food 2,000 1330 -1630 Make up bull nose wash nozzle. Contingency 5,000 1630 -1800 RIH to 4159 ft & try to wash out hole with high vis sweeps Trailor &Gen 150 1800 -2130 POOH & make new BHA w /new Bi- center bit Baker Tools 3,500 2130 -2300 RIH to 4158 ft. 2300- 0400 Ream hole to 4162 ft. Reaming operations are rough. 0400 -0600 POOH to take a look at bit and laydown oreintor. Mud Products & Mud Van 1,304 TOTAL DAY 59,839 TOTAL CUMULATIVE 906,003 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal s/qt (cc/30 min) (mm) (ppm) (Pa) cp 11b/100ft ( %) ( %) ( %) (m3) (m3) 9.1 44 8.6 15000 6 15 tr 4 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT DOU -VIS DEFOAM -X MUD VAN DAILY AMOUNT (sx or I) 6 2 COST COST(S) 1014 290 $1,304 MUD COMPANY IMI Swaco I MUD TYPE 'Polymer I CUMULATIVE COST $19,836 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE Depth DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inch inches Ft (m) (m) (m/hr) (daN) 3 7010798 370 bi center 6 I x 25 4337 0 3000 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi (m3 /min) ft/min 1 Gardener /den 3x3.75 3039 164.7 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). coil Conn 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) HYP DISION 1.53 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) CIRC SUB 1.15 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) WT BAR 3.14 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTOR 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP BI - CENTER 0.78 CEMENT TEST BOP TOTAL 25.18 TOTAL 0.00 LEASE/ROAD CONDITION Good WEATHER/TEMPERATURE (°C) 70 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1- 713 - 823 -7789 i Decca Consulting LTD. DAILY DRILLING REPORT DAY 13 WELL NAME Rutter and Wilbanks Corporation DATE 30- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Wait on day light AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0630 Made a correction to CT depth of 19.8 ft with cut off DESCRIPTION COST ($) 0630 -0730 Pick up BHA and and connect to well head Supervisor 1,500 • 0730 -1100 RIH. Wash to bottom. Have problems getting thru window. Schlumberger 60,000 Wash down to 4154 ft and start to mill Rain for rent 757 1100 -1430 No progress with mill. Mi -Swaco 4,000 1430 -1530 Pull back into casing and stand buy Contingency 5,000 1530 -1700 Decision was made to stop and plug sidetrack at 1830 hrs. Hotel &Food 2,000 Prepare to plug sidetrack & wellbore with cement. Trailor &Gen 150 Note: Received verbal approval at 1830 hrs from AOGCC to stop operations and prepare to plug sidetrack with cement. Mud Products & Mud Van 0 TOTAL DAY 73,407 TOTAL CUMULATIVE 919,571 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST ($) $0 MUD COMPANY IMI Swaco I MUD TYPE 'Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL# SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m/ (daN) I 0 0 hr) 1 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m/min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK -OFF GRADIENT(kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE/ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FM # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 I 0 Decca Consulting LTD. DAILY DRILLING REPORT DAY 14 WELL NAME Rutter and Wilbanks Corporation DATE 1-Jul-07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) WOC AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0730 Install connector,stringer andjet swirl nozzle. Install DESCRIPTION COST ($) injector, prime G pump and pressure up to 5000 psi Mi -Swaco 6,197 0730 -0900 Start mixing and batching mix water Schlumberger 58,784 0900 -1030 Circulate & establish fuild rates Rain for Rent 757 1030 -1500 RIH establish string weight at 8000 pounds at 4100 ft. Hotel &Food 2,000 Conducted injectivity tests, clean up well, circ and continue Trailor &Gen 150 to mix up cement and up to 15.6 ppg Supervisor 1,500 1500 -1700 Pre job safety & discuss cement job. Pump 3 bbls spacer Contingency 7,000 & 16 bbls Class G fiber cement with .04 gal /sk antifoam, 0.050 gal /sk LT Dispers, GasBlok 1.5 gal /sk, Accelerator 0.10 gal /sk. Displace with 7 bbls water & 22 bbls water thru coil. Pull coil at 100 ft/min & pump at 1.1 bpmto 3200 ft. Choke manifold back pressure at 2500psi Mud Products & Mud Van 0 1700 -1900 Sqeeze to 2500 psi for 30 min and 3000 psi for 30 min. TOTAL DAY 76,388 Shut in well and WOC. TOTAL CUMULATIVE 922,552 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM LOSSES (kg/m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST (S) $0 MUD COMPANY IMI Swaco I MUD TYPE 'Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (mmr) (daN) I 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3/min) (m/min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE/FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX# 1 - 907 - 320 - 0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX # 1- 713 - 823 -7789 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 15 WELL NAME Rutter and Wilbanks Corporation DATE 2- Jul -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Haul out Rig AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0700 RIH tag cement at 3210FT,positive pressure test of 3000psi DESCRIPTION COST ($) 0700 -0800 POOH and displace well, Supervisor 1,500 0800 -1000 Stop at freeze depth pump 3- barrels away deisel Schlumberger cement 68,827 1000 -1400 conducted negative pressure test 0 pressure on well Secure Schlumberger 50,265 1400 -1430 pressure up well to 500psi Trucking _ 101,646 Rig Released at 1430pm Hotel &Food 2,000 Trailor &Gen 150 Rain for Rent 757 FINAL REPORT Weatherford 747 Vac Truck 18,000 Mud Products & Mud Van 0 TOTAL DAY 243,892 TOTAL CUMULATIVE 1,299,681 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg/m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) (%) ( %) ( %) (m3) (m3) 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST ($) $0 MUD COMPANY IMISwaco I MUD TYPE I Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m/hr) (daN) I o 0 1 1 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m/min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP _ TOTAL I 0 TOTAL 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE (°C) 65 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE/FAX* 1 -713- 823 -7789 • • 1 Decca Consulting LTD. DAILY DRILLING REPORT DAY 16 WELL NAME _ Rutter and Wilbanks Corporation DATE _ 3- Jul -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER #REF! PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY Check well pressure after vetco installed well head. Pressure was 300psi DESCRIPTION COST ($) After 12 hours, the pessure was still 300 psi. Shut valves & Secure tree. Supervisor 1,500 Vetco Gray 4,279 Clean up location of all garbage. Clean out Rain For Rent tanks. Mark Roti 7,978 Four trailer on location to be picked up by Weaver Brothers in the Man lift &trucking 3,800 morning. Copper Basin San 2,000 Copper Basin Dispose) 2,000 Mud Products & Mud Van 0 TOTAL DAY 21,557 TOTAL CUMULATIVE 1,321,238 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s/I) (cc/30 min) (mm) (ppm) (Pa) (mPas) (Pa) , ( %) ( %) ( %) (m3) (m3) 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST (5) $0 MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m/hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m/min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5 - 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907- 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Tuesday, July 10, 2007 9:31 AM To: Maunder, Thomas E (DOA) Subject: Update No problem. Mick or I will be in contact shortly at least with completion forms. Eddie Original Message From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, July 10, 2007 12:25 PM To: Eddie Wright Subject: RE: What Did you receive? Thanks Eddie. Lets stay in touch as the new plans come together so we can do the naming and permitting correctly. Tom Original Message From: Eddie Wright [mailto:ewright @peiinc.com] Sent: Tuesday, July 10, 2007 9:22 AM To: Maunder, Thomas E (DOA) Subject: RE: What Did you receive? Tom I will check with Mick about the 407 Completion report that I prepared. He should be ready to submit this. We talked last night and he is out of town so I forwarded this to a separate email address for his review. Mick believes that we will be back on this well shortly. Mr. Rutter is close to having his funding in place to cut /pull the 5 ", sidetrack /drill to 4200', set 5" with a drill rig. Then we will bring back Schlumberger to drill the three zones down to 4500'. Final casing /tubing design is still in talking stages. Still chasing the pictures. Eddie Original Message From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, July 09, 2007 4:03 PM To: Eddie Wright Subject: RE: What Did you receive? Hi Eddie, We received the 403 sundry notice regarding the plugging work you and I discussed and Commissioner Foerster orally approved. I checked our incoming log and thus far we have not received the 407 (completion report). With regard to your message, at this time no 401 (permit to drill) is needed. When work is resumed the next document needed would be a 403 to re- enter the suspended well. Based on our discussion, that sundry would cover cutting and pulling the casing and setting whatever cement plugs are necessary to abandon 1 -19A. Then a 407 would close out that work. A new 401 would be needed to drill the new penetration 1 -19B. I suspect we will talk further on the future activities. FYI, enclosed is a well document flow sheet I put together. Hope it helps. Tom Original Message From: Eddie Wright [ mailto:ewright@peiinc.com] Sent: Monday, July 09, 2007 12:39 PM 1 • • To: Maunder, Thomas E (DOA) Subject: What Did you receive? Tom I forwarded the 407 Completion Report and the 401 Sundry Notice to Mick Franscico. Mick has not had time to review the information. So Mick and I have not sent you any reports. What did you receive from whom? Scott took pictures of location. I have not received his pictures yet. Eddie > Hi Eddie, > The sundry has been signed and will be mailed to Midland. As you put > the final paperwork together, please note the form to submit is a 407. > Suspended is a defined completion status under our regulations. > Did anyone get any photos of the location after rig down? > Best regards, > Tom Maunder, PE > AOGCC 2 • • Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Thursday, August 09, 2007 7:29 AM To: Maunder, Thomas E (DOA) Subject: RE: Ahtna #1 -19A Completion Report Tom, I will check with Mick for any updates and send you what I prepared along with pictures of location. Eddie > Hi Eddie, > Our log does not show that we have recently received anything > regarding the well. Was sort of wondering if a document was enroute. > Look forward to your reply. > Tom Maunder, PE > AOGCC > Original Message > From: Eddie Wright [mailto:ewright @peiinc.com] > Sent: Wednesday, August 08, 2007 9:53 AM > To: Maunder, Thomas E (DOA) > Subject: Ahtna #1 -19A Completion Report > Tom, > Did you receive a completion report? > Eddie Wright > Petroleum Engineers, Inc. > Three Riverway, Ste 1500 > Houston, TX 77056 > Office: 713 - 479 -7070 > Cell: 713 - 823 -7789 1 0 0 4/03/07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Schlumberger Rig No.: 1 DATE: 6/16/07 Rig Rep.: Ed Burrell Rig Phone: 398 -7272 Rig Fax: Operator: Rutter & Wilbanks Corp. Op. Phone: 320-0504 Op. Fax: Rep.: Ed Scott E -Mail ,; _- Well Name: ATHNA #1 -19A PTD # 207-085 Operation: Drlg: X Workover Explor.: X Test: Initial: X Weeldy: x Bi- Weekly Test Pressure: Rams: 500/5000 Annular. x Valves: 500/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drt. Rig NA Lower Kelly NA PTD On Location P Hazard Sec. P Bali Type NA Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8 P Trip Tank P NA Annular Preventer NA Pit Level Indicators NA NA #1 Rams 1 blind rams P Flow Indicator NA NA #2 Rams 1 2 -3/8 "pipe P Meth Gas Detector NA NA #3 Rams 1 blind rams P H2S Gas Detector NA NA #4 Rams 1 2 -3/8" pipe P #5 Rams NA Quantity Test Result Choke Ln. Valves 2 r plug P Inside Reel valves 1 P HCR Valves NA Kill Line Valves 2 2" plug P ACCUMULATOR SYSTEM: Check Valve NA Time/Pressure Test Result System Pressure 2500 P CHOKE MANIFOLD: Pressure After Closure 1200 P Quantity Test Result 200 psi Attained NT No. Valves 3 P Full Pressure Attained 2500 P Manual Chokes 2 P Blind Switch Covers: All stations Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 1000 psi Test Results Number of Failures: 0 Test Time: 3 Hours Components tested 24 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: ___ " :::, : ,- Remarks: Held pressure on annulus for 30 min. 2500 psi see chart.Test went good know problems on new BOP's and casing from surface to 4170Ft to top of cement. Held low 500 -5min high 5000 -5min Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES yes NO c - Oper. /Rig Waived By c - Database Date 6/15/07 Time 1200 c - Trip Rpt File Witness Ed Scott c - Inspector Test start 6 -16-07 1420 Finish 6- 16-07 1720 2007_0616_Ahtna_1- 19ABOP Test 6- 16-07.xls 2007 0616 Ahtna_1 -19A BOP Test 6- 16- 07.xls 40 s irair oF SARAH PALIN, 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 Eddie Wright Project Engineer Rutter & Wilbanks Corporation 301 S. Main St., Suite B PO Box 3186 Midland, TX 79702 Re: Exploration, Wildcat, Ahtna #1-19A Sundry Number: 307 -228 Dear Mr. Wright: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, fr, , . N. ' 1 an Chairman DATED this day of July, 2007 Encl. ( c;f -o,� RECEIVED 1>� S TATE OF ALASKA A 7 ALASKA OIL AND GAS CONSERVATION COMSION! UL 0 3 2007 // j MIS APPLICATION FOR SUNDRY A PPROVA �� ka 01! & Gas Cons. Commission 20 AAC 25.280 Any i 1. Type of Request: Abandon ❑ Suspend � f perational shutdown 1=1 Perforate ❑ Waiver Other 0 Alter casing ❑ Repair well ❑ P Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Plug Sidetrack Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number , '? .7 Rutter & Wilbanks Corporation Development ❑ Exploratory 0 'i95A1L 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: al OD 11 4 P.O. Box 3186, Midland, TX 79702 50- 099 - 20005 / 9•.5 7 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: Ahtna #1 -19A Spacing Exception Required? Yes El No ❑ 9. Property Designation:f�C�S' --. /44 10. KB Elevation (ft): 11. Field / Pool(s): Sec. 19, T-4 -N, R -3 -W 2037' KB 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): (Total Depth TVD (ft): ( Effective Depth MD (ft): ( Effective Depth TVD (ft): ( Plugs (measured): ( Junk (measured): PBTD 4536' ELM (TOC) PBTD 4536' ELM 1 - (99' 4536-4635' Casing Length Size MD TVD Burst Collapse Structural Conductor 78' BGL 13 -3/8 78' BGL 78" BGL Surface 1226 9 -5/8 1226 1226 5,750 3,090 Intermediate 1915 7 1915 1915 7240 5410 Production 4639 5" 4639 4639 10,140 10,490 Liner 588 3-1/2 5165 5165 10,160 10,540 Perforation Depth MD (ft): ( Perforation Depth TVD (ft): ( Tubing Size: ( Tubing Grade: ( Tubing MD (ft): 4232 -4387 4232 -4387 2 -7/8 L -80 49.6 Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal IN 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Development ❑ Service ❑ 15. Estimated Date for in ry./� 16. Well Status after proposed work: Commencing Operations: 1� ^�� I � 1 • _ t Oil ❑ Gas 0 Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: "'1i WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: C.AIMRS c' V), {„„T�cM 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Eddie Wrighty Title Project Engineer Signature 4love Phone 713- 823 -7789 Date 7/2/2007 � Gft � i�` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness (Sundry Number: 307„ ,.. Plug Integrity ❑ p BOP Test ❑ Mechanical Integrity Test El Location Clearance [ s Other: Q �� C��GV x,st.a l_ tz. vs. ttok 6 ck. G 1'4: i C `foist kQ C ciAin1\ Subsequent Form Required: 1„ lV1 W i a G. h� S BFL JUL 20D7 APPROVED BY ./) Approved by: ft _ .. " M . ISSIONER THE COMMISSION Date: V 7--- Form 10 -403 Revised 06/2006 0 lb 1 6 A . ,(�j /liubmit in Duplicate :, , • • APPLICATION FOR SUNDRY APPROVALS Rutter & Wilbanks Corporation Ahtna #1 -19 Ps Plug Side track Operations Descriptions of Operations Estimated operational start is 7 -1 -07 to plug the side track operations. We reached a decision point on 6/30/07 at the Rutter & Wilbank Corp., Ahtna #1 -19A. Our decision is to plug the existing coil tubing drilling effort and suspend operations. We would like to propose plugging the sidetrack hole because we can no longer get below 4154' to re -enter the sidetrack hole drilled to 4337'. Mulitple efforts have been tried over a three day period that include two different bit styles, one window mill & reamer, two different mud mottors, and one simple 2 -3/8" wash nozzle. Our plan is to fill the well from 4154' to 3200' with 16 bbls of cement. Then pressure squeeze up to 7.6 bbls of cement out the window or until a squeeze pressure of 2100 psig has reached. If the squeeze pressure is not reached, then we will stop the displacement at 7.6 bbls and leave a 500 ft cement plug in the well from 3629' to 4129' (top of window). Verbal approval was received at 6:30 pm on 6 -30 -07 to proceed with plugging operations from the AOGCC by Commissioner Foerster through Thomas Maunder. After plugging operations are complete we will rig down all equipment and suspend operation • • RECEIVED Petroleum Engineers, Inc. JUL 0 3 2007 Three Riverway, Suite 1500 Alaska Oil & Gas Cons. Commission Houston, TX 77056 Anchorage July 2, 2007 Mr. Thomas Maunder Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed is a copy of the 10 -403, Application for Sundry Approval to stop operations and plug the side track. This notice is a follow up to our conversations on 6 /30 /07you're your verbal approval received at 6:30 pm on 6/30/07 to proceed with plugging operations. Form 10 -404, Report of Sundry Well Operations will be prepared for the plugging operations. Another Form 10 -403 Application of Sundry Approval will be prepared to suspend operations. If you have any questions, please contact my office or telephone 713 - 823 -7789. Sincerely yours, Eddie L. Wright, P.E. Petroleum Engineers, Inc. Office: 713- 479 -7070 Cell: 713- 823 -7789 Email: ewright @peiinc.com Page 1 of 1 • • Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Wednesday, July 04, 2007 4:37 AM To: Maunder, Thomas E (DOA) Cc: mfrancisco@houston.rr.com Subject: RE: Rutter and Wilbanks Corporation Ahtna #1 -19A a ny - octsc Tom, I'll call Ed Scott this morning and see if he can take some final pictures. Thanks again for all your help. Eddie Wright From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, July 03, 2007 1:06 PM To: mfrancisco @houston.rr.com Cc: Eddie Wright Subject: RE: Rutter and Wilbanks Corporation Ahtna #1 -19A Mick and Eddie, Thanks. Is there anyone still there to take photos of the cleaned location? Such documentation would be good to have. Call or message with any questions. Tom Maunder, PE AOGCC From: Mick Francisco [mailto:mfrancisco @soginc.net] Sent: Tuesday, July 03, 2007 9:59 AM To: Maunder, Thomas E (DOA) Cc: Eddie Wright Subject: Rutter and Wilbanks Corporation Ahtna #1 -19A Tom, People are scattering and I wanted to be sure you got a copy of the final report for the Ahtna #1 -19A well. Things are pretty well moved off location. We are regrouping and shall be in touch with a plan. Thanks for all the help, Mick Francisco Rutter and Wilbanks 7/6/2007 Page 1 of 2 • • Maunder, Thomas E (DOA) From: Sent: Sunday, July 01, 2007 9:29 PM To: Maunder, Thomas E (DOA) Subject: Fwd: Rutter & Wilbank Corp. _Ahtna #1 -19A_ Update Original Message From: Eddie Wright <ewright @peiinc.com> To: Sent: Sun, 1 Jul 2007 6:22 pm Subject: RE: Rutter & Wilbank Corp. _ Ahtna #1-19A_ Update Tom Thanks for all your help. I believe the program was a success. We have learned a method to get gas out of the sand. Just wish we could have extended the hole to see the next two sands. We spotted our Schlumberger cement which is a fiber -type Class G mix to protect against gas and water flow. We mixed and pumped 16 bbls to fill casing up to 3200' with cement in place at 4:45 pm today. We tried to squeeze cement out the window with 2500 psig for 30 minutes. I have requested that we go up to 3000 psig for 30 minutes. We have not been able to squeeze any cement down the casing. Our estimated top of cement as we pulled out is 3214'. We will tagged cement under pressure tomorrow morning. If all looks well, we will conduct a negative test by bleeding off pressure and monitor SI pressure. Then perform a positive test to verify cement is in place. I will have the Sundry Notice mailed in the morning through an over night service. The Sundry Notice should be in your offices on Tuesday morning. Eddie From: Sent: Sunday, July 01, 2007 11:44 AM To: ewright©peiinc.com; tom _maunder @adm i n-.state.ak.us Cc: mfranci sco @houston.rr.com; sickiscott2205 @yahoo.com; eburrell @kenai.oilfieid.slb.com Subject: Re: Rutter & Wilbank Corp. _ Ahtna #1-19A_ Update Eddie, et al, Unfortunate that you have not been able to get much beyond the window. As noted in our conversations, Commissioner Foerster has given verbal approval of your plan. Doing the positive and negative pressure tests is a good plan. Please plan to submit the sundry application for this work early in work week. Based on our discussions, the well status will be suspended. Based on our conversations, it would appear that the well has utility for another sidetrack. Good luck with the forward work. Call or message with any questions. Tom Maunder, PE AOGCC 529 -1645 7/6/2007 • Page 2 of 2 Original Message From: Eddie Wright <ewright @peiinc.com> To: 'Thomas Maunder' < tom _maunder @admin.state.ak.us>; Cc: 'Michael S. "Mick" Francisco' <mfrancisco @houston.rr.com >; 'ed scott' <sickiscott2205 @yahoo.com >; 'Ed Burrell' <eburrell@enai.oilfield.slb.com> Sent: Sat, 30 Jun 2007 8:26 pm Subject: RE: Rutter & Wilbank Corp. _ Ahtna #1-19A_ Update Tom, Based on your phone call, we have been verbally approved to proceed with plugging operations by Commissioner Foerster. We will stop a cement plug from 4154' to 3200', then attempting to reach a squeeze pressure of 2100 psig. If the squeeze pressure is not reached after pumping 7.6 bbls, we will shut the well in. this will leave the top of cement at 3629'. This will be a 500 -ft plug of cement in the casing above the window top at 4129'. We will wait on cement for 24 hrs, and then perform negative and positive tests to verify the cement plug is holding. Thanks again, Eddie Wright From: Eddie Wright [mailto ewright ©peiinc.com] Sent: Saturday, June 30, 2007 11:13 PM To: Thomas Maunder'; ' Cc: 'Michael S. "Mick" Francisco'; 'ed scott'; 'Ed Burrell' Subject: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Importance: High Tom, We have reached a decision point on the Ahtna #1 -19A. Our decision is to plug the existing coil tubing drilling effort and suspend operations. We would like to propose plugging the sidetrack hole because we can no longer get below 4154' and cannot re -enter the sidetrack hole drilled to 4337'. Our plan is to fill the well from 4154' to 3200' with 16 bbls of cement. Then pressure squeeze up to 7.6 bbls of cement out the window or until a squeeze pressure of 2100 psig has reached. If the squeeze pressure is not reached, then we will stop the displacement at 7.6 bbls and leave a 500 ft cement plug in the well from 3629' to 4129' (top of window). Thanks for your assistance, Eddie Wright Petroleum Engineers, Inc. Office 713 -479 -7070 Cell 713 -823 -7789 size =2 width =" 100 %" align = center> AOL now offers free email to everyone. Find out more about what's free from AOL at AOL.com. AOL now offers free email to everyone. Find out more about what's free from AOL at AOL.com. 7/6/2007 • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Wednesday, July 04, 2007 4:37 AM To: Maunder, Thomas E (DOA) Cc: mfrancisco @houston.rr.com Subject: RE: Rutter and Wilbanks Corporation Ahtna #1 -19A Tom, I'll call Ed Scott this morning and see if he can take some final pictures. Thanks again for all your help. Eddie Wright From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, July 03, 2007 1:06 PM To: mfrancisco @houston.rr.com Cc: Eddie Wright Subject: RE: Rutter and Wilbanks Corporation Ahtna #1 -19A Mick and Eddie, Thanks. Is there anyone still there to take photos of the cleaned location? Such documentation would be good to have. Call or message with any questions. Tom Maunder, PE AOGCC From: Mick Francisco [mailto:mfrancisco @soginc.net] Sent: Tuesday, July 03, 2007 9:59 AM To: Maunder, Thomas E (DOA) Cc: Eddie Wright Subject: Rutter and Wilbanks Corporation Ahtna #1 -19A Tom, People are scattering and I wanted to be sure you got a copy of the final report for the Ahtna #1 -19A well. Things are pretty well moved off location. We are regrouping and shall be in touch with a plan. Thanks for all the help, Mick Francisco Rutter and Wilbanks 6/13/2009 0 • Decca Consulting LTD. 1 DAILY DRILLING REPORT DAY 18 WELL NAME Rutter and Wilbanks Corporation DATE 2- Jul -07 LOCATION (UWI) Athna #1 -19A Sec.19.T- 4- N.R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Haul out Rig AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0700 RIH tag cement at 3210FT,positive pressure test of 3000psi DESCRIPTION COST ($) 0700 -0800 POOH and displace well, Supervisor 1,500 0800 -1000 Stop at freeze depth pump 3- barrels away deisel Schlumberger cement 68,827 1000-1400 conducted negative pressure test 0 pressure on well Secure Schlumberger 50,265 1400 -1430 pressure up well to 500psi Trucking 101,646 Rig Released at 1430pm Hotel &Food 2,000 Trailor &Gen 150 Rain for Rent 757 - -- -- -- - - -- Weatherford 747 Vac Truck 18,000 FINAL REPORT Mud Products & Mud Van 0 TOTAL DAY 243,892 TOTAL CUMULATIVE 1,299,681 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST COST ($) r — 1 I so MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m /hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB j SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5 - 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP - - -- - - - --- TOTAL 0 TOTAL 1 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 65 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1 -713- 823 -7789 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Tuesday, July 03, 2007 4:05 AM To: 'Michael S. "Mick" Francisco' Cc: Maunder, Thomas E (DOA) Subject: Morning Report not in Attachments: RW_Ahtna #1- 19A_7- 1- 07_Rpt 17.xls Mick Can you take care of the morning report? Scott's report does not show the results of the negative pressure test. I have called and left message. Please edit and sent to Tom Maunder for his files. 'Thomas Maunder' tom_maunder@admin.state.ak.us Just copy Scott's report page to this spreadsheet file. It has the changed reports that I have corrected since 6/14/07. Thanks Eddie 6/13/2009 • III Decca Consulting LTD. DAILY DRILLING REPORT DAY 17 WELL NAME RLt =no`;INlbarks C-,rporatl.n DATE 1- Jul -07 LOCATION(UWI) Hthna ,-, 1-1 , , Se :1 7- 4- 0R -'W DEPTH (06:00hrs) AFE NUMBER 0 PROGRESS 00 CONTRACTOR & RIG F 5:' PROJECTED T.D rah T OPERATION (06:00 hrs) WOC AFE Cost Estimate 1 000 it L SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0730 Install connector,stnnger andjet swirl nozzle. Install DESCRIPTION COST ($) injector, prime G pump and pressure up to 5000 psi MI -Swaco 6,197 0730 -0900 Start mixing and batchinJ mix water Schlumberger 5 0900 -1030 Circulate & establish fulld rates Rain for Rent 757 1030 -1500 R IH establish string weight at 8000 pounds at 4100 ft. Hotel &Food 2,000 Conducted infectivity tests, clean up well, circ and continue Trallor &Gen 150 to mix up cement and up to 15.6 ppg Supervisor _ 1.500 1500 -1700 Prejob safety & discuss cement job. Pump 3 bbls spacer Contingency 7,000 & 16 bbls Class G fiber cement with .04 gal /sk antifoam, 0.050 _gaI /sk LT Dispers, GasBlok 1.�aI /sk, Accelerator 0.10 gal /sk. Displace with 7 bbls water & 22 bbls water thru coil. Pull coil at 100 ft/min & pump at 1.1 bpmto 3200 ft. -- - -- ---- ---- Choke manifold back pressure at 2500psi Mud Products & Mud Van 0 1700 - -1900 Sqeeze to 2500 psi for 30 min and 3000 psi for 30 min. TOTAL DAY 76,388 Shut in well and WOC. TOTAL CUMULATIVE 922,552 MUD PROPERTIES DENSIT V15CO51TY b cTrERLO FILTE,RRCAKE ® CHLOFIDES GELS �FIEHMEI DAILOLOSSES CUM LOSSES 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT _ ___ cluo VAN DAILY AM.IOUNT(sa or 11 _ - COST COST IS) — -- _. -- - - -- - $0 MUD COMPANY IMI Swaco 1 MUD TYPE [Polymer 1 CUMULATIVE COST $18,532 BIT DATA R� PITH SERIAL 512E TYPE JET SIDE DEPTH IN DEPTH OUT T HOURS RATE CONDITION OB Imml (Dm/ Im) Dc) � W Iminr, IaeM PUMP DATA SURVEY DATA PUTAP« DESCRIPTION SORE x STROKE OKES PRESSURE ANNULAR DEL DEPTH (m) (mm, ST lspm IN ) EM) Im3/REp) (m/mm) ANGLE I') KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06.00 to 06:00 hrs) CASING S¢[ m m BIT MOVE RIO _ RIG SERVICE ) c«s,NC OevTN wl BELL sue I RIG UP SURVEY GIENTIFGNm) FLOAT SDB SAFETY MEET TRIP aur,,,, s,UT.IN PRESSUN ,,, '_„5 EILID G _ -I- SPEED PURE BATE ts/DO HALD SPEED Gm ^ cPRESSNRE,a) 5 -t25 CIRCULATE WELD ON BOWL -- — - -- KELLY D - - -- _ -- - -- UN CASING 1 NIPPLE UP BOP _ - - - -- -- - -- CEMENT ) TEST BOP TOTAL 0 TOTAL 000 LEASE/ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTORTOOLPUSH Ed Bu,Cll TELEPHONE /FAX SUPERVISOR ES: 0c�I■ TELEPHONE /FAX REPORT SENT TO 00010 01,001 TELEPHONE /FAX # • Page 1 of 2 Maunder, Thomas E (DOA) From: stmaunder @aol.com Sent: Monday, July 02, 2007 6:09 AM To: Maunder, Thomas E (DOA) Subject: Fwd: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Original Message From: ed scott <sickiscott2205 @yahoo.com> To: Sent: Sun, 1 Jul 2007 11:28 pm Subject: Re: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Thanks Tom, It was nice working with you and we almost had it.Thanks for all your help look forward to working with you on another project.Ed Original Message - - -- Frs :" To: e 'tht @peiinc.com; tom maunder _ admin.state.ak.us Cc: mfran ,co whouston.rr.com; sickiscott2205 cuyahoo.com; eburrellrikenai .oilfield.slb.com Sent: Sunday, 1, 2007 10:44:24 AM Subject: Re: Rutte Wilbank Corp. _ Ahtna #1 -19A_ Update Eddie, et al, Unfortunate that you have not -n able to get much be and the window. As noted in our conversations, Commissioner Foer has given ver, .1 approval of your plan. Doing the positive and negative pressure tests is a good plan. -ase pla' o submit the sundry application for this work early in work week. Based on our discussions, the , - status will be suspended. Based on our conversations, it would appear that the well has utility for a s 'the idetrack. Good luck with the forward work. Call • message • h any questions. Tom Maunder, PE AOGCC 529 -1645 Original Messag- From: Eddie Wri: ' <ewright @peiinc.com> To: 'Thomas nder' < tom _maunder @admin.state.ak.us >; Cc: 'Michae . "Mick" Francisco' <mfrancisco(ci)houston.rr.com >; 'ed scott' <sickiscs 205 @yahoo.com >; 'Ed Burrell' < eburrell @kenai.oilfield.slb.com> Sent: ..t, 30 Jun 2007 8:26 pm Su ► ' ect: RE: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Tom, Based on your phone call, we have been verbally approved to proceed with plugging operations by Commissioner Foerster. 6/13/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Monday, July 02, 2007 1:16 AM To: eddiewright25 @hotmail.com; Eddie Wright; barry; Maunder, Thomas E (DOA); ed burrell Subject: Cement Job Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Building a website is a piece of cake. Yahoo! Small Business gives you all the tools to get online._ 6/13/2009 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 16 WELL NAME Rutter and Wilbanks Corporation DATE 1- Jul -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N.R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) WOC AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0730 Install connector,stringer andjet swirl nozzle,and install DESCRIPTION COST ($) injector, prime G pump and pressure up to 5000 psi Mi -Swaco 6,197 0730 -0900 start mixing and batching mix water Schlumberger 58,784 0900 -1030 circ and establish fuild rates Rain for Rent 757 1030 -1500 RIH establish string weight 8000 pounds at 4100FT Hotel &Food 2,000 conducted injectivity tests and clean up well, circ and continue to mix Trailor &Gen 150 up cement and up to 15.6 Supervisor 1,500 - - - - - -- -- -- - 1500-1700 Pre -job safety and discuss job ahead,pump 3barrel spacer Contingency 7,000 16- barrels fiber cement,7barrels water behind, run displacement of 22 barrels into coil , case cement at 100ft per /min at 1.1 barrels per /min to 3200 FT. hold back pressure at 2500psi 1700 -1900 Sqeeze to 3000psiand flush surface equipment.WOC 12 -HR (Notes) Class "G" Antifoam .04 gal /sk,Dispers,LT .050 gal /sk, Mud Products & Mud Van 0 Ga.sblok 1.500 gal /sk, Accelerator .100 gal /sk,bottom hole temp 88deg TOTAL DAY 76,388 - - -- - - -- - - slurry density 40.3% TOTAL CUMULATIVE 922,552 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT J- l i I MUD VAN DAILY I AMOUNT (sx or I) 1 COST COST ($) i i I $0 MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m /hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB i I RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP I CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Sent: Sunday, July 01, 2007 9:29 PM To: Maunder, Thomas E (DOA) Subject: Fwd: Rutter & Wilbank Corp. _Ahtna #1 -19A_ Update Original Message From: Eddie Wrivht <ewriabt @peiinc.com> To: Sent: Sun, 1 Jul 2007 6:22 pm Subject: RE: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Tom Thanks for all your help. I believe the program was a success. We have learned a method to get gas out of the sand. Just wish we could have extended the hole to see the next two sands. We spotted our Schlumberger cement which is a fiber -type Class G mix to protect against gas and water flow. We mixed and pumped 16 bbls to fill casing up to 3200' with cement in place at 4:45 pm today. We tried to squeeze cement out the window with 2500 psig for 30 minutes. I have requested that we go up to 3000 psig for 30 minutes. We have not been able to squeeze any cement down the casing. Our estimated top of cement as we pulled out is 3214'. We will tagged cement under pressure tomorrow morning. If all looks well, we will conduct a negative test by bleeding off pressure and monitor SI pressure. Then perform a positive test to verify cement is in place. I will have the Sundry Notice mailed in the morning through an over night service. The Sundry Notice should be in your offices on Tuesday morning. Eddie From: Sent: Sunday, 11, 2007 11:44 AM To: ewright @peiinc.co , • maunder(aadmin.state.ak.us Cc: mfrancisco@ houston.rr.co , .ckiscott2205©yahoo.com; eburrell@kenai... d.slb.com Subject: Re: Rutter & Wilbank Corp. _ ' • na #1 -19A_ Update Eddie, et al, Unfortunate that you have not been able to get • ch beyo , he window. As noted in our conversations, Commissioner Foerster : given verbal approva • our plan. Doing the positive and negative pressure tests is a good .: . Please plan to submit the sundry .: ication for this work early in work week. Based on our •' ussions, the well status will be suspended. Basel : • our conversations, it would appear that t - • ell has utility for another sidetrack. Good luck wi • e forward work. Call or message with any questions. Tom - • der, PE CC 529 -1645 6/13/2009 • • Page 1 of Maunder, Thomas E (DOA) From: Sent: Sunday, July 01, 2007 8:44 AM To: ewright @peiinc.com; Maunder, Thomas E (DOA) Cc: mfrancisco @houston.rr.com; sickiscott2205 @yahoo.com; eburrell @kenai.oilfield.slb.com Subject: Re: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Eddie, et al, Unfortunate that you have not been able to get much beyond the window. As noted in our conversations, Commissioner Foerster has given verbal approval of your plan. Doing the positive and negative pressure tests is a good plan. Please plan to submit the sundry application for this work early in work week. Based on our discussions, the well status will be suspended. Based on our conversations, it would appear that the well has utility for another sidetrack. Good luck with the forward work. Call or message with any questions. Tom Maunder, PE AOGCC 529 -1645 Original Message From:. • die Wright <ewright @peiinc.com> To: 'Thom. Maunder' <tom @admin.state.ak.us >; Cc: 'Michael . " ick" Francisco' <mfrancisco @houston.rr.co ; 'ed scott' <sickiscott2205@ . .00.com >;'Ed Burrell' < eburrell @ken.'.oilfield.slb.com> Sent: Sat, 30 Jun 2007 :. 6 pm Subject: RE: Rutter & Wilb.- Corp. _ Ahtna #1-19.' _ Update Tom, Based on your phone call, we have been vert . approved to proceed with plugging operations by Commissioner Foerster. We will stop a cement plug from 41 - to 3200', then attem g to reach a squeeze pressure of 2100 psig. If the squeeze pressure is not reaches fter pumping 7.6 bbls, we wi ut the well in. this will leave the top of cement at 3629'. This will be a 500 -ft : ug of cement in the casing above th- indow top at 4129'. We will wait on cement for 24 hrs, and the perform negative and positive tests to veri e cement plug is holding. Thanks again, Eddie Wright From: 'die Wright [mailto:ewright @ peiinc.com] Sen Saturday, June 30- ?nn7 11:13 PM T ; . Thomas Maunder' Cc: 'Michael S. "Mick" Francisco'; 'ed scoff'; 'Ed Burrell' Subject: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Importance: High Tom, We have reached a decision point on the Ahtna #1 -19A. Our decision is to plug the existing coil tubing drilling 6/13/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Sunday, July 01, 2007 6:49 AM To: Maunder, Thomas E (DOA); 'Michael S. "Mick" Francisco' Subject: RE: Ahtna #1 -19A Morning Reports & Update Attachments: RW_Ahtna #1- 19A_6- 30- 07_Rpt 16.xls Tom & Mick Attached is today's morning report. As we discussed last night, we are making arrangement today to plug the sidetrack operations with cement. Eddie Wright Petroleum Engineers, Inc. Office 713 - 479 -7070 Cell 713- 823 -7789 6/13/2009 I • Decca Consulting LTD. DAILY DRILLING REPORT DAY 16 WELL NAME Rutter and Wilbanks Corporation DATE 30- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T-4-N,R-3-W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT (06:00 hrs) day OPERATION 06:00 hrs Wait on da light AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0630 Made a correction to CT depth of 19.8 ft with cut off DESCRIPTION COST ($) - - - - -- - - - -- - - - -- - - - - - -- 0630-0730 Pick up BHA and and connect to well head Supervisor 1,500 0730-1100 RIH. Wash to bottom. Have problems getting thru window. Schlumberger 60,000 Wash down to 4154 ft and start to mill Rain for rent 757 1100 -1430 No progress with mill. Mi -Swaco 4,000 1430 -1530 Pull back into casing and stand buy Contingency 5,000 1530 - 17 Decision was made to stop and plug sidetrack at 1830 hrs. Hotel &Food 2,000 Prepare to plug sidetrack & wellbore with cement. Trailor &Gen 150 Note: Received verbal approval at 1830 hrs from AOGCC to stop operations and prepare to plug sidetrack with cement. Mud Products & Mud Van 0 TOTAL DAY 73,407 TOTAL CUMULATIVE 919,571 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT i i 1 MUD VAN DAILY AMOUNT (sx or IT COST COST ($) . $0 MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m /hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (m BIT MOVE RIG RIG SERVICE � m). CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM RAT HOLE ' MUD RING HALF SPEED PUMP RATE (spm) 1 - DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5 - 125MM CIRCULATE WELD ON BOWL -4 KELLY D RUN CASING i NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Saturday, June 30, 2007 8:26 PM To: Maunder, Thomas E (DOA); Cc: 'Michael S. "Mick" Francisco'; 'ed scott'; 'Ed Burrell' Subject: RE: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Importance: High Tom, Based on your phone call, we have been verbally approved to proceed with plugging operations by Commissioner Foerster. We will stop a cement plug from 4154' to 3200', then attempting to reach a squeeze pressure of 2100 psig. If the squeeze pressure is not reached after pumping 7.6 bbls, we will shut the well in. this will leave the top of cement at 3629'. This will be a 500 -ft plug of cement in the casing above the window top at 4129'. We will wait on cement for 24 hrs, and then perform negative and positive tests to verify the cement plug is holding. Thanks again, Eddie Wright From: Eddie Wright [mailto:ewright @peiinc.com] Sent: Saturday, June 30. 7007 11.1 1 PM To: Thomas Maunder'; Cc: 'Michael S. "Mick" Francisco'; 'ed scott; 'Ed Burrell' Subject: Rutter & Wilbank Corp. _ Ahtna #1 -19A_ Update Importance: High Tom, We have reached a decision point on the Ahtna #1 -19A. Our decision is to plug the existing coil tubing drilling effort and suspend operations. We would like to propose plugging the sidetrack hole because we can no longer get below 4154' and cannot re -enter the sidetrack hole drilled to 4337'. Our plan is to fill the well from 4154' to 3200' with 16 bbls of cement. Then pressure squeeze up to 7.6 bbls of cement out the window or until a squeeze pressure of 2100 psig has reached. If the squeeze pressure is not reached, then we will stop the displacement at 7.6 bbls and leave a 500 ft cement plug in the well from 3629' to 4129' (top of window). Thanks for your assistance, Eddie Wright Petroleum Engineers, Inc. Office 713 - 479 -7070 Cell 713- 823 -7789 6/13/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Saturday, June 30, 2007 5:20 AM To: Maunder, Thomas E (DOA); 'Michael S. "Mick" Francisco' Subject: Ahtna #1 -19A Morning Reports & Update Attachments: RW_Ahtna #1- 19A_6- 29- 07_Rpt 15.xls; RW_Ahtna #1- 19A_6- 28- 07_Rpt 14.xls Tom & Mick Attached are yesterday and today's morning reports. After several efforts, we are still having under gauge hole problems based on efforts with both the new 3 -3/4" and new bi- center bit. Will discuss these operations with Scott & Burrell this morning along with the Hugh Christensen bit representative. We are in the old hole based on how rough either bit has run. We will probably trip in hole with the new 3 -3/4" PCD bit again and just take the time necessary to ream through the tight spot. The first sand came in at 4230'. With our reaming at 4162 ft, we may have 68 ft to ream down. Eddie Wright Petroleum Engineers, Inc. Office 713 - 479 -7070 Cell 713- 823 -7789 6/13/2009 S 9 Decca Consulting LTD. DAILY DRILLING REPORT DAY 15 WELL NAME Rutter and Wilbanks Corporation DATE 29 - Jun - LOCATION (UWI) Athna #1 - 19A Sec.19.T 4 - N.R - - DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) POOH to look at bit AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 06 1130 R IH to window and mill window. Work thru window & tag DESCRIPTION COST ($) at 4154 ft. Ream 4154 to 416 Large cuttings plugged Schlumberger 43,128 choke. Cutting appear to be sandstone. Rain for Rent _ 757 1130 -1230 POOH w /milling assembly and laydown BHA MI -Swaco 4,000 1230 -1330 Cut 110 ft of 2 -3/8" coil to move stress point. Hotel &Food 2,000 -- - - - - -- - - - - -- - - - -- - - - - -- 1330 -1630 Make up bull nose wash nozzle. Contingency 5,000 1630 -1800 RIH to 4159 ft & try to wash out hole with high vis sweeps Trailor &Gen 150 1800 -2130 POOH & make new BHA w /new Bi- center bit Baker Tools 3,500 2130 -2300 RIH to 4158 ft. 2300- 0400 Ream hole to 4162 ft. Reaming operations are rough. 0400 -0600 POOH to take a look at bit and laydown oreintor. Mud Products & Mud Van 1,304 TOTAL DAY 59,839 TOTAL CUMULATIVE 906,003 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal s /qt (cc /30 min) (mm) (ppm) (Pa) cp 11b/100ft ( %) ( %) ( %) (m3) (m3) 9.1 44 8.6 15000 6 15 tr 4 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT DOU -VIS DEFOAM -X I I 1 1 i MUD VAN DAILY AMOUNT (sx or l) 6 2 COST L COST($) 1014 290 r $1,304 MUD COMPANY IMI Swaco I MUD TYPE [Polymer I CUMULATIVE COST $19,836 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE Depth DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inch inches Ft (m) (m) (m /hr) (daN) 3 7010798 370 bicenter 6 x 25 4337 0 3000 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi (m3 /min) ft/min 1 Gardener /den 3x3.75 3039 164.7 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) COI[ conn i 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK - OFF GRADIENT (kPalm) HYP DISION 1.53 I SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) CIRC SUB 1.15 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) WT BAR 3.14 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTOR 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP r BI- CENTER I 0.78 CEMENT TEST BOP 1 TOTAL 25.18 TOTAL 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 70 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1 - 907 - 398 - 7272 SUPERVISOR Ed Scott TELEPHONE /FAX# 1 - 907 - 320 - 0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1 - 713 - 823 - 7789 • 0 Decca Consulting LTD. DAILY DRILLING REPORT DAY 14 WELL NAME Rutter and Wilbanks Corporation DATE 28- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4341.0 AFE NUMBER 0 PROGRESS 4.0 -- - - -- - - -- - - -- - - CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Wait on bit AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0730 Drill F/4337 -4341 Ft DESCRIPTION COST ($) 0730 -1500 POOH to inspect motor and bit. Bit had crack in body and Schlumberger 43,128 broke when we attempt to take off the motor. Supervisor 1,500 15 0 -1630 Test all valves on choke manifold. Test 250 psi low & 5000 Hotels &Food 2,000 high. Tested good with no problems. Baker Tools 3,500 1630 -1830 RIH with new bit and new directional motor. Tag up at Rain for Rent 757 at whipstock trying to orient bit & motor thru window. Contingency 6,000 1830 -2030 Change orientation Trailor&Gen 150 2030 -2300 RIH. Attempt to get thru window into open hole MI -swaco 4,000 2300-2400 Still having problems at window or just into open hole. POOH No marks or damage to 3 -3/4" bit. _ 2400 -0400 Remove new motor & try old motor. Bit stopped at 4154ft. May have window or hole problem. POOH and check bit ODs. Mud Products & Mud Van 328 0400 -0600 POOH. Still having problems at window or with hole. TOTAL DAY 61,363 TOTAL CUMULATIVE 846,164 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal s /qt (cc /30 min) (mm) mg /I (Pa) cp lb/100ft2 ( %) ( %) ( %) (m3) (m3) 9.2 43 8.6 16000 6 14 4 - 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT Dou -vis 1 i 1 MUD VAN DAILY AMOUNT (sx or I) 2 1 I : i COST COST ($) 328 1 i $328 MUD COMPANY 'MI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $18,532 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM lnnches (mm) (m) (m) (m) (m /hr) (daN) 1 10022786 418 PDC 6 x 25 4341 0 1200 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi bbl /min (m /min) 1 Gardener /Den 3x3.75 3029 2.4 164.7 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) COIL CONN 0.95 I MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) HYD DISC 1.53 SAFETY MEET. TRIP _ MAXIMUM SHUT -IN PRESSURE (kPa) CIRC SUB 1.15 I RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) WT BAR 3.14 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTOR 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP BIT 0.52 CEMENT TEST BOP TOTAL 24.92 TOTAL j 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 70 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7789 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 Pagel of Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Thursday, June 28, 2007 3:12 PM To: Eddie Wright Cc: 'Ed Burrell'; 'Michael S. "Mick" Francisco'; 'ed scott'; Art Saltmarsh Subject: Re: Ahtna #1 -19A Update 6 -27 -07 Eddie, et al, It appears there is some encouragement. Drilling beyond the permitted depth is allowed provided the depth increase is less than 500'. It would appear that the planned depth increase is no where near the limit. Maintain constant bottomhole pressure is important. Managing volume in versus volume out is a valid practice to reduce any influx, however the variability of the back pressure verifies the range of mud weights that you detail. Having the mud products available to mix fluid to kill the well is appropriate. With regard to the BOP test, for an exploration operation the interval limit is 7 days unless expressly authorized to exceed. If your prediction of 24 -48 hours is valid, then it is possible that a BOP test may become a moot point. One item that you will need to address is obtaining a survey of the new wellbore sec Call or message with any questions. Tom Maunder, PE AOGCC - -- Original Message From: Eddie Wright <ewright @peiinc.com> Date: -•nesday, June 27, 2007 5:02 pm Subject: na #1 -19A Update 6 -27 -07 To: 'Thomas nder' <tommaunder @admin.state.ak. _> Cc: 'Ed Burrell < eburrell @kenai.oilfield.slb.co >, "'Michael S. \ "Mick \" Francisco " <mfrancisco @houston.rr.co' >, 'ed scott' <sickiscott2205 @yahoo. om> Tom, Per our conversation tod. , we are requ- ting permission from the AOGCC to continue drilling to -600? TVD. Our permit •ows 4300 ft. This additionalfootage :11 allow us to look at the ddle zone at 4386- 4404 ft TVD and t'e bottom zone at '474 -4530 ft TVD. Our expe iment to see gas from the first zone of interest at 423.- 4250? ' P has -en successful. We observed a slow down in penetration in th- shale -.ove the zone and then a drilling break from 4230 -4236? TVD. We shut down drilling operations and monitored the well. We observed an 6/13/2009 • Page 1 of 3 • Maunder, Thomas E (DOA) From: Art Saltmarsh [ art _saltmarsh @admin.state.ak.us] Sent: Thursday, June 28, 2007 2:59 PM To: Thomas Maunder Subject: Re: [Fwd: Ahtna #1 -19A Update 6- 27 -07] Attachments: art_saltmarsh.vcf Tom, I have reviewed the logs from the original hole and sidetrack for the Ahtna 1 -19 well. The operator is proposing to drill several hundred feet further than the PTD request. Stratigraphically, they will still be in the same sand interval as they are now. Other than the normal bottom hole conditions they encountered on the original drill, there are no obvious geologic problems with continuing to drill beyond their original request, to a maximum of 499' from the original wellbore. Additionally, they should supply a survey of the wellbore on completion of this operation. Art Thomas Maunder wrote: Art, Here is the message I got. Tom Original Message Subject:Ahtna #1 -19A Update 6 -27 -07 Date:Wed, 27 Jun 2007 19:21:31 -0500 From:Eddie Wright <ewright@peiinc.com> To:'Thomas Maunder' <tom maunder@ admin.state.ak.us> CC:'Ed Burrell' < eburrelk@kenai.oilfield.slb.com >, "'Michael S. \ "Mick \" Francisco" <mfrancisco(houston.rr.com >, 'ed scott' <sickiscott220*,yahoo.corn> Tom, Per our conversation today, we are requesting permission from the AOGCC to continue drilling to 4600' TVD. Our permit shows 4300 ft. This additional footage will allow us to look at the middle zone at 4386 -4404 ft TVD and the bottom zone at 4474 -4530 ft TVD. Our experiment to see gas from the first zone of interest at 4230 -4250' TVD has been successful. We observed a slow down in penetration in the shale above the zone and then a drilling break from 4230 -4236' TVD. We shut down drilling operations and monitored the well. We observed an intermittent gas /liquid flow into our open top tank with 2058 psig on a 1 /2 -inch adjustable choke. The flow was approximately 90% drilling /formation fluids and 10% gas. We were drilling ahead at 11:30 hrs with excellent hole conditions at 4254 ft. We have increased our back pressure during drilling from 1000 to 2000 psig with a 6/13/2009 Page 1 of 2 • • r Thomas E (DOA) , om ( ) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent; Thursday, June.28, 21107 12:12 PM . To: Eddie Wright Cc: 'ed scott' Subject: Re: Choke Repairs Yes, retesting any breaks /repairs is important. Eddie Wright wrote, On 6/28/2007 12:09 PM: Tom, We have the extra time to inspect the manifold and pump while we are changing out the mud motor and bit. I want to be sure the equipment is in good shape for the remainder of our drilling. I will remind Ed Scott to retest the manifold when the inspection is complete. Eddie From: Thomas Maunder [mailto :tom maunder @adm n.state.ak.us] Sent: Thursday, June 28, 2007 2:32 PM To: Eddie Wright Cc: 'ed scott'; eddie_wright25@hotmail.com; 'barry'; Art Saltmarsh Subject: Re: Gas to surface Thanks for the information Eddie. Is the choke wear more than might have been expected? It appears that there are spare parts available to make repairs. Tom Maunder, PE AOGCC Eddie Wright wrote, On 6/28/2007 11:27 AM: Tom We are still controlling the well to keep the bottom hole pressure constant and to have equal flow in /out of the hole. Now that we are below and flowing pass the zone at 4230 - 4250', we may observe some feed in. Early this morning (0350 hrs), we had some gas come up as a bubble. As a precaution, we stopped drilling at 4328' and continued circulating. We may have cut a thin sand which shows up on the mud log from the original hole. The mud log shows a spike in the drill rate and an increase in the sand percentage for the next 20 ft. No additional gas was observed and we continued to drill ahead. Today, we have seen the penetration slow down to 3 -5 ft per hour. So we had decided to stop drilling ahead at a depth of 4341'. At 1100 hrs, we were POOH to inspect the bi- center bit and drill motor. We will probably put in a new bit and motor. While we are out, we will inspect and repair our choke manifold and pump. We should be back on bottom and drilling again by 1900 hrs. Our next zone of interest is 4386 - 4404'. If you have additional questions, please let me know. 6/12/2009 Page 2 of 2 40 Eddie From: Thomas Maunder [maiIto tom maunder @admin.state.alcus] Sent: Thursday, June 28, 2007 9:57 AM To: ed scott Cc: eddiewright25 @hotmail.com; Eddie Wright; barry; mfrancisco @houston.rr.com; ed burrell Subject: Re: Gas to surface Gentlemen, While it is encouraging that there is gas in the strata you are drilling. As you drill ahead, gas should be evident as new cuttings are circulated up. However, the combination of choke pressure and fluid weight should balance the bottom hole pressure. Drilling with the well flowing is not part of the approved program. If I have misunderstood Ed's comments, please advise. Tom Maunder, PE AOGCC ed scott wrote, On 6/28/2007 6:45 AM: We are having good gas to surface and getting some good spikes. Hole conditions are in good shape and we are having no problems in the hole. Don't be flakey. Get Yahoo! Mail for M_ obile and always stay connected to friends. 6/12/2009 • 0 Decca Consulting LTD. DAILY DRILLING REPORT DAY 13 WELL NAME Rutter and Wilbanks Corporation DATE 27- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19.T- 4- N,R -3 -W DEPTH (06:00 hrs) 4337.0 AFE NUMBER 0 PROGRESS 115.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Drill ahead AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0630 Repair choke on manifold DESCRIPTION COST ($) 0630 -0930 Drill ahead F/4222 -4251 FT Supervisor 1,500 0930 -1100 Repair computor on rig crashed Schlumberger 43,128 1100 -1200 Drill ahead F/4251- 4254FT Rain for rent 757 1200 -1900 Stop drill pull up into casing and install new choke parts Mi -Swaco 4,000 and Repair wash out paking in mud pump. Trailor &Gen 150 1900 -0600 Control Drill F/4254- T/4337Ft Hotels &Food 2,000 Having Good gas to surface and it is building as we drill deeper Contingency 5,000 Good gas spikes last night. Baker tools 1,500 Mud Products & Mud Van 1,690 TOTAL DAY 59,725 TOTAL CUMULATIVE 784,801 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 9.2 45 8.5 15000 6 15 4.5 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT DUO -VIS I 1 1 ! MUD VAN DAILY AMOUNT (sx or I) 10 COST - --- - -- - $1,690 COST ($) 1690 1 i MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $18,204 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inches inches F/t (m) (m) (m /hr) (daN) 1 4 PDC 6 x 25 4154 0 5000 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) 1 Gardener /Den 3x3.75 3029 2.4 164.7 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). coil cone 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) bpv 1.57 RIG UP SURVEY LEAK -OFF GRADIENT (kPa/m) hyd disc 1.53 _ SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 3/4 circ sub 1.15 I RAT HOLE MUD RING _ . — HALF SPEED PUMP RATE (spm) wt bar 3.14 DRILL I W.O.C. HALF SPEED PUMP PRESSURE (kPa) oreintor 4.86 CIRCULATE WELD ON BOWL motor 11.2 RUN CASING NIPPLE UP BOP mill 0.83 CEMENT TEST BOP TOTAL I 25.23 TOTAL 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 70 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Wednesday, June 27, 2007 4:22 PM To: 'Thomas Maunder' Cc: 'Ed Burrell'; 'Michael S. "Mick" Francisco'; 'ed scott' Subject: Ahtna #1 -19A Update 6 -27 -07 Attachments: Optional Side Track to 4600 ft TVD.pdf; Optional Completion to 4600 ft TVD.pdf Tom, Per our conversation today, we are requesting permission from the AOGCC to continue drilling to 4600' TVD. Our permit shows 4300 ft. This additional footage will allow us to look at the middle zone at 4386 -4404 ft TVD and the bottom zone at 4474 -4530 ft TVD. Our experiment to see gas from the first zone of interest at 4230 -4250' TVD has been successful. We observed a slow down in penetration in the shale above the zone and then a drilling break from 4230 -4236' TVD. We shut down drilling operations and monitored the well. We observed an intermittent gas /liquid flow into our open top tank with 2058 psig on a' /2 -inch adjustable choke. The flow was approximately 90% drilling /formation fluids and 10% gas. We were drilling ahead at 11:30 hrs with excellent hole conditions at 4254 ft. We have increased our back pressure during drilling from 1000 to 2000 psig with a pump pressure of 3200 psig. We are still maintaining a pump rate of 1.0 -1.5 bpm going into the hole and adjusting the choke pressure to keep the same amount of fluid coming out. The inlet mud weight has ranged from 8.8 to 15.5 ppg. By adjusting the choke manifold back pressure, we are maintaining a constant bottom hole pressure. We are have sufficient drilling fluid products on location to mix & pump 70 -80 bbls of 19.5 ppg mud in the even of a well control issue. Our last BOP Test was completed on Sunday, June 24. We plan to complete our drilling operations in the next 24 -48 hour. If the operations continue pass Sunday, we will schedule a BOP Test that day or request a waiver to the next day when tools will be out of the hole. This additional footage will only be reached if hole conditions continue to be good, the gas influx continues to be manageable with back pressure, and no extensive equipment downtime is encountered. I have attached an Optional Side Track schematic and an Optional Completion schematic. The Optional Side Track schematic shows the borehole going to 4600 ft TVD. The Optional Completion Schematic shows the 2 -3/8" coil tubing cemented from 3200' inside the 5" casing down to the end of the side track hole at 4600 ft TVD. I will submit a revised completion procedure after cementing information is available from Schlumberger. Please give me a call or send an email I if you have any questions, recommendations, or 6/13/2009 • • RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1-19 API No.: 50- 099 - 50005 -00 Proposed Side Track Wellbore Schematic RKB 2037.0 18.3 6/27/07 GL 2018.7 Depth Casing /Cement Completion: g 2 -7/8" 6.5# L -80 EUE Tubing , f ) 78' BGL 13 -3/8" 68# L -80 Conductor Shoe Squeezed with 18.3 bbls 12-1/4" ikl 1,226 9 -5/8" 40# L -80 BTC Surface AO 04- 20 bbls Permaforst & Class G co 8 -1/2" 1,915 7" 26# L -80 BTC Intermediate 66 bbls Class G to surface 3,200 Top of cement (CBL) Top of Whip Stock at 4129' ak OM K . ±4,140 Top of Window Whip Stock Anchor at ±4,153' ±4,149 Bottom of Window TOC - placed w/ dump bailer 4,170 Mechanical Plug 4,220 k i Evaluate zones: E -Line Perfs: 4232 4250 ±4,230- 4,250' TVD Drill Perf Tool Channels: 4382 ±4,386- 4,404' TVD 4387 ±4,474- 4,530' TVD E -Line Perfs: 4474 4490 4506 4530 Top of cement 4,536 (placed with dump bailer) , End of Side track at ±4,600' TVD 4,577 Top of 3 -1/2" Liner , .�� bk. 4,635 Schlumberger Posi -Set Plug 4,639 5" 17.8# L -80 STL Intermediate Perforations: 4674 4680 = 53 bbls Class G 4922 4940 4923 4929 = 4932 4938 5010 5020 =_ 5076 5084 -3a 5,099 PBTD < 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 , 7 n;,iz,,, • • RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19 API No.: 50- 099 - 50005 -00 Proposed Optional Completion Wellbore Schematic RKB 2037.0 18.3 6/27/07 GL 2018.7 Depth Casing /Cement Completion: ,x : r; 2 -7/8" 6.5# L -80 EUE Tubing ` 78' BGL 13 -3/8" 68# L -80 Conductor ' Shoe Squeezed with 18.3 bbls 12-1/4" s 1,226 9 -5/8" 40# L -80 BTC Surface f 20 bbls Permaforst & Class G 8-1/2" 1 1,915 7" 26# L -80 BTC Intermediate 66 bbls Class G to surface 3,200 Top of cement (CBL) W. �y. 1 3,200 Top of cement in 5" casing (Cement top may be displaced to 3,500' to squeeze cement and Top of Whip Stock at 4129' 4r4 control water flow.) �~ 1 1 , ±4,140 Top of Window I Whip Stock Anchor at ±4,153' L 1 ±4,149 Bottom of Window r 1N TOC - placed w/ dump bailer 4,170 Mechanical Plug 4,220 Evaluate zones: E -Line Perfs: 4232 4250 � ±4,230- 4,250' TVD 1,11 Drill Perf Tool Channels: 4382 k ±4,386- 4,404' TVD 4387 1 1 1 ±4,474- 4,530' TVD t E -Line Perfs: 4474 4490 4506 4530 ly; Top of cement 4,536 End of Side track at ±4,600' TVD (placed with dump bailer) . 0 v � 4,577 Top of 3 -1/2" Liner l�� fi' 4,635 Schlumberger Posi -Set Plug 4,639 5" 17.8# L -80 STL Intermediate Perforations: 4674 4680 53 bbls Class G 4922 4940 4923 4929 4932 4938 5010 5020 5076 5084 5,099 PBTD . ,V; 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 "i ` • • 7 "OD 6.151 37.8348 0.036754 bbls /ft 7x5 annullus 3200 300 0.011502 3.45 bbls displaced cmt 3500 4129 5x2 -3/8 annullus 17.48076 5.640625 11.84014 0.011502 929 10.7 bbls Open holex2 -3/8 annu 16 5.640625 10.35938 0.010064 471 4.7 bbls 4129 15.4 4600 5" OD 25 0.024286 bbls /ft 4.181 17.48076 0.016982 bbls /ft 62 • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Wednesday, June 27, 2007 6:26 AM To: eddiewright25 @hotmail.com; Eddie Wright; Barry Ahearn; mfrancisco @houston.rr.com; thomas; ed burrell Subject: report for day 12 Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Hi Mick, MI -swaco charges per day for equipment on location are 4000 for men 3600 so the day total before the mud bill is 7600 dollars. You snooze, you lose. Get messages A SAP with AutoCCh eck in the all -new Yahoo! Mail Beta. 6/13/2009 • • Decca Consulting LTD. DAILY DRILLING REPORT DAY 12 WELL NAME Rutter and Wilbanks Corporation DATE 26 - Jun - LOCATION (UWI) Athna #1 - 19A Sec.19,T 4 - N,R - - DEPTH (06:00 hrs) 4222.0 AFE NUMBER 0 PROGRESS 68.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Change out choke on manifold AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0630 Preform leak off test on formation started at 1 /4bbl at a time DESCRIPTION COST ($) then we pumped at 1 -bbl /per min stayed the at the same at 2000 Hotel& food 2,000 wellhead pressure we just pumped it into the formation. Schlumberger 44,000 0630 -1130 POOH w /milling assembly and laydown tools (mill still in gage) rain for rent 757 Pick up drilling BHA . Install Ptlubricator Supervisor 1,500 1130 -1300 RIH w /new BHA to 4154FT ,flag pipe make depth correction Mi -swaco 7,600 1300 -1500 Drill F/4154- T14175FT Trailor and Gen 150 1500 -1600 Repair washed out choke on manifold Baker tools 3,500 1600 -1930 Drill F/4175- 4183FT incountered drilling break small influx Contingency 5,000 of gas to surface drill to 4210FT —._ 1930 -0600 Start to control drill F4210- 4222Ft and control water flow to surface, pressure 3029psi,wellhead 1962psi, we are having small amounts of gas flow spikes to surface. Mud Products & Mud Van 0 TOTAL DAY 64,507 TOTAL CUMULATIVE 725,076 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES ppg (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 9.5 42 9 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT i L, MUD VAN DAILY AMOUNT (sx or I) ) ._ _ COST COST ($) I I I i [ I $0 MUD COMPANY IMI Swaco - I MUD TYPE (Polymer I CUMULATIVE COST $16,514 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inches (mm) Ft (m) Ft (m /hr) (daN) 1 4 PDC 6 x 25 4154 68 0 5000 125 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) 1 Gardener /Den 3x3.75 3029 164.7 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. _ TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM - — RAT HOLE — MUD RING HALF SPEED PUMP RATE (spm) 1 -XO I DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 65 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # ! - 907 - 398 - 7272 SUPERVISOR Ed Scott TELEPHONE /FAX# 1 - 907 - 320 - 0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Tuesday, June 26, 2007 5:23 AM To: eddiewright25 @hotmail.com; Eddie Wright; Barry Ahearn; thomas; mfrancisco @houston.rr.com; ed burrell Subject: window cut Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Sucker -punch pam with award - winning protection. Try the free Yahoo! Mail Beta. 6/13/2009 0 • Decca Consulting LTD. DAILY DRILLING REPORT DAY 11 WELL NAME Rutter and Wilbanks Corporation DATE 25- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4154.0 AFE NUMBER 0 PROGRESS 14.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Perform leak off test AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -1200 Shut in well and read and record pressures shut in at start DESCRIPTION COST ($) 600psi finshed at 1200psi.Mix surface tanks up to 15.6 w /barite. Supervisor 5,500 1200 -1400 RIH at 100FT per /min to 4111 Ft circ at 1.9 barrels per /min Schlumberger 42,265 salt water coming back at a weight of 8.5ppg. Displaceed 140 barrels of Rain for rent 757 15.6 mud before we got returns back.Dropped down to 14 ppg and Contingency 10,000 returns came back. Loses about 60 barrels of weighted mud Hotel &food 2,000 1400 -1800 Build volume in mud tank and tranfer old mud from holding Baker tools _ 4,000 tank , hock up tranfer tank. Trailor &Gen 150 1800 -2230 RIH to 4139.2 start to cut window, establish new pump MI -SWACO 9,793 pressure of 2662 on pump and 1050 on well head at 2.4 barrels pre /min to make sure that we do not build volume. 2230 -0300 Drill open hole from 4144FT- 4154FT wellhead Press 1 psi,pump 2636psi Mud Products & Mud Van 7,674 0300 -0500 POOH F/4154 -TO Ft TOTAL DAY 82,139 0500 -0600 Perform leak off test on formation. TOTAL CUMULATIVE 660,569 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal s /qt (cc /30 min) (mm) (ppm) (Pa) cp lb /100ft ( %) ( %) ( %) barrel barrel 11 42 9 _ 9 8 14 60 60 MUD PRODUCTS USED (Past 24 hrs) PRODUCT barite soda -ash I DUA -VIS ASPHASOL RESINEX I POLY -SUPR I MUD VAN DAILY AMOUNT ( I) sx or I 654 2 1 5 2 2 4 I COST - - - - - -- - -- — -- _ � -- — -- COST(8) 5690 50 845 175 214 j 700 $7,674 MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $16,514 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inches inches (m) (m) (m) (m /hr) (daN) 1 7116071 4 window 3 x 0 4139 -4139 0 I 12 400 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) psi B /MIN FT /MIN 1 Gardener /Den 3.75x5 2560 2.4 164.77 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) 2 3/8x2 3/8 ctc I 0.95 MOVE RIG RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK - OFF GRADIENT(kPa/m) WGT BAR WFT 3.98 SAFETY MEET. TRIP MAXIMUM SHUT-IN PRESSURE (kPa) HYD DISC 7/8B 1.53 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) DAUL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTER 30 4.86 j CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING I NIPPLE UP BOP HCC -BI -BIT 0.82 CEMENT i TEST BOP TOTAL! 26.06 TOTAL 0.00 LEASE /ROAD CONDITION Good WEATHER/TEMPERATURE ( °C) 65 CONTRACTOR TOOLPUSH Ed burrell TELEPHONE /FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • Page 1 of 2 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Monday, June 25, 2007 3:57 PM To: Eddie Wright Cc: mfrancisco @houston.rr.com; 'ed scott' Subject: Re: Ahtna #1 -19 Eddie, et al, Thanks much for the update. Weighting up to reduce the necessary back pressure is appropriate. Truly drilling underbalanced was not in you plans or in our approval. Keep us informed. Tom Maunder, PE AOGCC cell: 529 -1645 Eddie Wright wrote, On 6/25/2007 3:50 PM: Tom, Thanks for your time this afternoon. As we discussed, we are still trying to get the window cut from approximately 4140 -4148' ELM. We have seen the pressure come up above 2100 psig with 8.6 ppg freshwater mud in the hole. We stopped milling and pulled up to allow the pressure to stabilize. Then we started to increase our mud weight to 15.6 ppm with the thought that a 600 psig choke manifold pressure would be sufficient. We are back on bottom and trying to mill ahead. The return fluid has been cut by the salt water flow from 15.5 to 13.0 ppg. This afternoon, we have recovered some 8.5 ppg saltwater with a1200 psig back pressure on the choke manifold. This indicates a 14.1 ppg EMW. We will continue to cut the window which should be about 5 -6 hours of milling tonight. Then POOH and look at the mill and string reamer to gauge window conditions. We hope to start back into the hole with the directional drilling assembly tomorrow. We did not expect the pressure and saltwater from the shale section as we started the window. We were expecting some pressure and had no problems with our containment of the pressures or fluids. With the salt water showing up early, we are reviewing our completion plan. This plan may include an open hole packer completion or cementing the 2 -3/8" coil tubing in the well. We are looking into options to help evaluate the sand, gas content and isolation. We have discussed logging and perforation options with Schlumberger Wireline. We are looking into packers with Baker Oil Tools. Safety and well control issues are at the top of our list. Our onsite storage capacity of 2140 bbls includes three 500 bbl frac tanks, one 500 bbl open top tank, 40 bbl mud mixing tank, and 100 bbl mud storage tank. We have been using a 200 bbl mud system with a hole capacity of 70 bbls, coil bundle capacity of 26 bbls, and 100 bbls of surface mud. I will give you another update tomorrow as we get the window milled tonight and additional information about setting a 2 -3/8" coil tubing string to approximately 4280 -4300 ft, open hole packers, cementing, logging, and perforating methods. Respectfully, Eddie Wright Petroleum Engineers, Inc. 6/13/2009 • Page 1 of 1 Maunder, Thomas E (DOA) From: Thomas Maunder [ tom__maunder @admin.state.ak.us] Sent: Monday, June 25, 2007 7:36 AM To: ed scott Cc: eddiewright25 @hotmail.com; Barry Ahearn; mfrancisco @houston.rr.com; ed burrell Subject: Re: weight up mud Morning Gentlemen, Interesting. Safe to say, I think you have drilled out of the casing. Pressure looks similar to what was present prior to plugging the original penetration. Weighting up is prudent. Was any notification of the flow event made to the NS Inspector, Jim Regg or myself. I did get a call late night /early am on my cell phone that I did not catch. 20 AAC 25.036 (g) requires notice within 24 hours of any use of BOP to prevent the flow of fluids from the well. Ed, I did get your voice message of Saturday regarding the successful BOP test. You also asked if I could send a copy of the IADC sheet we use. I do not have a copy of any IADC sheet. On the rigs I have been on, that is usually provided by the contractor. I would think the Schlumberger through their NS operations might be able to get such a "form ". I also acknowledge getting the BOP test form. I need to check a couple of entries and then I will get a message back to you. Much more complete this time. Tom Maunder, PE AOGCC ed scott wrote, On 6/25/2007 2:48 AM: Take the Internet to Go: Yahoo!Go puts the Internet in your pocket: mail, news, photos & more. 6/13/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Monday, June 25, 2007 2:48 AM To: eddiewright25 @hotmail.com; eddiewright25 @hotmail.com; Barry Ahearn; thomas; mfrancisco @houston.rr.com; ed burrell Subject: weight up mud Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Take the Internet to Go: Yahoo!Go puts the Internet in your pocket: mail, news, photos & more. 6/13/2009 I • Decca Cosulting LTD. DAILY DRILLING REPORT DAY 10 WELL NAME Rutter and Wilbanks Corporation DATE 24- Jun -07 i LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N.R -3 -W DEPTH (06:00 hrs) 4140.0 AFE NUMBER 0 PROGRESS 4.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Weight up mud system AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0900 -1000 Make up BHA DESCRIPTION COST ($) 1000 -1100 Displace coil tube to mud 9.2 barrels Supervisor 1,500 1100-1130 RIH @ 100ft/hr w /milling assembly Schlumberger 118,798 w /with no pump 4700pounds w /pump on 5300pounds _ Mi swaco 12,000 1130 -1230 Tag @ 4126FT made depth correction to 4136FT Trailor &gen 1,050 - - - - -- - - - -- 1230-1630 Start pump record pressures @ 2.4 BPM,923psi on pump Contingency 6,000 73psi on wellhead,begin milling @ 4136FT,drill to 4140Ft Baker Tools 71,400 1630 -1800 Encounter pit gain, stopped pump,pull up and monitored Hotels &food 1,500 well flow back to surface 1- barrel per minute for 10 minutes,shut well in RAIN for rent 5,299 30 minutes pressure build up to 2146psi, clhorides at 16,000 1800 -2000 Decision with town and Bill, decision was made to weight up 2000 -0600 mix barite and build up weight to 15.6 ppg mud, pump and displace hole to hold back salt water influx. Pump at reduced rate .8 Mud Products & Mud Van 7,146 - -- ---- - - - - -- - -- - -- -- barrels per /min, shut well in w /600 psi on choke read and record shut in TOTAL DAY 224,693 pressures.Mix up surface tank to 15.6 ppg. TOTAL CUMULATIVE 578,430 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES LB /GAL s /qt (cc /30 min) 1/32" (ppm) (Pa) cp lb /100ft ( %) ( %) ( %) (m3) (m3) 15.6 52 2/ 9 16000 18 23 41 0/59 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT m -I bar I DOU -VIS I I ■ L I MUD VAN DAILY AMOUNT (sx or I) 660 8 : F COST COST($) 5794 1352 1 $7,146 MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $8,840 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM inches Inches FT Ft Ft BARREL (daN) 1 7116071 4 window mill 3 x I 0 4136 4140 4 2 1200 400 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi barrels FT /MIN 1 Gardener /Den 3.75x5 1230 2.4 164.77 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) 2 3/8x2 3/8 ctc 0.95 MOVE RIG i RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK - OFF GRADIENT(kPa/m) WGT BAR WFT 3.98 SAFETY MEET. TRIP — MAXIMUM SHUT -IN PRESSURE (kPa) HYD DISC 7/8B ; 1.53 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) DAUL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREINTNER 30 4.86 CIRCULATE WELD ON BOWL MOTOR 11.2 RUN CASING NIPPLE UP BOP ■ HCC- BI - -BIT I 0.82 CEMENT TEST BOP TOTAL j 26.06 TOTAL 0.00 LEASE /ROAD CONDITION GOOD WEATHER/TEMPERATURE ( °C) 65 CONTRACTOR TOOLPUSH Ed Burrell TELEPHONE /FAX # 1- 907 - 398 -7272 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • 4110 Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Sunday, June 24, 2007 12:27 PM To: thomas Subject: Bop test Attachments: BOP test 06- 23- 07.xls Hi torn take a look at this test and let me no if it is okay test went good no problems at all.Thanks Ed. Be a better Heartthrob. Get better relationship answers from someone who knows. Yahoo! Answers - Check it out. 6/13/2009 • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: lim regq(a�admin.state.ak.us aogcc_prudhoe_bay@admin.state.ak.us bob_fleckenstein @admin.state.ak.us Contractor: Schlumberger Rig No.: DATE: 23- Jun -07 Rig Rep.: George Harris Rig Phone: 398 -2882 Rig Fax: Operator: Rutter & Wilbanks Op. Phone: 320 -0504 Op. Fax: Rep.: Ed Scott E -Mail sickiscott2205yahoo.com Well Name: Ahtna #1 -19A PTD # 175 -005 Meridian: Location: Section: Township: Range: Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Other: Test Pressure: Rams: 250/5000 Annular: Valves: 250/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly Coil Housekeeping: P Drl. Rig P Lower Kelly Coil PTD On Location N/A Hazard Sec. P Ball Type Coil Standing Order Posted P Inside BOP Coil BOP STACK: Quantity Size /Type P/F MUD SYSTEM: Visual Alarm Stripper 1 2.375 P Trip Tank NA NA Annular Preventer Pit Level Indicators NA NA #1 Rams 1 Blind /Shear P Flow Indicator NA NA #2 Rams 1 Pipe /Slips P Meth Gas Detector NA NA #3 Rams 1 Blind /Shear P H2S Gas Detector NA NA #4 Rams 1 Pipe /Slips P #5 Rams Quantity P/F Choke Ln. Valves 2 2" Plug P Inside Reel valves 1 P HCR Valves Kill Line Valves 2 1" plug P ACCUMULATOR SYSTEM: Check Valve 1 DFCV P Time /Pressure P/F System Pressure 2500 P CHOKE MANIFOLD: Pressure After Closure 2000 P Quantity P/F 200 psi Attained 31 P No. Valves 3 P Full Pressure Attained 55 P Manual Chokes 1 Blind Switch Covers: All stations P Hydraulic Chokes NA NA Nitgn. Bottles (avg): 4(a 1100psi P Test Results Number of Failures: 0 Test Time: 3 Hours: Components tested 18 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: jim regqaadmin.state.ak.us Remarks: Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES X NO c - Oper. /Rig Waived By Jim Regg c - Database Date 6/23/07 Time c - Trip Rpt File Witness Ed Scott c - Inspector Test start 1/0 Finish 11:41 pm Coil Tubing BFL 05/29/03 BOP test 06- 23- 07.xls • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Sunday, June 24, 2007 12:00 PM To: eddiewright25 @hotmail.com; eddiewright25 @hotmail.com; Barry Ahearn; thomas; mfrancisco @houston.rr.com; ed burrell Subject: Rig up Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Looking for earth - friendly autos? Browse Top Cars by "Green Rating" at Yahoo! Autos' Green Center. 6/13/2009 • • Decca Cosulting LTD. DAILY DRILLING REPORT DAY 9 WELL NAME Rutter and Wilbanks Corporation DATE 23- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19.T- 4- N.R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumber er PROJECTED T.D. 4280FT OPERATION (06:00 hrs) wait on day lights AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0300 Coil tubing on location DESCRIPTION COST ($) 0300-0600 Remove and install new coil tubing reel 0600 -1800 Rig up coil in stab into injector reel 1800 -2400 test connectors and test BOP,s all valves,blind rams, pipe ram, accumutalor, low test 250psi,high test 5000psi 2400 -0100 clean up wait on day lights we only have one crew so there will be no night shit. Ed burrell said that they will have one for tommorow night. Note= I will get with men and get accumulated cost for down time and pull on tommorows report. - Mud Products & Mud Van 0 TOTAL DAY 0 TOTAL CUMULATIVE 353,737 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT i 1 i ' MUD VAN DAILY AMOUNT (sx or I) L COST -- _ -- _ ._'.- --- — - - $0 COST ($) : MUD COMPANY IMI Swaco I MUD TYPE (Polymer I CUMULATIVE COST $1,694 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m /hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) BIT I MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5- 125MM I CIRCULATE WELD ON BOWL KELLY D 1 RUN CASING NIPPLE UP BOP CEMENT TEST BOP TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FAX # 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Sunday, June 24, 2007 8:22 AM To: eddiewright25 @hotmail.com; eddiewright25 @hotmail.com; thomas; mfrancisco @houston.rr.com; barry; ed burrell Subject: Rig up Hi Gentlmen, We have assembly the Rig and the boys finished up around 1.30 am we will should start cuttin a window around noon today. But Ed has informed me that he only have one crew and he will not have a second crew for two days so it may be slow going until we have a night crew. I will keep you up dated on drilling reports today and I will get new phone card so you can call me on 1- 907 - 320 -0504 if any problems thanks Ed Scott. Looking for a deal? Find great prices on flights and hotels with Yahoo! FareChase. 6/13/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Friday, June 22, 2007 3:56 PM To: Eddie Wright Cc: 'ed scott' Subject: Re: First BOP Test Eddie and Ed, Sorry I haven't gotten back sooner. I am not sure that I really have specific requirements that I can send you other than the regulations. Coil drilling BOP requirements are at 20 AAC 25.036. Requirements for coil well service BOP are at 20 AAC 25.286. The regulations are on the web site www.ao_cc.alaska.gov and are at the bottom of the middle column. So far as testing is concerned. A low pressure test and a high pressure test is required on all rams, annular(s) and valves. Since yours is an exploratory operation, the testing frequency is 7 days unless "overtime" is granted by the Commission. The latest version that Eddie sent in looks fine for content. I am curious about the 1000 psi bottles. Is that the pressure that Schlumberger normally runs? With regard to your lines and choke manifold, are hammer unions employed? If you, you should apply for a waiver. I suspect that your kit is assembled from what Schlumberger had available. Given the SD time, I suggest that you do a full test once everyone is back on location. Call or message with questions. Tom Maunder, PE AOGCC 907 -529 -1645 Eddie Wright wrote, On 6/22/2007 3:52 AM: Tom, I have cleanup some mistakes on this first BOP test. Would you please provide a copy of the AOGCC BOP testing requirements? I would like to provide this to Ed Scott for our testing on Saturday or Sunday this weekend. We need to record more information to meet the testing requirements. We should receive the replacement 2 -3/8" coil tubing and reel on Friday. Schlumberger will be changing out the reel on Saturday. We plan to start operations on late Saturday or Sunday morning. Thanks, Eddie Wright Petroleum Engineers, Inc. Three Riverway, Suite 1500 Houston, TX 77056 Office: 713- 479 -7070 Cell: 713- 823 -7789 6/13/2009 • • Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Friday, June 22, 2007 6:40 AM To: 'Thomas E Maunder' Subject: RE: First BOP Test Tom I came back to Houston on Tuesday. Working from my office and home. Ed Scott will be on location late Saturday. I will probably not come back, unless there are problems. I am working on historical paperwork to complete the Ahtna #1 -19 file. Eddie Original Message From: Thomas E Maunder [mailto:tom_maunder @admin.state.ak.us] Sent: Friday, June 22, 2007 9:34 AM To: Eddie Wright Subject: Re: First BOP Test Thanks Eddie. I am still at home. I will get a note to you after I am in. Are you still in AK? Tom Original Message From: Eddie Wright <ewright @peiinc.com> Date: Friday, June 22, 2007 3:52 am Subject: First BOP Test To: 'Thomas Maunder' <tom_maunder @admin.state.ak.us> Cc: 'ed scott' <sickiscott2205@yahoo.com> > Tom, > I have cleanup some mistakes on this first BOP test. > Would you please provide a copy of the AOGCC BOP testing requirements? > I would like to provide this to Ed Scott for our testing on Saturday > or Sunday this weekend. We need to record more information to meet > the testing requirements. > We should receive the replacement 2 -3/8" coil tubing and reel on > Friday.Schlumberger will be changing out the reel on Saturday. We > plan to start operations on late Saturday or Sunday morning. > Thanks, > Eddie Wright > Petroleum Engineers, Inc. > Three Riverway, Suite 1500 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Friday, June 22, 2007 3:52 AM To: 'Thomas Maunder' Cc: 'ed scott' Subject: First BOP Test Attachments: 2007_061 6 Ahtna 1 -19A BOP Test 6- 16- 07.xls Tom, I have cleanup some mistakes on this first BOP test. Would you please provide a copy of the AOGCC BOP testing requirements? I would like to provide this to Ed Scott for our testing on Saturday or Sunday this weekend. We need to record more information to meet the testing requirements. We should receive the replacement 2 -3/8" coil tubing and reel on Friday. Schlumberger will be changing out the reel on Saturday. We plan to start operations on late Saturday or Sunday morning. Thanks, Eddie Wright Petroleum Engineers, Inc. Three Riverway, Suite 1500 Houston, TX 77056 Office: 713- 479 -7070 Cell: 713- 823 -7789 6/13/2009 0 0 4/03/07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: tiro regq aogcc prudhoe bay bob fleckenstein (a� admin.state.ak.us Contractor: Schlumberger Rig No.: 1 DATE: 6/16/07 Rig Rep.: Ed Burrell Rig Phone: 398 -7272 Rig Fax: Operator: Rutter & Wilbanks Corp. Op. Phone: 320 -0504 Op. Fax: Rep.: Ed Scott E -Mail sickiscott2205yahoo.com Well Name: ATHNA #1 -19A PTD # 207 -085 Operation: DrIg: X Workover: Explor.: X Test: Initial: X Weekly: x Bi- Weekly Test Pressure: Rams: 500/5000 Annular: x Valves: 500/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig NA Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type NA Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8 P Trip Tank P NA Annular Preventer NA Pit Level Indicators NA NA #1 Rams 1 blind rams P Flow Indicator NA NA #2 Rams 1 2 -3/8 "pipe P Meth Gas Detector NA NA #3 Rams 1 blind rams P H2S Gas Detector NA NA #4 Rams 1 2 -3/8" pipe P #5 Rams NA Quantity Test Result Choke Ln. Valves 2 2" plug P Inside Reel valves 1 P HCR Valves NA Kill Line Valves 2 2" plug P ACCUMULATOR SYSTEM: Check Valve NA Time /Pressure Test Result System Pressure 2500 P CHOKE MANIFOLD: Pressure After Closure 1200 P Quantity Test Result 200 psi Attained NT No. Valves 3 P Full Pressure Attained 2500 P Manual Chokes 2 P Blind Switch Covers: All stations Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 1000 psi Test Results Number of Failures: 0 Test Time: 3 Hours Components tested 24 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: jim regq@admin.state.ak.us Remarks: Held pressure on annulus for 30 min. 2500 psi see chart.Test went good know problems on new BOP's and casing from surface to 4170Ft to top of cement. Held low 500 -5min high 5000 -5min Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES yes NO c - Oper. /Rig Waived By c - Database Date 6/15/07 Time 1200 c - Trip Rpt File Witness Ed Scott c - Inspector Test start 6 -16 -07 1420 Finish 6 -16 -07 1720 C: \temp \Temporary Internet Files \OLKB8 \2007_0616 Ahtna _1- 18B0BCIDIB'I1Basil,h046a319k BOP Test_6- 16- 07.xls • • Page 1 of 2 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Wednesday, June 20, 2007 7:20 AM To: Eddie Wright Cc: 'Michael S. "Mick" Francisco' Subject: Re: BOP pressure test form Thanks Eddie. I understood there was a coil problem from the daily report. There is always something. Best regards, Tom Eddie Wright wrote, On 6/20/2007 4:43 AM: Tom, Ed Scott continued to have computer problems with this submittal. I will take a look at this today and get the information back to you. We have temporarily shutdown site operations until Schlumberger can get a new reel with 2 -3/8" coil tubing. We developed a hole in the reel about 4075'. The total footage on the reel was 6,000'. The only alternative to fix this is to get another reel from the North Slope. Ed Burrell is working this issue and we should have a date later today from Burrell when the reel will be on site at the Athna #1 -19A site. Eddie From: Thomas Maunder [mailto:tom maunder ©admin.state.ak.us] Sent: Tuesday, June 19, 2007 11:01 AM To: Thomas Maunder Cc: Ed Scott; Eddie Wright Subject: Re: [Fwd: Re: BOP pressure test] Ed and Eddie, Got your message regarding the coil problems. Tough break. Have you had an opportunity to try to work the BOP test sheet again? Please have a look at the sheet I sent with the original of this message. Thanks, Tom Maunder, PE AOGCC T • : .s Maunder wrote, On 6/18/2007 8:05 AM: Ed, Ed your latest BOP to - •ort came throu• • - ame way. Try starting with this copy. I think with ti - : *gmal sheet you have to "save as" wit . - 'tie. To Original Message Subject:Re: BOP pressure test 6/13/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Monday, June 18, 2007 4:34 PM To: eddiewright25 @hotmail.com; Eddie Wright; thomas; Barry Ahearn; mfrancisco @houston.rr.com; ed burrell Subject: Wait on coil tubing Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls - - Don't get soaked. Take a quick peak at the forecast with theYahoo! Search weather shortcut. 6/13/2009 0 0 Decca Consulting LTD. DAILY DRILLING REPORT DAY 8 WELL NAME Rutter and Wilbanks Corporation DATE 18- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N,R -3 -W DEPTH (06:00 hrs) 4138.4 AFE NUMBER 0 PROGRESS 1.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Look at hole in coil tube AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 0600 -0900 Work on depth tracker on coil tube and inspect crack in DESCRIPTION COST ($) coil tubing drill line, Ed burrell called office of schlumberger they - - Supervisor cost — 1,500 said that it was going to take 5 -7 days to replace coil tubing spool Rain for rent 757 had to come from the north slope. Shut down send men home and - Hotel &food _ 2,000 wait on new coil tubing drill line. Trailor &gen 150 Baker tools 5,000 Schlumberger 25,204 Mi swaco 4,000 Mud Products & Mud Van 0 TOTAL DAY 38,611 TOTAL CUMULATIVE 353,737 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal (s /I) (cc /30 min) (mm) mg /I (Pa) (mPas) Ib /100ft2 ( %) ( %) ( %) (m3) (m3) 8.5 46 9 200 12 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT i I I I MUD VAN DAILY AMOUNT (sx or I) COST COST ($) i i $0 MUD COMPANY IMI Swaco I MUD TYPE 'Polymer I CUMULATIVE COST $1,694 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM INCHES (mm) FT FT (m) FT /H (daN) 1 7116071 4 window mill 3 x 25 4137 4138 1 6 0 G I IN 1200 400 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) psi barrels (m /min) 1 Gardener /den 3.75x5 1230 2.5 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). 23/8x2 3 /8ctc 0.95 MOVE RIG i RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) WGT BAR WFT i 3.98 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) HYD DISC 7/8B 1.53 RAT HOLE I MUD RING HALF SPEED PUMP RATE (spm) DUAL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) OREITNER 30 4.86 CIRCULATE — WELD ON BOWL I MOTOR 11.2 RUN CASING NIPPLE UP BOP ' HCC-BI-BIT 0.82 CEMENT TEST BOP TOTAL 26.06 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH : - 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Monday, June 18, 2007 8:05 AM To: Ed Scott Cc: Eddie Wright Subject: [Fwd: Re: BOP pressure test] Attachments: 2007_061 6 Ahtna 1- 19A.xls Ed, Ed your latest BOP test report came through the same way. Try starting with this copy. I think with the original sheet you have to "save as" with a new title. Tom Original Message Subject:Re: BOP pressure test Date:Sun, 17 Jun 2007 12:58:37 -0800 From:Thomas Maunder <tom_maunder adniin.state.ak.us> Organization:State of Alaska To:ed scott <sickiscott2205 ayahoo.com> CC:Eddie Wright <ewri ht eiinc.com> References : <887289.18923.gm @web33302 .mail.mud.yahoo.com> Ed, I have looked at the BOP test sheet and have a couple of questions. I have added a few bits of info in the upper section. Mainly Xs on drilling, initial and explor. I have also included the permit number and titled your report. 1. I am curious why all the Fs (failures) in particular the choke manifold. There should be no Fs. 2. Did you time the recharge of the accumulator system to 200 psi? That is an important entry. 3. The number of failures and the test time should also be entered. 4. The number of components is the total number of rams + valves that were tested. 5. What is meant by the entry "2x2 hammer "? Thanks in advance. Tom Maunder, PE AOGCC ed scott wrote, On 6/16/2007 11:34 PM: Hi Tom, Here is the test for the board and I tested the annulas to up to 2500psi for 30 min. and it looks good if you need anything else just call thanks Ed. Fussy? Opinionated? Impossible to please? Perfect. Join Yahoo! 's user panel and lay it on us. 6/13/2009 • • 4/03/07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim regqaadmin.state.ak.us aogcc prudhoe bay(cadmin.state.ak.us bob fleckensteinadmin.state.ak.us Contractor: Schlumberger Rig No.: 1 DATE: 6/16/07 Rig Rep.: Ed Burrell Rig Phone: 398 -7272 Rig Fax: Operator: Rutter & Wilbanks Corp. Op. Phone: 320 -0504 Op. Fax: Rep.: Ed Scott E -Mail sickiscott2205 Well Name: ATHNA #1 -19A PTD # 207 -085 Operation: DrIg: X Workover: Explor.: X Test: Initial: X Weekly: x Bi- Weekly Test Pressure: Rams: 500/5000 Annular: x Valves: 500/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: I Well Sign I Upper Kelly I Housekeeping: F Drl. Rig F Lower Kelly I PTD On Location I Hazard Sec. I Ball Type I Standing Order Posted P Inside BOP 1 BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8 F Trip Tank I I Annular Preventer I Pit Level Indicators I I #1 Rams 1 blind rams P Flow Indicator I I #2 Rams 1 pipe rams P Meth Gas Detector I I #3 Rams 1 blind rams P H2S Gas Detector I I #4 Rams 1 pipe rams P #5 Rams I Quantity Test Result Choke Ln. Valves 2 2x2 hammer F Inside Reel valves 1 P HCR Valves I Kill Line Valves 2 2x2 hammer F ACCUMULATOR SYSTEM: Check Valve I Time /Pressure Test Result System Pressure 2500 P CHOKE MANIFOLD: Pressure After Closure 1200 P Quantity Test Result 200 psi Attained I No. Valves 3 F Full Pressure Attained 2500 P Manual Chokes 2 F Blind Switch Covers: All stations Hydraulic Chokes 0 1 Nitgn. Bottles (avg): 1000 psi Test Results Number of Failures: Test Time: 0 Hours Components tested all Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: jim regq Remarks: Held pressure on annulus for 30 min. 2500 psi see chart.Test went good know problems on new BOP's and casing from surface to 4170Ft to top of cement. Held low 500 -5min high 5000 -5min Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES yes NO c - Oper. /Rig Waived By c - Database Date 6/15/07 Time 1200 c - Trip Rpt File Witness Ed Scott c - Inspector Test start 6 -16 -07 1420 Finish 6 -16 -07 1720 C: \temp \Temporary Internet Files \OLKB8 \2007_0616 Ahtna_1 -19A (2).xls 2007_0616 Ahtna_1 -19A (2).xls • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Monday, June 18, 2007 7:53 AM To: 'Michael S. "Mick" Francisco' Cc: 'Ed Burrell'; 'ed scott'; 'Thomas E Maunder'; eddiewright25 @hotmail.com; 'Eddie Wright' Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Mick Here is Ed Scott's morning report. 6/13/2009 • S Decca Consulting LTD. DAILY DRILLING REPORT DAY 7 WELL NAME Rutter and Wilbanks Corporation DATE 17- Jun -07 LOCATION (UWI) Athna #1-19A Sec.19,T- 4- N.R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Milling window AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 600 -830 Rig up whip stock DESCRIPTION COST ($) 830 -930 RIH to flag point to MD 4140FT pickup 17Ft off bottom Supervisor cost 1,500 930 -1030 Set MD 1011am pump up and shear pin on whip stock Rain for rent 757 at 3200psi,pressure drop to 0 looks good no problems - Hotels &food 2,000 1030 -1130 POOH and displace to 8.5 ppg mud Schlumberger 46,913 1130 -1330 make up milling assembly and 3.80 bit Mi swaco 12,522 1330 -1530 wait on computor hard drive on location 1530pm 1530 -1930 Repair computer. 2000 RIH tag top of whip stock at 4135' Trailer &gen 150 2000 -2130 Establish flow rates 1- barral per min -250 psi on choke, Contingency 7,200 300psi on well head, 469psi on coil, then 2.5 barrels per min. well head travel &site aogcc meeting 9,600 309 psi coil 1030psi, choke 750psi hold back press. 2130 -1130 RIH to top of whip stock tag at 4135'. Start to cut window at 4137- 4137.4Ft Mud Products & Mud Van 1,694 1130 -0030 vac truck problems. Rig up transfer pump. TOTAL DAY 82,336 0030 -0600 Mill F/4137.4- T/4138.4Ft Stop to check depth problem. TOTAL CUMULATIVE 315,126 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES lb /gal (s /I) (cc /30 min) (mm) mg /I (Pa) (mPas) Ib /100ft2 ( %) ( %) ( %) barrels barrels 8.5 46 9 200 12 0 0 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT clean up defoam x duo -vis Iasph- supremq' I ; MUD VAN DAILY AMOUNT (sx or I) 1 1 20 ] 12 COST COST ($) 698 145 676 1 175 1 j $1,694 MUD COMPANY IMI Swaco I MUD TYPE 'Polymer I CUMULATIVE COST $1,694 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM FT inches FT (m) (m) (m /hr) (daN) 1 7116071 4 window mill 3 x 25 - 4137 0 1200 400 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) inches (spm) psi gallons (m /min) 1 Gardener /Den 3.75X5 1230 2.5 ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) 2 3/8x2 /38 ctc 0.95 MOVE RIG 1 RIG SERVICE CASING DEPTH (m) BPV 1.57 RIG UP SURVEY II LEAK - OFF GRADIENT(kPa/m) WGT BAR WFT 3.98 SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) HYD DISC 7/8B 1.53 RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) DUAL CIRC 1.15 DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) ORIENTER 30 4.86 CIRCULATE WELD ON BOWL ' MOTOR 11.2 RUN CASING i NIPPLE UP BOP HCC-BI BIT 0.82 ' CEMENT I TEST BOP TOTAL 26.06 TOTAL; 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Eddie Wright [ewright @peiinc.com] Sent: Sunday, June 17, 2007 10:49 PM To: 'Thomas E Maunder' Subject: Cased Hole Log Attachments: SLB Cased Hole Log Data.pdf; Summary of Well Data from Cased Hole Log.pdf Tom Here is the cased hole log where we recorded GR /CCL /Pressure/Temperature readings in 0.5 ft increments to a total of 154 pages! The data columns are Depth, GR, Water Temperature, Water Gradient, and Well Pressure. I summarized the data into a short two page summary. We have started to mill the window tonight. We had the computer control system fail on the SLB CTU. Got parts flown in from the North Slope and installed this afternoon. After checking out the data acquisition system, we started in the hole to mill the window. Eddie 6/13/2009 Summary of well Data from Cased Hole Log Condensed view of well Data from Cased Hole Log June 11, 2007 2007 - Jun -11 16:23 WELL INFORMATION DATA DESCRIPTION Rutter & wilbanks Corporation :COMPANY AHTNA NO. 1 -19 ST #1 :WELL COPPER RIVER BASIN WILDCAT :FIELD Sec. 19, T 4N. R 3W, CRM :LOCATION GULKANA :COUNTY ALASKA :STATE 50 -099- 20005 -00 :API NUMBER Schlumberger :SERVICE COMPANY 19 :Section 3w :Range 4N :Township INFORMATION VALUE DESCRIPTION 17.00000 :Casing weight 5.00000 :Current Casing Size 4640.00000 :Total Depth - Driller 2018.69995 :Elevation of Permanent Datum 2037.00000 :Elevation of Log Zero 2018.69995 :Elevation of Ground Level 2037.00000 :Elevation of Kelly Bushing J. DALEBOUT :Engineer's Name 2007 - Jun -11 16:23 :Date as Month- Day -Year 3W :Range 4N :Township 19 :Section 50- 099 - 20005 -00 :API Serial Number KELLY BUSHING :Drilling Measured From KELLY BUSHING :Log Measured From GROUND LEVEL :Permanent Datum ALASKA :State or Province COPPER RIVER BASIN WILDCAT :Field Name AHTNA NO. 1 -19 ST #1 :Well Name Rutter & wilbanks Corporation :Company Name 1 :RUN NUMBER 18.300049 :Elevation of Depth Reference (LMF)above Permanent Datum Page 1 • • summary of Well Data from Cased Hole Log DEPTH GR FLUID TEMPERATURE BOTTOM HOLE TEMP GRADIENT PRESSURE (ft) (deg F) (deg /ft) (psi g) 4307.5 0.0000 88.6451 0.0234 4158.9497 4300.0 19.6582 88.6614 - 0.0307 4156.1152 4290.0 24.0132 88.5537 0.0216 4149.9785 4280.0 24.2695 88.5426 - 0.0002 4143.8228 4270.0 22.1464 88.5159 0.0097 4137.8086 4260.0 13.5546 88.4537 0.0072 4132.0352 4250.0 12.4742 88.3720 0.0130 4126.0469 4230.0 23.7626 88.2434 0.0169 4114.2764 4220.0 31.6335 88.1008 0.0125 4108.3574 4210.0 33.2494 87.9995 0.0132 4102.4336 4200.0 30.1991 87.9089 0.0113 4096.5015 4190.0 29.1599 87.8296 0.0096 4090.6467 4180.0 24.6987 87.6887 0.0245 4084.6978 4170.0 24.8390 87.5455 0.0215 4078.8940 4160.0 21.2801 87.4153 0.0193 4073.2163 4150.0 26.9600 87.2935 0.0203 4067.2886 4140.0 26.3901 87.1755 0.0168 4061.4397 4130.0 22.2884 87.0566 0.0174 4055.5017 4120.0 33.7590 86.9209 0.0205 4049.7000 4110.0 38.6498 86.7766 0.0234 4043.7302 4100.0 40.5518 86.6280 0.0203 4037.9724 4000.0 33.6892 85.2906 0.0146 3979.5059 3000.0 29.9056 72.2854 0.0152 3409.4473 2000.0 35.9545 61.1963 0.0186 2855.5232 1500.0 26.5672 55.1636 0.0221 2584.5422 1000.0 20.3825 48.5573 0.0193 2315.5063 500.0 11.9003 39.5587 0.0267 2048.9290 100.0 15.9613 33.6430 0.0190 1835.9630 90.0 14.8102 33.4980 0.0172 1830.6421 80.0 15.4951 33.3868 0.0133 1825.2695 70.0 10.9652 33.2873 0.0331 1819.9583 60.0 16.2492 33.1683 0.0106 1814.6285 59.0 15.6022 33.1599 0.0097 1814.1360 58.0 13.3017 33.1557 0.0083 1813.5676 57.0 10.7859 33.1489 0.0103 1813.0469 56.0 13.4482 33.1422 0.0085 1812.5011 55.0 13.3743 33.1375 0.0072 1811.9413 54.0 14.3449 33.1339 0.0047 1811.5032 53.0 12.9064 33.1345 - 0.0005 1810.9554 52.0 11.0011 33.1356 - 0.0032 1810.4432 51.0 13.5525 33.1381 - 0.0052 1809.8531 50.0 13.3372 33.1397 - 0.0020 1809.3420 45.0 9.0338 33.3138 - 0.1338 1806.7490 40.0 12.0238 33.9889 - 0.2430 1804.1733 35.0 10.6113 35.3477 - 0.5261 1801.5895 30.0 12.6839 38.3929 - 1.1359 1799.1180 25.0 8.7419 43.7817 - 2.0887 1796.5846 20.0 3.2946 48.9487 0.0949 1794.0114 15.0 2.7062 51.7676 - 1.7543 1791.6202 10.0 8.3461 57.7375 - 1.6003 1789.1898 5.0 9.4153 60.6784 - 0.7261 1786.8895 0.0 14.4098 62.0248 - 0.2668 1784.5322 Page 2 • Page 1 of 1 r Thomas E (DOA) Maunder, ho as ( O ) From: ed scott [sickiscott2205 @yahoo.com] Sent: Sunday, June 17, 2007 3:00 PM To: thomas Attachments: Bop Test sheet.xls Sorry Tom,I must have not prest save when I started I was filling it out wrong so I changed it I most not have prest say before I sent it We had no problems on the test everything tested first time.sorry Ed You snooze, you lose. Get messages ASAP with AutoCheck in the all -new Yahoo! Mail Beta. 6/13/2009 • • 4/03/07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim regg a(� admin.state.ak.us aogcc prudhoe bay bob fleckenstein (a� admin.state.ak.us Contractor: Schlumberger Rig No.: 1 DATE: 6/16/07 Rig Rep.: Ed Burrell Rig Phone: 398 -7272 Rig Fax: Operator: Rutter & Wilbanks Corp. Op. Phone: 320 -0504 Op. Fax: Rep.: Ed Scott E -Mail sickiscott2205 Well Name: ATHNA #1 -19A PTD # Operation: DrIg: Workover: Explor.: 1-19A Test: Initial: Weekly: x Bi- Weekly Test Pressure: Rams: 500/5000 Annular: x Valves: 500/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: I Well Sign I Upper Kelly I Housekeeping: P Drl. Rig P Lower Kelly I PTD On Location I Hazard Sec. I Ball Type I Standing Order Posted P Inside BOP I BOP STACK: Quantity Size /Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8 P Trip Tank I I Annular Preventer I Pit Level Indicators I I #1 Rams 1 blind rams P Flow Indicator I I #2 Rams 1 pipe rams P Meth Gas Detector I I #3 Rams 1 blind rams P H2S Gas Detector 1 I #4 Rams 1 pipe rams P #5 Rams 1 Quantity Test Result Choke Ln. Valves 2 2x2 hammer P Inside Reel valves 1 P HCR Valves I Kill Line Valves 2 2x2 hammer P ACCUMULATOR SYSTEM: Check Valve I Time /Pressure Test Result System Pressure 2500 P CHOKE MANIFOLD: Pressure After Closure 1200 P Quantity Test Result 200 psi Attained I No. Valves 3 P Full Pressure Attained 2500 P Manual Chokes 2 P Blind Switch Covers: All stations Hydraulic Chokes 0 I Nitgn. Bottles (avg): 1000 psi Test Results Number of Failures: 0 Test Time: 0 Hours Components tested all Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: iim regq Remarks: Held pressure on annulus for 30 min. 2500 psi see chart.Test went good know problems on new BOP's and casing from surface to 4170Ft to top of cement. Held low 500 -5min high 5000 -5min Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES yes NO c - Oper. /Rig Waived By c - Database Date 6/15/07 Time 1200 c - Trip Rpt File Witness Ed Scott c - Inspector Test start 6 -16 -07 1420 Finish 6 -16 -07 1720 C: \temp \Temporary Internet Files \OLKB8 \Bop Test sheet.xls Bop Test sheet.xls • • Page 1 of 1 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Sunday, June 17, 2007 12:59 PM To: ed scott Cc: Eddie Wright Subject: Re: BOP pressure test Attachments: 2007_061 6 Ahtna 1- 19A.xls Ed, I have looked at the BOP test sheet and have a couple of questions. I have added a few bits of info in the upper section. Mainly Xs on drilling, initial and explor. I have also included the permit number and titled your report. 1. I am curious why all the Fs (failures) in particular the choke manifold. There should be no Fs. 2. Did you time the recharge of the accumulator system to 200 psi? That is an important entry. 3. The number of failures and the test time should also be entered. 4. The number of components is the total number of rams + valves that were tested. 5. What is meant by the entry "2x2 hammer "? Thanks in advance. Tom Maunder, PE AOGCC ed scott wrote, On 6/16/2007 11:34 PM: Hi Tom, Here is the test for the board and I tested the annulas to up to 2500psi for 30 min. and it looks good if you need anything else just call thanks Ed. Fussy? Opinionated? Impossible to please? Perfect. Join Yahoo!'s userpanel and lay it on us. 6/13/2009 0 • 4/03/07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim reqqadmin.state.ak.us aoqcc Prudhoe bay bob fleckenstein (c� admin.state.ak.us Contractor: Schiumberger Rig No.: 1 DATE: 6/16/07 Rig Rep.: Ed Burrell Rig Phone: 398 -7272 Rig Fax: Operator: Rutter & Wilbanks Corp. Op. Phone: 320 -0504 Op. Fax: Rep.: Ed Scott E -Mail sickiscott2205 ahoo.com Well Name: ATHNA #1 -19A PTD # 207 -085 Operation: DrIg: X Workover: Explor.: X Test: Initial: X Weekly: x Bi- Weekly Test Pressure: Rams: 500/5000 Annular: x Valves: 500/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: I Well Sign I Upper Kelly I Housekeeping: F Drl. Rig F Lower Kelly I PTD On Location I Hazard Sec. I Ball Type I Standing Order Posted P Inside BOP 1 BOP STACK: Quantity Size /Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8 F Trip Tank I I Annular Preventer I Pit Level Indicators I I #1 Rams 1 blind rams P Flow Indicator I I #2 Rams 1 pipe rams P Meth Gas Detector I 1 #3 Rams 1 blind rams P H2S Gas Detector 1 1 #4 Rams 1 pipe rams P #5 Rams I Quantity Test Result Choke Ln. Valves 2 2x2 hammer F Inside Reel valves 1 P HCR Valves I Kill Line Valves 2 2x2 hammer F ACCUMULATOR SYSTEM: Check Valve I Time /Pressure Test Result System Pressure 2500 P CHOKE MANIFOLD: Pressure After Closure 1200 P Quantity Test Result 200 psi Attained I No. Valves 3 F Full Pressure Attained 2500 P Manual Chokes 2 F Blind Switch Covers: All stations Hydraulic Chokes 0 I Nitgn. Bottles (avg): 1000 psi Test Results Number of Failures: Test Time: 0 Hours Components tested all Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: iim reqqadmin.state.ak.us Remarks: Held pressure on annulus for 30 min. 2500 psi see chart.Test went good know problems on new BOP's and casing from surface to 4170Ft to top of cement. Held low 500 -5min high 5000 -5min Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES yes NO c - Oper. /Rig Waived By c - Database Date 6/15/07 Time 1200 c - Trip Rpt File Witness Ed Scott c - Inspector Test start 6 -16 -07 1420 Finish 6 -16 -07 1720 C: \temp \Temporary Internet Files \OLKB8 \2007_0616 Ahtna_1 -19A (2).xls 20070616 Ahtna_1 -19A (2).xls • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Sunday, June 17, 2007 5:33 AM To: eddiewright25 @hotmail.com; Eddie Wright; barry; mfrancisco @houston.rr.com; ed burrell; thomas Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Be a better Heartthrob. 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DAILY DRILLING REPORT DAY 6 WELL NAME Rutter and Wilbanks Corporation DATE 16- Jun -07 LOCATION (UWI) Athna #1 - 19A Sec.19,T 4 - N,R - - DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) install whip stock wait on computor parts AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 600- 1400 pm Finish rigging up, Function test BOP's DESCRIPTION COST ($) - - -- - - - - - -- - - -- - - - - -- 1400- 1730pm Test BOP equipment ,all valves ,2 -blind rams,2-pipe ram Supervisor cost 1,500 2- man chokes,2x2 hammer unions,lines to tanks,inside reel valves, Rain for rent 757 accumulator system 2500 start,1200 left after function test,nitgon test Hotel &food 2,000 all bottles 1000 psi, Schlumberger 25,204 1730- 180 -pm make up x/o on coil line and mud motor Water truck 700 1800- 2000pm rig down computor dead on rig ,no controls at all code #8 Mi Swaco 5,000 it looks like hard drive is gone we will have to wait until morning to fix Baker Tools 2,500 2000- 0600am pick up mud motor ream to bottom to clean up Trailor &Gen 300 casing, tag cement pull up and circulate, and change over to mud, pull Contingency 4,500 coil hook up and install whip stock and wait on computor parts before Vetco Gray 7,507 we set whip stock. Mud Products & Mud Van 0 TOTAL DAY 49,968 TOTAL CUMULATIVE 232,790 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s/I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or I) COST --i so COST ($) i 1 MUD COMPANY IMI I MUD TYPE I 1 CUMULATIVE COST $0 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m /hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT 1 I move rig down time on rig 2.00 CASING DEPTH (m) BELL SUB i RIG UP 8.00 SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM make up whip 3.00 MUD RING HALF SPEED PUMP RATE (spm) 1_X0 _ - - - L __ DRILL Rig up mud motor — HALF SPEED PUMP PRESSURE (kPa) 5- 125MM I CIRCULATE 4.00 WELD ON BOWL KELLY D I Ream 3.50 NIPPLE UP BOP CEMENT TEST BOP 3.50 TOTAL; 0 TOTAL 24.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE/FAX # 1 - 907 - 320 - 0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1 - 713 - 823 - 7789 • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Sunday, June 17, 2007 5:31 AM To: eddiewright25 @hotmail.com; eddiewright25 @hotmail.com; barry; mfrancisco @houston.rr.com; thomas; ed burrell Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Looking for a deal? Find great prices on flights and hotels with Yahoo! FareChase. 6/13/2009 0 • Decca Consulting LTD. DAILY DRILLING REPORT DAY 6 WELL NAME Rutter and Wilbanks Corporation DATE 16- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19,T- 4- N.R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) install whip stock wait on computor parts AFE Cost Estimate 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 600- 1400 pm Finish rigging up, Function test BOP's DESCRIPTION COST ($) 1400- 1730pm Test BOP equipment ,all valves ,2 -blind rams,2 -pipe ram _ Supervisor cost 1,500 2- man chokes,2x2 hammer unions,lines to tanks,inside reel valves, Rain for rent 757 accumulator system 2500 start,1200 left after function test,nitgon test Hotel &food 2,000 all bottles 1000 psi, Schlumberger 25,204 1730- 180 -pm make up x/o on coil line and mud motor Water truck 700 1800- 2000pm rig down computor dead on rig ,no controls at all code #8 Mi Swaco - 5,000 it looks like hard drive is gone we will have to wait until morning to fix Baker Tools 2,500 2000- 0600am pick up mud motor ream to bottom to clean up Trailor &Gen 300 casing, tag cement pull up and circulate, and change over to mud, pull Contingency - 4,500 coil hook up and install whip stock and wait on computor parts before - Vetco Gray 7,507 we set whip stock. Mud Products & Mud Van 0 TOTAL DAY 49,968 TOTAL CUMULATIVE 232,790 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( %) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT I I I ; MUD VAN DAILY AMOUNT (sx or I) I COST COST ($) ( $O MUD COMPANY IMI 1 MUD TYPE' I CUMULATIVE COST $0 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m /hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm) BIT move rig down time on rig 2.00 CASING DEPTH (m) BELL SUB I RIG UP 8.00 SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB I SAFETY MEET. _L_ _ TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 -159MM make up whip 3.00 MUD RING HALF SPEED PUMP RATE (spm) 1 -XO DRILL Rig up mud motor HALF SPEED PUMP PRESSURE (kPa) 5- 125MM CIRCULATE 4.00 WELD ON BOWL KELLY D I Ream 3.50 NIPPLE UP BOP I CEMENT TEST BOP 3.50 TOTAL j 0 TOTAL1 24.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Saturday, June 16, 2007 11:34 PM To: thomas; eddiewright25 @hotmail.com; eddiewright25 @hotmail.com; barry; mfrancisco @houston.rr.com; ed burrell Subject: BOP pressure test Attachments: Bop Test sheet.xls Hi Tom, Here is the test for the board and I tested the annulas to up to 2500psi for 30 min. and it looks good if you need anything else just call thanks Ed. Fussy? Opinionated? Impossible to please? Perfect. Join Yahoo!'s user panel and lay it on us. 6/13/2009 , 0 • 4/03/07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim regq aogcc Prudhoe bay bob fleckenstein (cr� admin.state.ak.us Contractor: Schlumberger Rig No.: 1 DATE: 6/16/07 Rig Rep.: Ed Burrell Rig Phone: 398 -7272 Rig Fax: Operator: Rutter & Wilbanks Corp. Op. Phone: 320 -0504 Op. Fax: Rep.: Ed Scott E -Mail sickiscott2205 Well Name: ATHNA #1 -19A PTD # Operation: Drlg: Workover: Explor.: 1-19A Test: Initial: Weekly: x Bi- Weekly Test Pressure: Rams: 500/5000 Annular: x Valves: 500/5000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: I Well Sign I Upper Kelly I Housekeeping: F Dri. Rig F Lower Kelly 1 PTD On Location I Hazard Sec. I Ball Type 1 Standing Order Posted P Inside BOP I BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8 F Trip Tank I I Annular Preventer I Pit Level Indicators I 1 #1 Rams 1 blind rams P Flow Indicator I I #2 Rams 1 pipe rams P Meth Gas Detector 1 1 #3 Rams 1 blind rams P H2S Gas Detector I 1 #4 Rams 1 pipe rams P #5 Rams I Quantity Test Result Choke Ln. Valves 2 2x2 hammer F Inside Reel valves 1 P HCR Valves I Kill Line Valves 2 2x2 hammer F ACCUMULATOR SYSTEM: Check Valve 1 Time /Pressure Test Result System Pressure 2500 P CHOKE MANIFOLD: Pressure After Closure 1200 P Quantity Test Result 200 psi Attained I No. Valves 3 F Full Pressure Attained 2500 P Manual Chokes 2 F Blind Switch Covers: All stations Hydraulic Chokes 0 1 Nitgn. Bottles (avg): 1000 psi Test Results Number of Failures: Test Time: 0 Hours Components tested all Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: Om regq Remarks: Held pressure on annulus for 30 min. 2500 psi see chart.Test went good know problems on new BOP's and casing from surface to 4170Ft to top of cement. Held low 500 -5min high 5000 -5min Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES yes NO c - Oper. /Rig Waived By c - Database Date 6/15/07 Time 1200 c - Trip Rpt File Witness Ed Scott c - Inspector Test start 6 -16 -07 1420 Finish 6 -16 -07 1720 C: \temp \Temporary Internet Files \OLKB8 \Bop Test sheet.xls Bop Test sheet.xls • • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Saturday, June 16, 2007 3:01 AM To: eddiewright25 @hotmail.com; Eddie Wright; barry; thomas; mfrancisco @houston.rr.com; ed burrell Subject: Rig up and install BOP's Attachments: Rutter and Wilbanks Corporation Ahtna #1- 19A.xls Sick sense of humor? Visit Yahoo! TV's Comedy_ with an Edge to see what's on, when. 6/13/2009 III • Decca Consulting LTD. DAILY DRILLING REPORT DAY 5 WELL NAME Rutter and Wilbanks Corporation DATE 15- Jun -07 LOCATION (UWI) Athna #1 -19A Sec.19.T- 4- N,R -3 -W DEPTH (06:00 hrs) AFE NUMBER 0 PROGRESS 0.0 CONTRACTOR & RIG # Schlumberger PROJECTED T.D. 4280FT OPERATION (06:00 hrs) Prepare to test BOP's AFE Cost Estimate - 1,000,000 SUMMARY OF OPERATIONS (06:00 - 06:00 hrs) DAILY COST SUMMARY 600- 1700pm Rig up coil tubing rig and surface tanks,swaco tanks DESCRIPTION COST ($) mix up mud, laydown christmas tree valves and spool,install new valves, Schlumberger 4 -day Rig total 58,056 1700 -600am install BOP's to fit bird cage. _ Supervisor 1,500 MI swaco 9,600 Rain for rent 757 Hotel &food 1,500 Contingency 7,000 water truck 650 Mud Products & Mud Van 0 TOTAL DAY 79,063 TOTAL CUMULATIVE 182,822 MUD PROPERTIES DENSITY VISCOSITY WATER LOSS FILTER CAKE pH CHLORIDES GELS PV YP SAND SOLIDS OIL DAILY LOSSES CUM. LOSSES (kg /m3) (s /I) (cc /30 min) (mm) (ppm) (Pa) (mPas) (Pa) ( %) ( %) ( ( Y.) (m3) (m3) 0 MUD PRODUCTS USED (Past 24 hrs) PRODUCT MUD VAN DAILY AMOUNT (sx or 1) , — __ COST $0 COST ($) — I i MUD COMPANY 1 1 MUD TYPE' I CUMULATIVE COST $0 BIT DATA BIT # SERIAL # SIZE TYPE JET SIZE DEPTH IN DEPTH OUT TOTAL HOURS RATE CONDITION WOB RPM (mm) (mm) (m) (m) (m) (m /hr) (daN) 0 0 PUMP DATA SURVEY DATA PUMP # DESCRIPTION BORE x STROKE STROKES PRESSURE RATE ANNULAR VEL. DEPTH (m) (mm) (spm) (kPa) (m3 /min) (m /min) ANGLE ( °) KILL DATA BOTTOMHOLE ASSEMBLY TIME BREAKDOWN (06:00 to 06:00 hrs) CASING SIZE (mm). BIT i MOVE RIG RIG SERVICE CASING DEPTH (m) BELL SUB RIG UP SURVEY LEAK - OFF GRADIENT (kPa/m) FLOAT SUB SAFETY MEET. TRIP MAXIMUM SHUT -IN PRESSURE (kPa) 2 - 159MM i RAT HOLE MUD RING HALF SPEED PUMP RATE (spm) 1 -XO i — DRILL W.O.C. HALF SPEED PUMP PRESSURE (kPa) 5 - 125MM i CIRCULATE WELD ON BOWL KELLY D RUN CASING NIPPLE UP BOP CEMENT TEST BOP 1 TOTAL 0 TOTAL 0.00 LEASE /ROAD CONDITION WEATHER/TEMPERATURE ( °C) CONTRACTOR TOOLPUSH 0 TELEPHONE /FAX # 0 SUPERVISOR Ed Scott TELEPHONE /FAX# 1- 907 - 320 -0504 REPORT SENT TO Eddie Wright TELEPHONE /FAX # 1- 713 - 823 -7789 . . Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Friday, June 15, 2007 3:10 PM To: Eddie Wright; Ed Scott Cc: Art Saltmarsh Subject: 207 -085 Ahtna_1- 19A.pdf Attachments: 207 -085 Ahtna_1- 19A.pdf 207- 085_Ahtna_1- 19A.pdf (2 KB)... Eddie and Ed, Enclosed are the cover letter and signed 401 for your drilling activity. I understand that Eddie will meet Art maybe this evening or tomorrow to deliver the full packet. I have made some "mark ups" in the document, please check for them. With regard to your BOP test. It does not appear that we will have an Inspector available to witness the BOP test. I have spoken with the Inspector's supervisor and we will waive witness of this test. Please complete the test form provided and send it to me for quality control. Please continue to send the report as you have been. I appreciate receiving that daily input. If you have any questions, please don't hesitate to call me. Good luck, Tom Maunder, PE AOGCC 1 • Page 1 of 1 Maunder, Thomas E (DOA) From: ed scott [sickiscott2205 @yahoo.com] Sent: Friday, June 15, 2007 6:54 AM To: Thomas Maunder Subject: Re: [Fwd: Emailing: BOP Coil Operator 5 -15 -07 p.xls] Thanks Tom, I will get the to us this sheet and I will send it to you first.Looks like that spool will be here today and then we will nipple up and test hope some time tonight by the time we get nipple up.Thanks Ed Scott Original Message - - -- From: Thomas Maunder <tom_maunder @admin.state.ak.us> To: Eddie Wright <ewright @peiinc.com >; ed scott <sickiscott2205 @yahoo.com> Sent: Thursday, June 14, 2007 2:30:19 PM Subject: [Fwd: Emailing: BOP Coil Operator 5 -15 -07 p.xls] Ed and Eddie, Here is the electronic BOP test form. The BOP test should be recorded on a copy of this form and submitted via email. Probably best to send it to me to check before it goes to others. Notice of performing the BOP test should be given to Jim Regg or the NS Inspectors. I am not sure if anyone will be available to witness the test. But we will see. Best regards, Tom Maunder, PE AOGCC Original Message Subject:Emailing: BOP Coil Operator 5 -15 -07 p.xls Date:Thu, 14 Jun 2007 11:43:11 -0800 From:Robert Fleckenstein <b o b _1eckenstein @admin.state.ak.us> Organization:State of Alaska To:Thomas E Maunder <tom maunder @admin.state.ak.us> You snooze, you lose. Get messages ASAP with AutoCheck in the all -new Yahoo! Mail Beta. 6/13/2009 • • 4/03/07 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim regg(c�admin.state.ak.us aogcc prudhoe bayadmin.state.ak.us bob fleckenstein (c,admin.state.ak.us Contractor: Rig No.: DATE: Rig Rep.: Rig Phone: Rig Fax: Operator: Op. Phone: Op. Fax: Rep.: E -Mail Well Name: PTD # Operation: DrIg: Workover: Explor.: Test: Initial: Weekly: Bi- Weekly Test Pressure: Rams: Annular: Valves: MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: I Well Sign 1 Upper Kelly I Housekeeping: I Drl. Rig I Lower Kelly I PTD On Location I Hazard Sec. I Ball Type I Standing Order Posted I Inside BOP I BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper I Trip Tank I I Annular Preventer I Pit Level Indicators I I #1 Rams 1 Flow Indicator 1 I #2 Rams I Meth Gas Detector I I #3 Rams I H2S Gas Detector I I #4 Rams I #5 Rams I Quantity Test Result Choke Ln. Valves I Inside Reel valves 1 HCR Valves I Kill Line Valves I ACCUMULATOR SYSTEM: Check Valve 1 Time /Pressure Test Result System Pressure I CHOKE MANIFOLD: Pressure After Closure I Quantity Test Result 200 psi Attained I No. Valves I Full Pressure Attained I Manual Chokes I Blind Switch Covers: All stations Hydraulic Chokes I Nitgn. Bottles (avg): Test Results Number of Failures: Test Time: Hours Components tested Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Superviser at: jim regqaadmin.state.ak.us Remarks: Distribution: 24 HOUR NOTICE GIVEN orig -Well File YES NO c - Oper. /Rig Waived By c - Database Date Time c - Trip Rpt File Witness c - Inspector Test start Finish C: \temp \Temporary Internet Files \OLKB8 \BOP Coil Operator 5 -15 -07 p.xls BOP Coil Operator 5 -15 -07 p.xls 1 SARAH PALJN, GOVERNOR ALASKA OII. AND GAS 333 W. 7th AVENUE, SUITE 100 CONSE CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 RVATION ii is l�il�ii►7►7 PHONE (907) 279 -1433 FAX (907) 276 -7542 Bill Rutter III Principle Rutter and Wilbanks Corporation (Oil and Gas Production) 301 S. Main Street, Suite B P.O. Box 3186 Midland, Texas 79702 Re: AHTNA 1 -19A Rutter and Wilbanks Corporation (Oil and Gas Production) Permit No: 207 -085 Surface Location: 1139.4' FEL, 2224.2' FSL, SEC. 19, T4N, R3W, CRM Bottomhole Location: 1139.4' FEL, 2224.2' FSL, SEC 19, T4N, R3W, CRM Dear Mr. Rutter: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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 petroleu e• field inspector at (907) 659- 3607 (pager) . ar Norma air DATED thisi day of June, 2007 cc: Department of Fish 85 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. f 1 • • pr,"1-71\fri May 16 07 02: 08p Rutter Companies 43 /.:32 - p•-`t- 14 1%. 5 j ''1 1 1 ``IrT 7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' s...)a t: 6r .umm,ss: PERMIT TO DRILL ;i>±;.6, aka 20 AAC 25.005 la. Type of Work: 1b. Current Well Class: Exploratory ® Development Oil ❑ 1c. Specify if well is proposed for. Drill ❑ Redrili ❑ StratigraphicTest ❑ Service O Development Gas 0 Coalbed Methane ❑ Gas Hydrates 0 Re -entry 0 Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑ Single Well R 11. Well Name and Nurrnbefin Rutter and Wilbanks Corporation Bond No. ev 4//430,/ Ahtna 1 -19 , 3t 3. Address: - 301 S S. Main St . , Suite B 8. Proposed Depth: 12. Field/Pool(s): � 1 P. 0. Box 3186, Midland, TX 79702 MD: 4300' TVD: 4300' 4a. Location of Well (Governmental Section): 7. Property Designation - 4'Y / 1 Surface: 1139.4' FEL, 2224.2 FSL Sec. 19 Sec. 19, T -4 -N CRM Top of Productive Horizon: T4N , R3W, CRM 8. Land Use Permit 13. Approximate Spud Date: Satre Ahtna Surface 5/28/07 Total Depth: 9. Acres in Property. 14. Distance to Nearest Same 640 acres Pre 1139' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 527867 y- 2964256 Zone- . (Height above GL): 2017 feet Within PotA 16. Deviated wells: Kickoff de 4190 feet 17. Maximum Anticipated Pressures in prig (see 20 MC 25,035) �G y ,+,�`j�} Maximum Hole Angle: 1 S degrees Downhoie: 4500# Surface: �1` o - Nf g-' r \ 4 1, S 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity. c.f. or sacks l Hole Casing Weight Grade Coupling Length MO TVD MD TVD (including stage data) 4 tl5 NQ DQzr. - 43�� . 1...1 A ,Q9yvv G 1 o--t.- 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MO (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MO (ft): Effect, Depth ND (ft): Junk (measured): Casing Length _ Size Cement Volume MD ND Conductor /Structural 78' 14 -'1 /R" 78' 78' . Surface 1707.7' 9-5/8" 1226' . 1226' ' Intermediate 1896.7' 7" 1915' 1915' Production GE,l9r 5i* - 4639'. 4639' Liner 588' 3-1/2" 5165' 5165' Perforation Depth MO (ft): Perforation Depth TVD (ft): 4508 -4530, 4474 -4530, 4387 4382, 4232 -5 20. Attachments: Filing Fee ,�J OP Sketch ❑ Drilling Program [. Time v. Depth Piot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ r Dlverter Sketch 0 Seabed Report © Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21. Verbal Approval; Commission Representative: Date 22. !hereby certify that the foregoing is true and correct. Contact Printed Name A. W. Rutter, Jr. Title Vice President Signature a 4 -. ), e yA Phone (432)683 -1524 Date 5 -16 -07 c/ Commission Use Only Permit to Drill oa,?(v, API Number: o:496007 S' C, J - Permit App at See cover letter for other Number. `irj -1344- �' 50- 099-S Date: (o , S 1 0 requirements. CondlOons of approval : tf box is checked, well may not be used to expbre for, test, or produce coalbed methane, as hydrates, or gas contained in shales: RI Other Samples req'd: Yes❑ Nol Mud log read: Yes❑ . .2o[L( 5000 ;\ (� H measures: Yes❑ No - al svy req'd: Yes F, No SvV∎tJ i .C_CL, `i" ©C C � `t• � N ' 'ROVED BY THE COMMISSION DATE: 6is // / � , Submit in Form 10 Revised 12/2005 plicate o R 1 61 A 111 • 0 RUTTER AND WILBANKS CORPORATION OIL AND GAS PRODUCTION 301 S. MAIN ST., SUITE B EC E I \ E n MID P.O. ND, BOX 3186 86 MIDLAND, TX 79701 V C 4J PHONE: JUN 1 2007 FAX: (432) 683 -1824 Alaska Oil & Gas Cons Commission (432) 683 -1732 1 40 01 3 5, 2007 Tom Maunder — O C c Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Ste. 100 Anchorage, AK 99501 Dear Tom, Please find enclosed a check ($100.00) for the Permit to Drill application fee (Form 10 -401) for the Ahtna #1 -19A Well. If you have any questions, please call Bill Rutter III or Chris Rutter. Sincerely, I l a ,ll.i \(,k Z'1 ' 1 ,i , J a Clements Jun 15 07 03:20p Rutter Companies 432631732 p.l FACSIMILE TRANSMISSION FROM RUTTER AND WILBANKS CORPORATION P. O. Box 3186 Midland, Texas 79702 (432)683 -1824 Fax (432)683 -1732 Date: June 15, 2007 Please Deliver Promptly To: TOM MAUNDER ALASKA OIL & GAS CONSERVATION COMMISSION From: Johnna Clements Here is a copy of the check for the application fee for the Ahtna #1 -19. The Check is going out today Federal Express Overnight. Thank you RECEIVED JUN 1 5 2007 Alaska Oil & Gas Cons. Commission Anchorage Jun 15 07 03:20p Rutter Companies 4326831732 p.2 Vendor No. - RUTTER AND WILBANKS CORPORA N Check No. P.O. EIOX 3146 •- MIDLAND, TEXAS 79702 7793 voice Number Invoice Date Explanation Gross Amount Deductions Amount Paid Application fee for Permit 100.00 to drill (Form 10 -401) for Ahtna #1 -19A • • • • • • WESTERN NATIONAL BANK RUTTER AND WILBANKS 7144aft 0(1 /lot 1163 MIDLAND, TEXAS CORPORATION / ' 7 ?f P.O. BOX 3146 • MIDLAND, TEXAS 79702 - Vendor No. Check Date • Check No. Amount 6 -15 -07 7703 $100.00 Pay ** *ONE HUNDRED AND NO /100 * ** • to the • order of ALASKA OIL & GAS CONSERVATION COMM. RUTTER AND WILBANKS CORPORATION ATTN : TOM MAUNDER • ___ �_.� 333 W 7th AVE., STE. 100 ANCHORAGE , AK 99501 11. 023883 {1' 1: L.L 63073701: 8096980 L Il' RECEIVED JUN 1 5 2007 Alaska QiI & Gas Cons. Commission Anchorepp 11111 . Petroleum Engineers, Inc. Three Riverway, Suite 1500 Houston, TX 77056 7� June 9, 2007 Alaska �`, }� � a fxu :�w. `;:s����sian Mr. Thomas Maunder Alaska Oil & Gas Conservation Commission 333 W. 7 Ave., Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed is a copy of the 10 -401 Notice of Intent To Drill (Sidetrack) dated 5/16/07. Enclosed is the Revision 4, of the Plugback„ Sidetrack, and Test Procedure. Revision 4 includes the AOGCC pressure build up testing and notification for AOGCC inspectors to be present during certain steps. Revision 4, also, includes some minor grammar changes that are different from Revision 3 that I emailed to you on 6/8/07. Please use this version for your considerations to approve our Intent To Drill. I look forward to working with you as we begin the coil tubing sidetrack and drilling operations at the Ahtna #1-19 location for Rutter & Wilbanks Corporation. Sincerely ours, Eddie L. Wright, P.E Petroleum Engineers, nc. Office 713- 479 -7070 Cell: 713 - 823 -7789 Email: ewright @peiinc.com FW: Rutter & Wilbanks Ahtna #1 -19 • Subject: FW: Rutter & Wilbanks Ahtna #1 -19 From: Eddie Wright <ewright @peiinc.com> Date: Thu, 07 Jun 2007 14:14:59 -0500 To: art saltmarsh@admin.state.ak.us Good morning Art, Our plans to work on the Ahtna #1 -19 have been finalized and approved by Mr. Rutter. We are planning on starting to move to location on Monday, June 11. Attached are the following: 1. Form 10 -403 Application for Sundry Approval of the Operational Shutdown period from 10/27/06 to 6/11/07 2. Form 10 -403 Application for Sundry Approval for the Plugback of existing perforations 3. Ahtna #1 -19 Procedure to plug back perforations and to sidetrack well. 4. Wellbore Diagrams that illustrate the current wellbore diagram, proposed plug back diagram, proposed sidetrack, and potential completion diagram. The original documents will be in an overnight mail service this afternoon. The documents should arrive in your office no later than Monday morning. With your assistance, is this information sufficient to receive a verbal approval to move to location for the planned plug back operations? If you have some questions, please send me an email. I can give you a call at your convenience to discuss these items. am continuing to complete the package for the sidetrack operation. I will have this package complete tomorrow and will send the package to you electronically for your review. will continue to work on the historical documents. I hope to have all information to complete the historical documents by 6/20/07. I enjoyed our visits last week and look forward to working with you. Sincerely yours, Eddie Wright Petroleum Engineers, Inc. Three Riverway, Suite 1500 Houston, TX 77056 Office Direct 713 - 479 -7070 Cell Phone 713 - 823 -7789 Email ewright @peiinc.com Content -Type: application/pdf A19 403 OS PP.pdf Content - Encoding: base64 Ahtna #1 -19 Final Procedure_6- 7- 07.pdf Content -Type: application/pdf Content - Encoding: base64 1 of 2 6/7/2007 1:41 PM • • Rutter and Wilbanks Corporation Ahtna #1 - 1 9A Plugback, Sidetrack and Test Project Summary 25 April 2007 M S Francisco — Houston, TX Ed Burrell- Schlumberger- Kenai, Alaska Eddie Wright — PEI — Houston, TX Revision 1 — 24 May 2007 Revision 2 — 7 June 2007 Revision 3 — 8 June 2007 Revision 4 — 9 June 2007 Page 1 of 28 1 • Workover Objective: Phase 1 — P &A existing perforations and plug back the well. Plug and abandon perforations at 4230 - 4250', 4382', and 4387' with a mechanical plug set at ±4220' and dump bail a minimum of 25' of cement on top. This abandonment is in accordance with 20 AAC 25.112, Well Plugging Requirements, Section C, Plugging of cased portions of a wellbore, Paragraph 1, concerning perforated intervals, Subpart E which states: "if the perforations are isolated from the open hole below, a mechanical ��` bridge plug set no more than 50 feet above the top of the perforated interval, and .... a minimum of 25 feet of cement placed on top of the plug with a dump bailer." Note: Attachment #1 is the Current Wellbore Schematic and Attachment #2 is the Proposed Plugback Wellbore Schematic. Phase 2 — Side track at ±4140' to a depth of ±4280' TVD 1 ji A. Begin cutting a window in the exiting 5" casing string at approximately 4,140' and finish window at approximately 4149', sidetrack and drill to a depth of <\.-\1 approximately 4,280' TVD, achieving a minimum of 10' of displacement from the �.k original hole at 4230' TVD, all utilizing coiled tubing unit, mud motors and under pressure. B. Flow test the well to ascertain reservoir fluids. ilk Note : Attachment #3 for the Proposed Side Track Wellbore Schematic. Phase 3 — Completion or P &A --i C A vtcckS.c -�5 sv `ca_ , 42414/4 tS To be determined by results of the flow test, reservoir fluids and discussions with Rutter and Wilbanks and partners. A completion operation envisions a production packer, tail pipe, packer seal assembly, coil tubing hanger, and coil tubing. Page 2 of 28 • • Current Condition: The original well, Athna #1 -19, was drilled to a total depth of 3,705'. The drill string became stuck. Fishing operations were unsuccessful and left a fish in the hole with top of fish at 1967'. The well was plugged back and bypassed to a depth of 4,640' where a 5" intermediate production casing was run and cemented at 4,639'. Drilling continued to 5,165' where a 3 -1/2" production liner was run and cemented on 6/25/05. Perforations from 4,674 - 5,084' were tested with no success in the summer of 2005. In 2006, attempts to re- complete the well utilizing a Perf Drill tool were unsuccessful after attempting to mill windows at 4,387' and 4,382'. By an amendment letter dated 10/18/06 to the AOGCC, a zone from 4,232- 4,250' was perforated and tested, but the well did not flow. The well did build pressure to 2,100 psig in 4 hours, but bled to 0 after 1/3 of a barrel flowback. On 10/25/06, a single joint of tubing was run below the tubing hanger and landed in the tubing spool to facilitate spotting a diesel pill at surface for freezing considerations and operations were suspended. This is shown in Attachment #1 for the Current Wellbore Schematic Reservoir Conditions: The zone of interest (4,230') was drilled with 19.4 ppg mud to offset the high pressure water zones shallower in the well under the 7" casing shoe at 1,914'. It is thought that this overbalance forced mud solids into the pore spaces and inhibited any production. Estimated pore pressure in the zone of interest is 18.3 ppg equating to 4,125 psi at 4,320'. Mud log indicates a drill rate increase from 5 fph to 10 fph at 4,320'. c icStc , OS . ) \-1 )2 , 0 Q C \S \`-'■ 3 ( ‘C ; ‘'-kls\Ve' 4_91 Page 3 of 28 • • Procedure: Revision 4 changes are indicated in BOLD to meet testing and verification requirements required by the AOGCC. Phase 1 — Isolate perforations per 20 AAC 25.112 Well Plugging Requirements, Part C — Plugging of cased portions of a wellborn, Paragraph 1 Perforated Intervals, - Subpart E. Note: Contact the AGOCC Inspectors Office 24 hours in advance at 907 - 659 -2714 by voice, 907 - 659 -2717 by fax, or 907 - 659 -3607 by pager to allow sufficient time for an inspector to be schedule to witness work. 1. Check all casing annulus and SITP pressures. 2. Rig up a flow back tank with a gas buster, if required. 3. Contact the AGOCC Inspectors Office 24 hours prior to starting this Step. Bleed off any pressure to tank. Monitor well to ensure well is dead. Record description of flowback fluids and gas. Shut in well for a 4 -hour pressure build up. Record pressure every 30 minutes. Based on testing in 2006, the well should have about 2100 psig SITP. The well should flow back less than one barrel of fluid. 4. Move in and rig up electric line and lubricator. Test lubricator to 5,000 psig. 5. Contact the AGOCC Inspectors Office 24 hours prior to starting this Step. Make gauge ring run to insure setting depth for bridge plug can be reached. During run, a Temperature Survey /CCUGR log may be run. Set a mechanical bridge plug at ±4220'. See Attachment #4 for the mechanical plug data and Attachment #5 for Cased Hole CBUCCUGR Log Section. 6. Contact the AGOCC Inspectors Office 24 hours prior to starting this Step. Make multiple bailer runs to dump a minimum of 25' of cement on top of bridge plug. Estimated top of cement may be between 4180- 4195'. Leave well shut in for sufficient time allowing cement to set. Collect and observe surface samples of cement. 7. Contact the AGOCC Inspectors Office 24 hours prior to starting this Step. Bleed off pressure and monitor well to ensure it is dead. Shut well and monitor pressure build up. f no pressure build up is noted in 3 -4 hours, continue with next step. <..ov4■�p \�r -c3 \`Z ©0 c. I t �-1 8. Nipple down the Christmas tree. Attachment #6 is a Schematic of the VetcoGray tree. 9. Rig up and pull tubing hanger and single joint of tubing. 10. Install pre- tested (from top) 5 1/8" 5K x 4 1/8" 5K tubing head, 2 ea. x 4 1/8" 5K valves, and 11" 10K x 4 -1/8" 5K adapter on top of tubing spool. Attachment #7 the proposed valves on the VetcoGray wellhead. Later, the VetcoGray tree will be assembled on top. 11. Contact the AGOCC Inspectors Office 24 hours prior to starting this Step. Run in with electric line & tag top of cement. Run GR/CCL log for tie -end to whip stock setting depth. 12. Rig down and release electric line. Page 4 of 28 • Phase 2 — Side track at ±4,140' to an approximate depth of 4,280' TVD 1. Prepare location for coiled tubing operations. —CS-c. 2. Mobilize 2 -3/8" coiled tubing unit. Attachment #8 is a listing of the vendor equipment and the 2 -3/8" coil tubing specifications. Attachment #9 is the BOPE layout. 3. Rig up 2 3/8" unit on wellhead and test BOPs to 5,000 psig. A coil tubing run may be required to establish correlation to PBTD. 4. Pick up and run 5" whipstock on coiled tubing per service company procedures. Attachment #10 is a schematic of the Baker Oil Tools Thru- Tubing, CT Mono - Bore RWS whipstock with dimensions. 5. Space out and set whipstock to start window at a depth of ±4,140'. 6. Pick up and run a straight hole motor, window mill, and dressing mill to mill a window in 5" casing off of whip stock. Estimated length of window is ±8.9'. a. Directional control of the sidetrack is not required. A general directional plot for two plans is shown in Attachment #11. Availability of downhole motors and bent housing will determine the actual path. b. Take pressure readings to evaluate pump pressure and back pressure effects. Establish flow rates at approximately one barrel per minute increments. Record pump pressure with back pressure increments of 250 psig from zero to 750 psig as measured at the discharge manifold choke. c. After window has been cut, pullback into casing, shut in well and monitor SITP to establish a BHP. d. Continue to mill approximately 10' of new formation. Pullback into casing, shut in well and monitor SITP to establish a BHP. e. Pressure up and conduct a leak off test to a 20 ppg EMW. Increase the pressure in 0.25 bbl increments and plot pressure. When pressure departs from straight line, contact Mick Francisco (713- 301 -2216) and Eddie Wright (713- 823 -7789) in Houston to discuss further operations. i. If the drilling fluid weighs 9.5 ppg and hole depth is 4150' TVD, then the maximum test pressure is 2,266 psig. f. Pull out of hole and measure window mill and reaming mill. If mill is under gauge, run a motor and dressing mill to dress window. Page 5 of 28 • 7. Run a bent - housing motor and drilling assembly and continue drilling the well to a depth of approximately 4,280' TVD per directional plan. a. Circulate minimal weight drilling fluid to minimize formation invasion. b. During drilling operations, pullback into casing and evaluate formation pressure increase by shut in well and monitor SITP to establish a BHP. c. Maintain sufficient back pressure at surface to balance formation pressure. Increase drilling fluid weight when back pressure exceeds 1,000 psig or when back pressure causes drilling problems with downhole motor. d. Evaluate and report formation pressure build up and estimated bottom hole pressures. e. Attachment #12 has copies of log sections from the Open Hole Log and Mud Log. 8. Circulate hole clean. 9. Pull coil out of hole. 10. Rig up flowback equipment. Equipment may include an open top tank and gas buster for initial testing. 11. Open well and flow to tank to verify formation fluids. If sufficient gas is shown, flow gas through flare line to estimate gas flow and possibly obtain samples. Note: Capacity of 5" at 4,250' is approximately 70.3 barrels. 12. Shut well in for pressure build up. Estimate BHP and EMW. Note: DO NOT KILL WELL! 13. Further activities will be established after reservoir fluids are determined. Phase 3 — Completion or P &A Procedures will be developed pending results of flowback. Page 6 of 28 • • Attachment #1 - Current Wellbore Schematic RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19 API No.: 50-099. 50005.00 RKB 2037.0 18.3 Current Wellbore Schematic GL 2018.7 10 Depth Casing/Cement Completion: 2-716' 6.511 L -80 EUE Tubing L L78 ' BGL 13 -3/8" 88# L -80 Conductor Shoe Squeezed with 18.3 bbls 12 -114" 1,226 9-518" 401 L -80 BTC Surface 20 bbls Permaforst & Class G 8-112" 1,915 7" 261« L-80 BTC Intermediate Welbore Fluid Above Packer: 66 bbls G to surface 9.0 ppg KCL brine with oxygen scavenger and corrosion inhibitor. Top 20' is diesel for freeze protection. 3,200 Top of cement (CBL) E-Line Perfs: 4232 4250 Dril Perf Tool Channel: 4382 4387 — — Top of cement 4.536 (placed with dump bailer) 4,577 Top of 3 -112" Liner Cgi ls 4,835 Weatherford E -IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L-80 STL Intermediate Perforations: 4674 4680 = 53 bbls Class G 4922 4940 4923 4929 4932 4938 = 5010 5020 5076 5084 = _ 5,099 PBTD / _ \ 5,165 3-1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 Page 7 of 28 • • Attachment #2 — Proposed Plugback Wellbore Schematic RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19 API No.: 50-099. 50005 -00 Proposed Plugback Wellbore Schematic RKB 2037.0 18.3 6/6107 GL 2018.7 Depth Casing+Cement Completion: 2-7/8' 6.5# L -80 EU E Tubing j LLL 78' BGL 13 -3r8" 68# L -80 Conductor Shoe Squeezed with 18.3 bbls 12 -114" 1,226 9.5/'8" 40# L -'I BTC Surface 20 bbls Permaforst & Class G 8-1/2" 1,915 7" 26# L-80 BTC Intermediate Wellbore Fluid Above Packer: 66 bbls Class G to surface 9.0 ppg KCL brine with oxygen scavenger and corrosion inhibitor. Top 23' is diesel for freeze protection. 3,200 Top of cement (CBL) 4,195 TOC - placed with dump bailer 4,220 Mechanical Plug E-Line Perfs: 4232 4250 m. Drill Perf Tod Channel: 4382 4387 — — Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" liner 41\42eLi 4,635 Weatherford E-IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L-80 STL Intermediate Perforations: 4674 4680 = = 53 bbls Class G 4922 4940 4923 4929 = °- 4932 4938 5010 5020 5076 5084 5,099 PBTD 5,165 3-1/2" 8.8 L-80 STL Prod. Liner Total Depth (MD 8 TVD) 5,165 Page 8 of 28 • Attachment #3 — Proposed Side Track Wellbore Schematic RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19A API No.: 50-099 - 53335 -00 Proposed Side Track Wellbore Schematic RKB 2037.0 18.3 6/10t7 GL 2018.7 Depth Casing/Cement Completion: 2 -718" 6.5# L -80 EUE Tubing 78' BGL 13 -3/8' 68* L -80 Conductor Shoe ed with 183 bbls 12 -114' 1,226 9-5/8' 40# L -80 BTC Surface 20 bbls Pormaforst di Class G 8-112' 1,915 7" 26# L -80 BTC Intsrmcdato W©Iboro Fluid Above Packer: 66 bbls Class G to surface 9.0 ppg KCL brine with oxygen scavenger and corrosion inhibitor. Top 20' is diesel for 3,200 Top of cam nt (CBL) freeze protection. Top of Whip Stock at 4129' ±4.140 Top of Window Whip Stock Anchor at ±4,153' ±4,149 Bottom of Window TOC - placed w1 dump bailor 4180 -4195 Mechanical Plug 4,220 Evaluate zone ±4,230- 4,250' E -Line Perfs: 4232 4250 Drill Pert Tool Charnel: 4382 4387 = End of Side track at ±4,280' Top of cement 4,536 (placed with dump baler) 4,577 Tap of 3-112' Liner 4,635 Weatherford E -IRBP ►�+r ` (Inflatable Rot BP) 4,639 5" 17.8# L -80 STL Intermediate Perforations: 4674 4680 53 bbls CI G 4922 4940 4923 4929 4932 4938 5010 5020 5076 5084 5,099 PBTD 5,165 3-1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 Page 9 of 28 • • Attachment #4 — Mechanical Set Plug PosiSet Plug Summary Schlumberger Description The PostSet* plugs are elastomerle- anchored plugs run through tubing and set in PosiSet Meg Swam' casing to plug off non- productive zones. Expansion ratios are typically 3:1. Physical characteristics are as listed on page two. Features • Positive anchoring with upper and lower giro • One-day simple operation 1 l • Accurate depth control • Non - explosive deployment ▪ Set Deviated holes including horizontal • Open hole .�, r. • In perforations or screens AU Plug Setting Sequence ' N II il _ Into mediate Aiges I F1& g3et and l 1easFd I M I ,a I Rumng Inv rmediate Page 10 of 28 III • i Units Kr/ Dina Casino sizefinl. 4 5 Vs 74ie !4i Cash! inside duvets! mega iin.l 3.50/'4.311 4.00/4.52 4.505.02 6.50,7.02 8.43;1101 PosiSet plug number H345225 H345226 H345042 H40530 1345700 Wings Temperat<re i fr CI 340/171 34071 300/14g 275135 275/135 Pressure !psi) 1000 1000 500 1000 503 Alining outside diameter In]. 1'Vis 1 1 2'A 2 Minimum restriction tin.) 1.77 1.77 127 2.18 2.75 Seal length i in.l A 2.7 2.5 9 4.1 55 Distance tool bcttcrn to seal 'in.' B &1 81 8.1 22 21 Set irpertcrations yes as yes yes yes Set in screen yes yB2 yes ya5 yes Set in cross flow yes yes up only As yes Set in open hde yes t yes t yes t yE t yes t Anther slip force I'M' 25,000 251000 25,000 5101000 90,000 Anchor to anchor lin.I C 11.1 109 14.5 22 21 Set length without cement i in 1 0 39 39 31 476 31,8 Cement recanmended yes yes NA yes yes Odrer Properties Delivery Iagth lin.j 90 90 130 126 145 Airweig`rtfbm) 28 28 37 96 67 MPSU,4A yes yes yes yon no MPSUc4 sot al rsr y'es yes yes yon As Seelig time iappren.l min 17 17 60 60 90 Shelf life C. 80F Ns 4 4 2 2 2 PosiSel Plug Number H345225 H345226 H345042 H4C6320 H345700 t Hole rnr4 IN cin1Q kiwi Fob dinaior requied Prawn retry net Ti agif I]ifvertid prom= rs drgntkrrr upcn fnmsti n st wgth 'Sapp curl; scot Page 11 of 28 , . S • Attachment #5 — Cased Hole Log Section with CBL/CCL/GR • Schlumberger I . ------,.:- , , RUTTER AND WI LBANKS CORPORATION • • . , c., AHTNA NO, 1-19 ST#1 F , : - .1: - .1 COPPER RIVER BASIN WILDCAT a'.•:: VALDEZ CORDOVA - . Sate ALASKA SLIM CEMENT MAPPING T001 CBL-VDL w/ CEMENT MAP IMAGE :I. no. ," ---• -:- •;; ,.. c. - - . - . _ .. -1- _ ..._.... ..--,, / 1 4r4 44 .' " eit (...APO F r:, • ' :* - - ‘ ° , • ;2 ; . ,.• - ,-.. X z•• 5271267 ...-29642r ?ONE: .;,. I- I < r 3 . Pe.relati.a.1 aaturr: . ,;jir-Ipt.. 1 .1 -': .47:- _ :-.1 .., '' 7 f:- 5 - o.. 1 • :O. ? *.) c- , ri Cc • • • P - I Log Measured : Kr- LIN' i- 11 --- P' ao--I.T. - ,.1.7, 11 , , I prillong Mer.rastaed From Kr.7: I RJR : *.Nr:. _ .. . ,. , yr . A . - . . Api Sera' !..1..,:„. 7.›..-...;,7.0- I •.,,,,... !I -7,......7.,„e If . • ' ; .--". ...': 50 4 7,.;(115 X - — . . . i ONE jerp1.11 Drillvr I 46.1t) ft Sc hiun Elepth '; 4515 .f _ &Atom 1ogInterva: '5O' I! ..1 ... ._ f op1.09 Interval 1CX10 tt . . _ Creiing r Kola Type 1 POLYMER ,f1ANNA i1 IN Density 194 Ibni?gal _ ..__ .... . _ _ Fti.P43 i Wei 011 ' • BififiAgINGII 8 1,4iNG . , Bit Size 1 6 125 ;IP trOtr. ign?ft ■ TO r 4e47H 15 Ibm 41 Grade F!... Ott To 464711 • _ _... . _. _ . .. _ .. . . Maxi %urn Re•:-.>064 I ernperaturec. i 91 degF 191 92 Logger On Ant'arr Time .. 9-Jun-2305 16:0D Unit Nutnet I. xaori 1 1i1a. I KENAI, AK .. . ..___ Recorded By ETHAN CHAB _ ORA Witnessed 6 MR.. JOHN NICHOLSON Page 12 of 28 1 . . 111 III CBL-VOL licklunener MAIN PASS MICKI-',[14,Hnl i Lctm paw: RUTTER AND WILBANKS CORPORATION Well: AHTNA NO. 1.19 STS 1 Input DLIS Files DEFAULT SCPAT_PSP . 014L UP FN:13 PRODUCER 04-Jim 2005 17:56 4533.5 FT 1515.6 FT Output DLIS Files DEFAULT SCMTPSP015PUP FN;14 PRODUCER 09 don 2005 19,01 4433.5 FT 1540,0 FT OP System Version: 13C0-300 SCMT-BB 13C0.300 PIPT.A n I 3C0-300 PIP SUPdlMailY 1:31Time Mark Every 00 S - - •- " . Tool! tot. Drag From D3T to BTIA Cable Dreg GoodRood From STIA From AC131 10 GOSO to STIT Stuck Stretch Good Bond (G0130) (STD) 1 0 (MV) 10 fit (F) 50; DleCilm last i Transit TIM ed ca. , Fluid Compensated CM Amplitude (TT) (COE 400 (US) 900 I (COLD) lb. (MV) D 100' , , . ---- Tension Mln Amplitude PA Gamma Roy (GR) , (TENS) ' COL AmplIttMe (CF0.) C =11:10.011191.•■ 0 (GAPP) 1001 Ain 0 (MV) 10 VOL VarlabliOnally (VOL) ,3000 0 200 (US) 121 — - — i 1 - 1 , 1 ■ .: • ; - 1 : MAIN PASS - 0 PS! I i 0 i I 1 ', • I : 1 - 1H- Page 13 of 28 _. __ _s, — - • ..,r....o= ...z:�.... ...r ra:�:+c**,+n!'.__ _,.. _.; ac;,:,,_• r}. xc` r. -rs -.. ...y .....�. �._.v._ ,.,..�......,.,. w- .r.,= ,.- .r- rwww.v: • .. _. •- . •,....- - ....:. ., ... .. '1f�a..7G ,i.n.::•ui"'�w ,...�,• y,* 'Sr .:• w.w:Ae - � c -+• � _ w++! *Y^S #`T�'J�RQli9i .. ,•. - R ra�>k!WW*^�^'•?^'^+" -,. ... ,,. ., ..4 ,+.Y• ..manna. .. - - . �. �.«..... ..v.:.z.__.iaa- .+..�- , rsar+4 , -.� : ..n•,�.., ...mss-- ,-- •- •-- •+— �-- .- :— . - zmw.: c..�+. x.-.. __._. .... I , • i 1 • • I ... 1 ' I i i ., , v---,-/,'"\- I l � 11 I 1 co ---7-1", �.�,. ; . # { _ a _ filler �� � j'I 111 1 i ;; i ' ;' , _ 1tI 1 ' 11111'! I 1 1 , I t li, ,, x ; 1; . 1. 1 1',II '. a) ;_ � • 0- as 'S 3� — � , ; t I 1 { J I i . .- I i J } 1 1 1 MI 111111 y i i 1 .1 X1 ®.11011 mum i I I I1 i I Ii A ' ...- - u t -..,- 1 ' I --•- - ._,..4 ! I . _�._•....- ........ ..... - .. _ �. + , 4 • I I i, -+ ,- - a-- i ' • I _-4-^h ...I- is 4- 1 1 { i' 3 i i) 1 1 1 1 • i - I j I { d . ._.._. - • ' . 1 'a._ . 11111111 ' 1 I E I I i t I l �11i II 1 . _ i 1 . 1A1 `-T � ' ' I • i me i • • Attachment #6 — Current VetcoGray Wellhead and Tree -- Wig 00 Fes. itS %4 ac S . t ... / MU aC f - 40.. -1 iii ''''''t. . "1"'-'.- [..fit 111111 V i r ' 4-l3ff$ MD ,a l II 9a -vx' 'lL i+/ -„...... „. y i ".ti '8-91,1$ 101 IM I all 0 t l it ION . .. le i , '- ►. .! ' 'I II . Ns- --1 /a.. I I , ,L .., , N 1 El if I .■":‘,W,...'w g � �� , • ,..,,..,,, :. ,..:,,, hi II I. ... .1 WIl ., a. MI Ng 320R' ' i : 32.41}' IMO .: P. "a u soy► • sir 1 1 1, it 1 ,� - "II! � i-IIL , i .1 ,' . 'S. i Si INIA11, a " — — L.:IN, ..m i . . 32.00 ' : 11 ION I 3l 1,2` 25 --1/4' mil . �' 1 1 sE 181 A i LtA•14 t I # g i po ' . ip ri t.....„ Si 1s III Iw ! ati' :d ,. !lb._ 1 �..; a ,. r!ris Csa , iii, . OD MG a_mr Op I .- I F 9.119 09 3' OD C!+7± . . ALL nretEnsmms KRE AAPFDX�IATC — a. TOO GOAT SYSTS�19 OrOwnisma 4 veteog ra ka° 3'e x 9 -518 X 7 X$ X 2-7/9 no. W.VM MSP ASSEMBLY a .vaw . E.►i - 7•,7,.41 , � � '�'i. - , ,, .:.. :.s ...c _ Ste - 54xe Page 15 of 28 , . • • Attachment #7 — VetcoGray Tree with Proposed dual 4-1/8" 5K Valves -a..=-- , :•.....,....;= ...,.:6 7 : .1. r . D;i2=E;'''' —,— pic...qc :■ ''',A' -:; .74i • F.. : =.1.4 1411.' 7:‘.. ItrIli I { .....■0......... • ---- ; 7 7, * -.: - ' 5 7:" •..„ ---+"---* —_-_-_-- , . • ■ i , —,... .-- ,,.......,..,, ''',-_, - _• , • - - -7-1 — E--.4;5r:Nc L-,.;,-,:-.. -....1 -1-7- ........ . .L. r lif Irif.. I ''' . : ' e I - '1 II= 1 I ( ,......1 . .. ' :LI ■ , . ...,___. Tea & ' a Vete° Gray ...... .. _ _ _ _ ■ ' pi 11,0 BY 7 Pict , ..1 .- T - E.1. i. ,,;,,,,: , 7. .,..'... '''..:"_ V:A.f k. . : sP-,6236 . 1 Page 16 of 28 • Attachment #8 - Schlumberger CTU Equipment List & 2 -3/8" Coil Tubing Specification 2 318" CINLED TUBING Set whipstock, mill window and &ill -60 open hole 2 CT 8� 1071 : 0 5 Day unit, 8 tur m iviu rn, per clay Ilarxt: 107133 :1 eo Hr Unit adcitIcria hoar (land: 10713E930 1 9030 P. Pipe Rurnhg DP- per run, 1t 10713E030 0 2 Ea 2,3+' Die Dharcie over 1 cycle 1071391€10 Ea hltttmurn , per clay 107139730 1 Ea - _ Head or Plpe :version, 1071.= :r 1 et r Charge. _ 3at1 & Jrroad, per lift CT "i ax. P u Services: 1018.030 5 Day Fluid Pub Less Mall 1i11P (3 hr. mini ) 102CD 1 and trildarl urft, par job 10E03,3030 5 Day Basket, per day InchAles 'at' a 2' Iron 10 • ;: 0 ED Hr Fluid Pump Less 'hal 200 HI-1P, onal , rs, per hr. 10 90030 1 Day ferogen Unit r,9 hr rnlnirrurr, per day;• 10 1000 1 :ay 2000 gx. Tank, per (My 10 v r 1 Job 1 , ' LAMM pti Personnel: 1031 'ie0 123 Hr Service Su ter, Land, per trr t3 hr ) 10311 r i Hr Service Te 1x1 l- LaTI. per IT (8 hr rnlnl ;) 1031217 1 E Hr Crew Travel. per IT 103107001 5 Day .. . :.: Job rater, per dry 1031210000 Ea - " enoe, pet clay , per mart Page 17 of 28 • EiI • ' 4 : 11E045030 1 Job ColCAT 1030E .40 5 Day - ma t 112#4, per r y 1O72Ei 5 Day 3 1116" or4 UM' ehA FLIY# Cross per dal 1020E24320 5 Day In - Stand. per day 103042021 5 Day 3 tt1E ca 1.16" 10.1 or 9/ 4 4 per day, per 1 103017030 5 Day Hydratilo Crete. per day 1072E5030 5 Dai 2 1 1E" or 4 116' 10M . ; 4- per Oa)! (CAT 2) Bakal Hole As/40mb ty: TCOLS 1 Job Wiloistoot ard rrMIng assently HC 1 EA DrIlIrrg br. Ste 1 EA Drill motors E:x ici, :e: 10304,101 2 = 3 IR rig C-Laskets 11 EP o greater, e 10203700 2 E3 sipper Elenerl Insert. rrIr 1 per well 10223;14 1 `=3 Ree Swirei Pearl; 1070370E0 2 Ea 3 11E" or 4 1(16" CaLal Expendaties, per Job w 443 21001 Me Mleage on. -, egJI - 4 I Il 14r fige Mleage PckLps 0 1 Job Fichvt.- eqUpTel P02-CO 3 303 oaf N 4 - (art : J313 20 gal J313 - Fr! u Reouplp Agern MI 302 BEN_ WIWI; MJd system Page 18 of 28 • ID pRPRECISION I° COIL TUBING DATA 2 -3 /S" o.D. TE Available Grades: HS -90 CM OR HS -90 WTM (CONTINL :OUSLY- MILLED TUBING) (BUTT - WELDED TUBE SECTIONS) DIMENSIONS ' TUBE BODY LOAD ' INTERNAL (Inches) Nominal (Lbs.) PRESSURE (psi) O.D. Wall Wall I.D. Weight Yield Tensile HydroTest Internal Specified Specified Minimum Calculated Lbs. / ft. Minimum Minimum 90% Yield Min 2.375 0.125 0.118 2.125 3.011 79.500 85 .7[x) 8,000 8900 2.375 0.134 0.128 2,107 3.215 84,910 91,500 8,700 9,600 2,375 0.145 0.138 2,0155 3.162 91,400 98,500 9,300 10,400 2.375 0.156 0,148 2.063 3.706 97,900 105,500 10,000 11,100 2.375 0.175 0.167 2.025 4,122 11 =.900 117,100 11,200 12,500 2.375 0.190 0.180 1.995 4.445 - 117.400 - 126,500 12.100 13,400 Tube Body Load: Yield & Tensile Minimum calculated on Specified Wall. Hydro Test: Test Pressure Value is 909E of the Minimum Internal Yield Pressure Rating. Internal Yield: Internal Pressure to cause yielding using Minimum Yield Strength and Minimum Wall Thickness. Maximum Working Pressure is a function of tube condition and is determined by Use user. DIMENSIONS TUBING AREA TORSIONAL INTERNAL EXTERNAL (Inches) (sq. in.) YIELD CAPACITY DISPLACEMENT 0.D. Wall w/ Wall Internal (ft. / lbs.) per 1000 ft. per 1000 ft. S ecified Minimum Min. Min. Yield Ultimate Gallons Barrels Gallons Barrels 2.375 0.118 0.837 3,593 3,894 4,090 184,23 4.39 23014 5.48 2.375 j 0.128 0,904 3.527 4,170 4,398 181.13 4.31 230,14 5.48 2.375 0.138 0,970 3.460 4,438 4,700 177.37 4.22 230.14 5.48 2.375 0,148 1.035 3.395 4,699 4,997 173.64 4.13 230.14 5.48 2.375 0.167 1.158 3,271 5,175 5,545 167.31 3.98 230.14 5.48 2.375 0.180 1.241 3.189 5,485 5,908 162.38 3.87 230.14 5.48 Torque Values Calculated Using Minimum Wall Thickness and Minimum Yield Strength. Other siuslwall thickness available on request. (NOTE: ABOVE DATA IS FOR NEW TUBING AT SPECIFIED MINIMUM STRENGTHS.) Page 19 of 28 • • - PRECISION MATERIAL SPECIFICATIONS - HS-9O'm TUBE TECHNOLOGf HS-90 CM (CONTINUOUSLY MILLED TUBING) HS-90 W (BUTT WELDED TUBE SECTIONS) PHYSICAL PROPERTIES: MINIMUM YIELD STRENGTH - 90, PST MINIMUM SILE STREN 97,1 PSI MINIMUM ELONGATION - 25% MAXIMUM HARDNESS - 22C ROCKWELL •J__MI u ITI - CARBON 0.10 - 0.15 RANGE MANGANESE 0.60 - 0.90 RANGE PHOSPHORUS 0.025 MAX SULFUR 0.005 MAX SILICON 0.25 - 0.40 RANGE CHROMIUM 0.55 - 0.70 RANGE COPPER 0.20 - 0.44) RANGE ALUMINUM 0.040 MAX NICKEL 0.14 - 0.30 RANGE MOLYBDENUM 0.10 - 0.15 RANGE STF.F.1 ALLOY DESCRIPTION: A-606 Type 4, Molly Page 20 of 28 • S Attachment #9 - BOP Equipment Layout for the CTU .__M 1 ‘ - - ‘ Ar 2sa # Luwt - L p15 A .�t.. r 3 Iv .- RIP 3. 1 .1 f, "a t _ . MS li 111111111111111 .Sr.. I rr c -_ a If.sliCiS 5+41vEA .6 01 4 , 044 dl II M Page 21 of 28 • IIII III 1 1 Attachment #10 — Whipstock -- Baker Thru-tubing Style Baker Thru-Tubing Volta Baker CT Mono-Bore RWS Raker Oil 'I oats We Glenalan Date: Co Marl_ __ -, X to 2 318' Reg pl.__ 9.11 a 1.00 - ID ... ' ...... _____. II Baker #10 'X Hydraulic Top Collar -5/./...74/ • 2.7000 1 5 eel — I Setting Sleeve .._ ... . Whipstock Setting Depth I ., -0 3635' 00 (DAL of sleeve 2 801 1 i ■ ■. 1 Bottom Collar <I1‘ a ' i 1 i 8.150' I RA T40 % i I . Whipstock Orientation M€WS 0 Degrees I 'fro y Left Right .0er , 1 i I 12.44' I i la*, CHI Teals I raosia-Oors 1 RVIMI 1 . 4 Ilir i OAL 4144424882 N 18.42' I 12.42' i * Critical Dimensions for Window Exit Pinch Point ----OA,' Mid Point ----TA' 40 4e0 4 4 ,4 1 7 Final Exit -----eir So/ Se 9 1 - 3.825" 00 1 I 1144Msg Rods I DIRsor 13441.140 1 .141' TP.:1 OP 1Spis 114,4114ip Rod Body OD i' UPPIsr 114211411 Rad 4141' Long mbe $mithy Plod !Err Dad, OD Lewin' sawn. Rod RAW Lamm jil 1. 11.1 W 4r Page 22 of 28 • • • Attachment #11 — Directional Plot and Plans Schlumberger -4C -23 C .] 4C r� wined KOP Yc 16111 4 43 Jml.�dfiw.. 4147 4. 6,3 4157 4 I r 4137 4200 4207 M S 8 4230 4:27 4240 4247 4:5 ] .... 4257 Mna , a :T : KIP 4411.1 IMO M»'a 1 Sr 2 !COP rfMSW 'S10D 4:57 4253 m n -40 - a 20 4C Vertical Seattle tag Allyn - 0', Scam - 1(In1:20(11 ) Origin - 0 Nt -S, D EI-V Page 23 of 28 • • Ahtna 1.19A 10/100 Proposal Sc hiumberger New Ca! ,ire 8, 2607 eine! CU Corrgrtrion Meteor liriwn C.ndare i h Oat Ye€ed Ordion Atim& C.7 Fied Geed awe! MOM Mae Crew. 1/4 c" :0:tE4A0D0t e� Gamic Genic Pod TYDReereeeDin Ka Met Ge lee 1 I 7110 Fervent 8erriee 1506.011 retei a 4o Wen Sea level detrme: 1 -19 sr 210 111e12FY i Collegian eine Wee Care Ahte 1.19 ST MY 41,40M 10-160 i Ids fl 20:7 -oral Fire �{ T00010100; P e r a k : 1 5.143•2 ?i.43 t; 2559 i D X5 Waimea oq Arid Coettirme woos minion Die Lmrim Later¢ a webs reekrioe Yodel coda Tit Norm Revere Aria common Teel car Yap Moro: -. Ti Aue: Ord tale Fodor omG Cooaoir_ Reamed To: 4! tied Cameo N d eke= Peke a elr a ND vow' RR Bs O Ol Oreollool Mike Too Fee (R) (e a: ?dq1 i *.i :R) AI (n: IR) (0101 (4 Mil trills roc t 4129. UO3 0:36 2529. 41313 3. 0 0.30" HT 0D C. KG'F 8 0'130 4140.00 2021 0.70 2640.00 414073 119 C. 19 0.00 HS 18.19 0.00 415100 300 0.00 2649.99 4149:93 3.63 3.53 0.00 HS 1000 0.28 4233.00 600 0.00 2639.74 4199.74 5.42 5.42 0.00 HS 1000 1.64 4233.00 11.00 0.00 2 7 2 9 . 3 3 4229 33 10.37 13.37 0.00 MS 1 1 2.06 :00 1 3.03 0.30 2743.69 4248:99 14.63 1453 020 HS 10 03 2.28 4281.43 16.14 0.30 2779.30 4279 33 2243 .'"►4.3 (:70 - 10.07 2.56 Schiumberger p Ahtna 1 -19A 151100 Pro osal 11epaR Car .Are 6 247 e.eer a Eta Commas Yetlot liri un Comm dart teem Meow Fame 0.MC• Fitt Greic 4Irrirg maim swim Wiwi lye r tE t moon f tic Generic Aig t Geeic Pod T10 Relbeeae Deem es Mel: Gees Ydel M' Regrew Barrier 159102 rdei t 43 Lien Sea Lend Swett Ahem 1 -19 ST 210 1.1112 1Pe: melee) Ciliation level Made) Gate A4ihe 1 .19 r 2 KY 4140hd 15.190 i Jade 6 20017 Tad Fitl tlhegttr Tau I CO r erpdie. 23553' 317812 122E5 00 737 mania olt Arad Coodilye totem Deletion ode Lemke LAW* Ned•eli Deoloafiao Imaeon 4ri0 4E a'U[ tlorla Reticle Aria tleoFepewe MaC Tatm Car Ids "''' -The Moan: Oriel lays Fritr CooeOnyer hater mad To: wei Fled Came ikaee M Fame eeLaeaTe TMI Aerial Ole 91 Ored DUI 0e ' ei Cora Severe Too; Fa IRI lier 41ee1 itI 4R1 it' (RI 121 10411 (407324 R op 4129: 0 0 0:76 2529. 4129. 1ir 0 0.00 Ham`` 033 0. KOF 81y 10130 4140.00 207 0.90 2640 4140:03 0.19 019 033 HS 1519 3.00 415100 3. 50 010 2549.99 4149.99 057 0.67 0.00 HS 1500 137 .00 1.03 0.00 2699.55 4199,55 8.96 6.93 0.00 HS 15.03 1.69 4214.50 '3.19 0.00 271373 4213.73 17.01 10.01 0.00 HS 1503 2.12 4253.00 1850 O.70 2747.87 4247 97 19.70 19.70 0.30 HS 15_01 2.56 TO 4283.68 23.55 0.70 27'79.30 4279:30 31.78 31.73 033 - 15103 2.57 Page 24 of 28 . . • li t Attachment #12 - Logs Sections from Open Hole and Mud Log IIIIIIIIIIII„,riIIIIIIIIII_ 1 ,,.. :. ! z x g : X . X : .r.: 7., -7-7_ i . 0 n -4 gs 5e 2.• X) e :•0 LI W g g C 2 ii ; i• it , e F etc: C:DF PER RIVER BASIN . .411,_DC. so ( 7 6 .1 0 , ..,: Er*1600 14 2 C. iii 3 5 Q .13 -ocatar: Se,: 19. T4N-R31N GRIM a a (D E i ./3 c CE II E .91 tL Ricg tZ C •• 'V ANTNA NO 1-10 ST** (C) a) -d f z - , Fe ... - ..el: i 6 ... 6 — t , sp ik, re r: . ::),i ary RUTTER AND WILBANKS CCP • • = s< - = _CCATION AI A 1:i 7 13 1 "0 X 1%) Cr) 0) - 1 0 < 0 > 73 . a 6 II TI _ C U' --I v . 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MI I I I ..R.7 I.,,c 1.11,41.1.LLL t , ip , p Emos 2 (OHMM) 200 ..11 kli. • SP (SP) — - 2 0 A1T-H 30 Inch Investigation (AHT30) Tension (TENS) 2 (MV) - 2 (OHMM) 200 3000 (LBF) (.0 C omputed Micro Alpha Processed Neutron Porosity HILT Caliper (HCALI Ncirmal _ AIT-H 20 Inch Investigation lAHT20) ANPORL 3 (IN) 13 IHMNO) 2 (OHMM) 200 0.6 (WV) - 0 - (OHNIM) 710 0 Computed Micro Gamma Ray (GR) _ Inverse AIT-H 90 Inch Investigation (AHT913)_ Delta-T (DT) n (GAPI) 12l• 1HMIN) 2 (011MM) 200 150 (USW) 50 (011MM) 40 0 Area Bit Size (BS) From AIT-H 10 Inch Investigation (AHT10) Std. Res. Density Porosity (DPHZ) 3 (IN) 13 HMNO to 2 (OHMM) 200 0.6 (WV) 0 .., 1 MAIN PASS I I I f 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I O 1 , I 1 I 1 I 1 ) 1 Page 25 of 28 11111111111111111M11111111111•11111111111111111111 111111111111111111 1►)iii311111i1111n111111 111111111!!1!! !1!►. 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INC_ horizon - wel loggin!g.com I Abbreviations CCNParilr Rutter and wilbanks Corp. WELL Ahtna 1 -19 ST1 CO crculate at _C{.STION 2224' FSL, 1139' FEL Ltir lagged after Tr?p Sec. 19, T4N-13 UM C5 Connection Gas 4n viper Gas x; 527637, Y= 2964256, Zone 1 7. Trip Gas ELEVATION [B: 2037', a: 2013.7` $•s Surety GAS FIELC Copper Rivet Basin wildcat !a no Returns COSY valdez Cordova Borough, Alaska se tier► Bit nR 4iper Run :API ND. 50 - 099 - 20OOS rrCB Origin: CO 8 t ( SPX DATE march 3, 2005 PP Ptn Pressure LCOGIJG DATES Nay 9, 2005 -June 22, 2005 5 P Strokes Per Minute LOGGING DEPTH 1960' t0 5165' a1 A+11 out of molt L: Last circulation CO. 5 EOLOGIS' COMPANY Msh John Nicholso1, pave Morris Symbo CO Nabors blasts Drilling R:G Mi.. 129 °MIKAN GNBBRO 'walk I M,D COMPANY MI 941,C0 f' -AS VO`Cc~` �P C L 1TE TYPE Pol ymer / ran�ethin ►F= Min PC.L TE I>r- AT#IITE Nil EMT SCRIST -SHA1F LCGGD G GEDLCG :STS Doug Milhan, Neil Peterson, El'AU C ALT ©5ERANTr.NE tSALT Bernie Leas 6 :, a ®MARBLE =.4X/I RITE I 'TZ IITITE VREPARPHICS =P1> & CLAM srr SIZE 6.125" from ;d90' to 4640' i) Ili ®SLATE ICLAYSTONE 4.125" from 4440' to 5165' � IACIT€ ® GNEISS =CLAY FELSI SIL DIRE 1 BQUART2ITE aSILTSTCNE Ea +t • • CdERT CIRENf w-- ;FrT?:USTICS ►•26L1SSY CHERT raSMC5TCNE CISLNG 13, 375' Conductor at 93' ®IUFF YSTAL MAUL 01E17 SIC 9.625r at L23' ®1JIFF-LITHIC MCI Cr r J SiELL FRAYS ' + II. ► - LINESTCItE tv OWN 7 - at 1916' E3 + TZ DIORITE _ w 0OLO5Ti1HE L PAECCIA 5" at 4639' r :.. ,,+PETE �C y1,�� TES CE � O y EN6li� �� A I TE Ft-1 9"' r lN0.L ..: : :.9AI TE M}H CA LIBRAT:ON: 1%MEMO 0N7VALEIICE • Las aWLTS Drill Rate Lithology' Int. Gases Ch- oalatograph Remarks ern et. Li th '14 k+7 M<<n - Orll Me3,1rsak� Cwneie Et►u� lure '*t al ilt Coe Pps Cos 7 rp.uw 30 10 14 Mk SOk 25k 20 47 6C LC IX IMO 3+0t 10Ok _ - k tr ,„ all pas trent* Ceg.,29.1 Page 27 of 28 1 ■^AOD 00 • • • dk gry -btk it dries t/ ■ ^_1700 1 qq ry; trn;1 -n1lky qtz. fspr if a/ O45 1,, morman00 -0a w a; t Kul ,rfabd l$thic (rags; coal, volt; • • ■_13 0 0 • • i • t tr orng.grn• vfn -fn; rnd -sbrnd; ^fl+ owl srtd; grdg t /fn- wadi, sbang - LJg0t1 • •'. * 9490' r or sprtd/ uneonsl, ace ' 0 4 0n�f0 talc c slot; tr-cost shod/ OD 017 rhonbadrl calct xis, pyr sphrs/ r + " 01910P1300 0_• • •• mpg(, lot: rr orltgsh Toss; 0100 ■ 0 • • • • aft Golub pl brn -pry clay, was . A 017012 0.••• : — )Kr d ''thICr: 'ntr RMI a ■ t70001HIII • • • • . ¢r ;p .. abd ter) r 'r am I- NIM1170Qp a1 Of" ' Gus PH 7d na nOa ; wed gry, It yry. pct • istialAarinatICIIEZI, Cl au MPS s h to mom::** fns -r. ah; fri. -awd fired wk a v •1 ::r - 13 0000 ... spotty Ale rxnc tr arnq foss; •,x' a.m.:. g ■ . 0g •4.:13 • .. l gen as t raps /thin stringers, ■. ^nn[[�� gOrw II - ^ihd all 11thiti I s_a; bik, clr -wht, p1 grn, ••n0 nl1DGt�4 ernq, slsd -cr dk 1104: vin -fn, r anal don • • • t tr ..d; uneorssl , tr kaai tr S /VellatS snip min • • calct, pyr glauc; can chlartc elf •DLlntl• ,• • • • ■ grains; r arngsh radlrn foss. w • .•• • r • • ... • • • • IOU U4 J r+r 19,i vi% 4 Iry 50 yypp `s 4 Og • � • i•1 3,4 rk i.4.4 7 - 17000001 4 • 1:11:11200 a • � ( : lief s8.1W t/ *.�ppq; h l• • QaBgLt Q.... .— *(net 14; he 1oas.a an trip - 11102405 t gpu 0 ••pnq G • • • • TO t � v dk whin witty fn -fn; t,0! tai( t ■■ •irm i 3{ , ' --Co si stn: Yr . -- ;bang; qtx, abd volts rujoec 'Os RPM �•r!it9 • • • • • • Galt • • d sansssta n qtz v1 ns; kaol mtx; talc trot rs• limo • 4 1Y1141!!!!!21:11:110 • • • • : tra- t ei06ara con: rr pyr /prrtq fair, chlrtte. 9 t: — 12 PO = Ymaq;7C007f , C4 7. I grave; prdqq *fary. rd$h bra. 11111oanagnar mushy- ti /brel wkly colt sltse. HOnnnOCiGa • r • I MO0 0t7ofac}o drlllsd to 4171' • co; t 1111 GOnGGt1 '. fine art t /x4. and condit,or+ 1 ?31r2Oos 1 ■dD1301aitt7 T.6 ; v bolo for aChlunrb.rgor ii-logs: i / 1r2D41 • 00000C1t70 ran array 1 /bhe spas,* /qua e rag10000001MI ray /3•ar califs/sp /camp litho 111111 • . &unity/caw neutron /gamsa ray. 1004 :ar t .uu au0 ©naa RPtt 60 nnaoo:I1o• • • ,, IMa 19. ,s 47 pv 71 16, A 1 a�xo, n017ai7a ! • • ` f1 4.0 ph 9.a c7- 1Z0Oppm FSPN SO dt7hatlond.. • _.. 1 000t11i0 • • • nt drilling w/ partial mud "" Z 000000'• • • • 1 losses to the ro oms Lion. Oaaoacy0•••• .r 00012000• • • Ass I is snots *mai It-and gry, lair dk gry; 111011311001:1120 • • • • trnsl -clr qt:;. vtn -fm.; ano to pQRQt� ;bang. lair sbrnd; wlcnfl; w1 17Q ;rq* • •' clay artd: al la1 • fapr w /l ith 0Q traps; sot pi �gqrn traps; solids - p1 brn -gry kaolinitic etx. 2 ■00010. -..c .; . •r,c id - " dk yry -bik wit. dryir►g t/ ISO �1Dcl l t1® wear 1 It gry. Pow mOiikt -trnsl 9t%; _ ■ tXl1 ��QQ `abd 9q--1.11 lcn ill spit; co. bik 1 1111 1 0410 7� 1 (Tithic■ tr yrn, prig vfn tt 1000 nt]aIx ••s 1 Ori•aht Rro1 midi; w l -nod trtd; rid -rbang s ■00t70nt7C uweansel -0r speed w /wht kato .. s�1t0000000 mtxr scat tr cale1 a welt, is. •-'�. Igri .• wht. pnkih wht. It iag4i0lOnnil T orngs pnk; sdy /suerp it; rtrly sp , s,x ■N000 n e x _sit say y gaol to sod firms irreg -tab ergs w is■1I0 0 eta tr; Tr I# sebplanar tract; pass partially Il°�0 ®0CG0� dolowitic; cod -via ran w/hcl; ,1 ROg Q retanant kcal el *ys floculate. 1i 0 •'• += IN 19.4 vii 47 In''oirt Page 28 of 28 • Rutter and Wilbanks Corporation Ahtna #1 -19A Phase 3 - Completion Project Summary 14 June 2007 M S Francisco — Houston, TX Ed Burrell- Schlumberger- Kenai, Alaska Eddie Wright — PEI — Houston, TX Original Page 1 of 20 • • Workover Objective: Phase 3 — Completion or P &A as determined by flow test results. To be determined by results of the flow test, reservoir fluids and discussions with Rutter and Wilbanks and partners. A completion operation envisions a production packer, tail pipe, packer seal assembly, coil tubing hanger, and coil tubing. If a completion is not made, then either a suspension of operations will be requested or a Phase 3, Part B may be followed to plug and abandon the well. Current Condition: The original well, Athna #1 -19, was drilled to a total depth of 3,705'. The drill string became stuck. Fishing operations were unsuccessful and left a fish in the hole with top of fish at 1967'. The well was plugged back and bypassed to a depth of 4,640' where a 5" intermediate production casing was run and cemented at 4,639'. Drilling continued to 5,165' where a 3 -1/2" production liner was run and cemented on 6/25/05. Perforations from 4,674- 5,084' were tested with no success in the summer - -of 2005. • In 2006, attempts to re- complete the well utilizing a Perf Drill tool were unsuccessful after attempting to mill windows at 4,387' and 4,382'. By an amendment letter dated 10/18/06 to the AOGCC, a zone from 4,232- 4,250' was perforated and tested, but the well did not flow. The well did build pressure to 2,100 psig in 4 hours, but bled to 0 after 1/3 of a barrel flowback. On 10/25/06, a single joint of tubing was run below the tubing hanger and landed in the tubing spool to facilitate spotting a diesel pill at surface for freezing considerations and operations were suspended. This is shown in Attachment #1 for the Current Wellbore Schematic. Attachment #2 is the Proposed Wellbore Schematic through the Plugback of the current perforations. Reservoir Conditions: A cased hole log was run on June 11, 2007 which recorded pressure, temperature, gamma ray, and collars. This log indicates that the minimum subsurface temperature is 33.13 degrees F at 54 ft. The pressure at the zone of interest (4230') is 4,114.3 psig which is a equivalent mud weight (pore pressure) of 18.70 ppg. The zone of interest (4,230') was drilled with 19.4 ppg mud to offset the high pressure water zones shallower in the well under the 7" casing shoe at 1,914'. It is thought that this overbalance forced mud solids into the pore spaces and inhibited any production. Estimated pore pressure in the zone of interest is 18.3 ppg equating to 4,125 psi at 4,320'. Mud log indicates a drill rate increase from 5 fph to 10 fph at 4,320'. Page 2 of 20 r Procedure: Revision 0 Based on the flow back data, the well may be set up as a completion or P &A'd per the following procedure. The following is Phase 3 with Part A for the Completion and Part B for the plug and abandonment of the Ahtna #1 -19A. Phase 3 — Part A: Completion 1. After flow back test is complete, run 2 -3/8 "coil tubing back bottom. Check for fill and verify total depth is ±4,280' TVD. 2. Circulate hole clean with lower drilling fluid density. Establish new fluid density based on flow back test data and an underbalance of 1000 psig. If the bottom hole pressure is estimated at 18.7 ppg, then displace hole with 14.2 ppg drilling fluid. Pull out of hole with coil tubing. 3. Make up Baker 32FA30 Permanent Production Packer assembly which will include a shear out sub with plug, tail pipe and production packer. Estimated length of assembly is 25 -50'. 4. Verify that when Baker Production packer assembly is set, there will be no flow up the tail pipe. The shear out sub and plug will be sheared at a later date when production testing is conducted. 5. Trip in hole with production packer assembly on coil tubing with appropriate hydraulic setting tool. a. Estimated setting depth for the production packer is 4,100'. Actual setting depth will be determined by length of production packer assembly and a space out distance above the top of the whipstock. b. Estimated setting depth of ±4100' is based on a top of the whipstock at 4129' and the end of the production packer assembly at 4125'. 6. Release packer and pull up 30'. Trip down and tag packer. Mark coil tubing for packer location. 7. Release pressure on annulus of the coil tubing. Trip down and check packer location. Shut well in and monitor for any sign of pressure buildup. If no pressure build up, pull out of hole. 8. Make up Baker 20FA30 K -22 Anchor and 40 -30 PBR seal assembly for production packer. Connect assembly to coil tubing. Run in hole with assembly. 9. Stab seal assembly into packer and mark coil tubing for space out. 10. Pick up and cut the coil tubing. Make up coil tubing hanger to coil tubing. 11. Pump 30 gallons of diesel down coil tubing followed with 46 bbls packer fluid. Packer fluid may be drilling fluid or a completion fluid. 12. Displace diesel and packer fluid into annulus with KCI water. a. Actual volumes will be calculated and checked on location prior to pumping displacement. b. Volume of displacement fluid will be based on coil tubing length. If the coil tubing length is 6,000 ft, then displace with 22 bbls. 13. Slowly land seal assembly and coil tubing hanger. Set coil tubing hanger pins in coil tubing head. Test backside to 1000 psig. Page 3 of 20 • • 14. Verify seals are holding by releasing pressure off coil tubing. 15. Rig down the Coil Tubing BOPE. 16. Bolt up the crossover from the VetcoGray Coil Tubing Head to tree. NU 2- 9/16" production LICC & Lest. 17. Secure tree with chains and locks. RD & depart Location. Lock gate. Phase 3 — Part B: Plug & Abandon Well 5�� u� 1. TIH with CT to bottom of sidetrack at 4280' TVD. A 2. Mix & pump cement plug #1 in sidetrack from 4040 -4280' TVD. Retrack coil tubing as cement plug is displaced in hole. Estimated volume of cement is 5 bbls with top of cement at 3980 ft. 3. Hook up flowline to 5 "x7" casing annulus and establish a pump in rates of 1.5, 2.0 and 2.5 bpm. 4. Mix & pump plug #2 in 5 "x7" casing annulus. Annulus volume is approximately 24.5 bbls. Mixing and pump 30 bbls of cement. Close casing valve and disconnect flowline. Verify cement is in annulus at valve. Flush flow fine with fresh water. Tie back on to casing valve and displace cement with 3 gallons of freshwater to displace cement 5 ft below ground level. 5. Run casing with CIBP and set at 1326'. Mix & pump plug #3 from 1326 -1126' . Volume of cement is calculated at 3.4 bbls. Mix and pump 5 bbls for top of cement to be at 1032 ft. Pull up to 1100 ft and circulate out cement. 6. Pull coil tubing up to 155'. 7. Mix & pump plug #4. Pull up to 5 ft and circulate out cement in well head and coil tubing unit.' 8. ND wellhead, Cut off casings. Weld on Plate at base of cellar. 9. Rig down equipment and clean up location. 10. Depart location. Page 4 of 20 S 0 Attachment #1 - Current Wellbore Schematic FIUTTER 8( WILBANKS CORPORATION Sec 4. T4f4. pas AHTN A #1-19 API No: 50-09C‘50:1C,,v5-• 00 PK8 2037,0 t ,3 Current We if bOre Schematic CI. 2018] 1012106 Depth Ca::Ang.tetnent Colt) pletii.tin: 2-7$* 65# 1:80 ELIE Tubing L 7e: Ba. 13 61:-,14 L-80 Conductor Shoe Squeezed With 188 bbki 12 t I 1,226 9 41:4 L-80 ETC: Surface 20 bbl Perrnafottit 8 Cila.f.4.; Cli 8-1'2" 1,f?15 7" 44.' L-K ETC Intermedint? Wellt Fluid Above Packer 66 bbis CI= C to sutface 9.0 prig KOL Mlle with cigen f4avenget afid c,-orrosio inhibitor. Top X is diesel fcf freeze proection. 3,200 Top of Cement i,CEL:i = = E - Line Perk,: 4232 4250 Drill Peri Tool i:.;hannel: 4852 =.7. m.,...„ tr.= ...„., 4387 _ ---,--- _ ,:--- Top of cement 4 536 place d with dump boiler: 4,577 Top of 3- t=2" Liner teF2E1 4,635 Weatherford E-IFIBP (inflatable Ret BP! 4.639 5" 17,4' L-80 S:TL fotermediate Pe iforaticinz,: 4€.,74 4e4y.. „. 53 bbli; Cilazit. G 4922 44i 4523 4*29 :”...,.., 4932 4 =,...'.; 5076 50514 . „..„ s,)9 P ET D / \ 5.165 3-12" L Prcid, Liner Tool Depth il,tp 8 IVO. 5.1 Page 5 of 20 , . I 0 Attachment #2 — Phase 1, Proposed Plugback VVellbore Schematic RUTTFR & WILRANKS CORPORATION I , si,:: 4. "NM, Rm AHTNA #1-19 Proposed Plugback We bore Schematic RKE 2037,(4 18.3 6O7 a 2018,7 Depth Casingtetne nt Completion: L., , 2-Te.' 63 L.80 EU E Tubing e $' BL , *. 13-3!t'r 6e4 Lb) unduct Shoe Squeezed with I 8.3 bbis 12-1!4" i ,22 , „,..4- Sir 41: ETC Surface 2 Ms Pet & elm (..; 8 1,915 7" `i:K5# i..-e ETC Intermediate Wellix Fluid Abcive Pacio,N: 56 bbk Clcos G to tAirface St..) pp I<CL bine with oxygen ccavenget and corrosion inhibitor, Top 2:1' is. desel for freeze pr 3,201 Top of ,c.,ement .(C81;, 4,15 TOG - pl xed with dump hailer 4,221) tMchanica1 Pim E-Line Nit: 4232 4 251) Drill Pe rf To Channel: 4382 = 4 3$7 Top of cement 4.5'36 placed with dump Mier: 4 ,577 Top ,, 3-112" Linet 1 4.635 V [ford E-IFIEP 1:Inflatable Ret BP 4,€-3 9 5" 17.8# 1,-80 STL Imtrintcliate. , . Pe rforationc.: 4€ 4680 ,,,,,,,, _ 53 bbic, !att. 1..; ,-------- 022 4c-40 4'? 23 4!?29 .. 4932 4''38 .,...._ = 54:111;* 5.7J21) - , PET D L'?: Pro Line, Total Depth , IME , ,c.r T' ,5 Page 6 of 20 • • Attachment #3 — Phase 2, Proposed Side Track Wellbore Schematic RUTTER & WILBANKS CORPORATION 4,1 R3W AHTNA #1-19A API No.: 50- 099-5X05- Proposed Side Track Wellbore Schematic RKB 2037.0 18 007 GL 20185 0p111 C-osing COM 2-7'8" 6.F.41.-K BUB Tubing L 7$' BGL 1 3-9' 68# L80 Condwtor - 1. ,,,r Jo] Shc4 SqL1.44zd with 183 bi:t 12 1 228 9-518' L$0 RIC Surtv4 20 L4:1 Pit & Cb,7,4 172' 1915 . 7° 21.i4 L-80 RTC 1ntwrii4di3t Wi�hori Rid Abov.,.? Pak4r: 68 bbts Clow S stitfae;i1 ppg KCL Nil* with vavicify and mosion TCip 20' is 64. c.4 for ts1 200 :4 c4nwit fr4:4 rowtion. Top e4 Whip t3tock at 4129' ±4.14 Top IA Window Whip Std. A ithot at ±4.153' 1:4149 BMCkill TOC 0111104.-1111 pi3C4d wl dump bail 4180-4 195 h14.41 Plug 4220 Ev.._11dati; E-Lim Pt: 42K 4250 Drill P4,411 Toot Chann41: 4.3 457 _ End c4 it ±4 Top of co) mit 4,536 1:00c.F.1 with dump OW 4.577 T% wt.:1W 4t325 Wthrbii E-1R6P A —gip— ibh, ontbtabw R4t, BP! 4,€f39 5" 17.84 L-80 STL Int4rirwliat.? Priotaijorr. 4874 4580 bbis Cbsz. 4922 4940 4923 4929 =. 4932 4938 6 099 .5 t) Ei.120 P6TD S 176 91 2** L-80 P:1 Lw 1 MCI Page 7 of 20 • Attachment #5 — Phase 3, Part B, Proposed Plug & Abandonment '7 S....9.90Leks --447e4 ;2 .444 , RATTER & WILBANKS CORPORATION AHTNA #1-19A Optional Proposed P&A W1411hOte Sehethatk: AKE 2037,( 1S.:3 61907 rL 20184 7 . . , i4iYth C-3 114,g:41134M Cc:1014A : j !Plug a L - -480 EttE Tubing 684 L-80 ConduCor Ship.? Squ44.4z41 with 14?..2 1:43ts Pito: i 1 4' 1.226 9-45.4- 40# 1;80 BTC; 4'"..4rfia itoQ 4 5-155 150 23= 2" Ws Pi441. inatomt & Clow G 1 1126 200' Pm 1 0 32 Retaino 12f: I * 1 ,915 7 26# L-480 ETC- InoNwictiati.: pi= =.. 66 1:4131s Clox C., to suitci? 2 191 - 1715 204'S tc 2CC Top of o 4°, Ca) 1 4040 - 4280' TVD Top 4:4 Whi1. i7.404-1. ot 412 • 1Plog r I, ±4, 140 Top of Window , . Whip Stlx414', A Khor ±4, I5 ±4.149 Bottom of Window -- • 1 "41,114111 T pioci4d 4w,' dump boilK 4 180-4 195 1,14 Plug 4.220 Evoluatii zon4? 4±42:30- 4.254Y E tin P•k44 ito 42S2 4250 Drill P4;41 TI Chann.A: 4982 *387 7,7= EW1 of f_iid tro4 it 4±4.280' Top of 4>? 4.535 II:4134;44A with lum 4144.44ri 4 577 T4:4p of 1 '2' Lint 465 W .431114? rford E- REP .4174ZMI7IL ilaftatabfre R4t. BPI 43C95' 17, Et L-80 ST1. Inwinidiz& Pq4 4674 4680 HAL 7, hc - 4922 4940 492? 4929 492 4998 5010 E.020 1:499 PETE:4 ';'• 8 L-80 TL P14:44:1 Lin. T4l C4.44pth ;k1C4 T C. 4 1 4 Page 9 of 20 ' 9 0 Attachment #6 — Current VetcoGray Wellhead and Tree --- 44 „I ., 4 ----/----f—.71 . ?, i ‘...`(,...-....,v4 ,t) r 5 . , , ,. ... 4: - 1 - -:-.-: ,-,..-- ---..... TIlso ” .... , I i& 4, ''.4-4( SZ.,./16 :04 ,1 a irrt , i s , fli It -- _ , ... , . 4ff ' EN ,, ,d .. ... * N . ,.... ''iii` .. f . ..1:--, i - 1 ...5-.4.?, "1S- _ , I I 1 ,* .,,, ,‘ I f ' 1 I 1 1 1111, t , 1 - L ,..,--' I g '''...4: ' I 2Y, 4 1' 6 - , qd Z Li 3 L-71"a' 73 4 _1. rtir.1 „,. VSHr a .i.-:i At t■tr.:: lit 9 Al RAY .S7.3.TiriZE E}f7.!NY:-Terrl i vetcograyl I t3-.2 $: 0 (,.. ..... 7 ,.). I.) ..- 7 rit, Jf;`i 14f r As.f 1 'it-, ' •, ,,, c X e at it , 1, i 1 :+0 iVet ,... 10 ,t• $1 'Z' n f . S. A... ..2o, o0,, er4 T r , .:__,„,.... :....._ , . . Page 10 of 20 • • Attachment #7 — VetcoGray Tree with Proposed dual 4 -1/8" 5K Valves �k} fzz e � t Y 272 �tYl' — qvw ^vw : 1k ✓ • k =7 a, J I af Veto° Gray Page 11 of 20 • S Attachment #8 - Schlumberger CTU Equipment List & 2-3/8" Coil Tubing Specification 2 3:8" 1:. OILED 71JEING Sit whipstc.c: rill window •rc, ciri I . .i?': cipel ho e 2 375' 07 :..z...y ...1-1 Ei 1,-. :11 ~.e •-. per :a,' ::: -Ir ..1-11 pe F..r - 1 - 1 . ; :r B- per % - . :t.° t. ::,::: :r3Ii- o%' c:ii 1 t. '7' ,:. VP' :,F6' li.::::7 I-:1:' = pe :::: :a rygs- ..:a:1 CT F L c PLnp 1; S-mi.. ::e*: =Jr': Lell :ra- 2:: -1-= ,-: '..-- T.Iro. 1:515:43:0 `i Rt• '..:1:ii: '',.:21.r:7-_ "..,;71',.'1:::-::; :.,- '`. :E.' :."i'.7 Ee:. per :.z.y :rc „tei ' ::* :'2 ^ ''o =.r) Lels :ra 2:: -1-.=. a:: ': '''.:.. ri.° lir 2 - 17::::e - iL -,: _ i !-- :::S.: ::0 : :v '" :a. - 3 - (,..>e° .:...7..., RI:. *-1:r i. :7:7:IL -:a.1 Personr 91: , :_. - ir :-.=:-.- t:E 7,4E- '. ._1 pe. '''''' , ,,i- : r" - ! - , - .1, .... ,.. ... -ir :e... `:e Ter: 10 ..a. .:er — i I' 4 :::: :::::::t• c , - I' .:-.".:,"; ". ,e :e°, le _:!.: :.:::-..r........' per :.zy .1: VI:e t*. per :ay Page 12 of 20 • ni an C' ■" 0 A IC. 1 -.• ii i si 4 k " ‘'''' l '"' v.i.1 '.' t ik _., 11,,.„,1 ILA 1, „1 1,„,,1 1.4 ,,,,,, a, { 171 1 eell r ki 1 ,M I Cji I 0 1 11 1 N in 0 . N NI1 el ' - e 1 - 1! :J., , i e.• ..• ro• -, ••■ i 1 -. 141 .1'71 en in ry 1 en , ,, I -• I. a 1 , , , • ..0 1 P 1 1 1 • I e N 1 ° • 51, e I • • 1 • lel • , I i'" ,e, ' 1 • 19 ' 1 '1 ••‘' 1,11 • 11 '' 1 1 .. 1 1 1 ..04 en .8 • - 4 • .. f . 1 r..711 „-3 r 1 „;-_•, 1;1 1„„..■ L.j 1„..„,• 17 • 1• ,:1 ... 1._■ L L....1 L.1 kJ L,„1 1.,,, /..."'" 1 I 11 11 1 1 ,1„ IV 1 411111111111% ' 17 le 1171 •-z- ey• iTI 1 47.11 ..- 171 . 117,1 f 71 = ' • X° ....0 .eir. kro ..... II • • o f • -4 ...... , 4, •0_, ,,.... i ' ' 1.`,/ •,` 1 1.11 Cu 1(1 t .",,a s t*,,6 I C t l',.. -- oo, .„I V I I I .,.:. • rn i •", en, *-- / ' .' ni Ill rfl f •I • ,,,,, ...4: ...I. 111 111 111 111 :::' „ a , "xo fa 0 40 1 1I fo :".1 e'•8 ro f• ro ......-* • • - e: •. - 13 a) CO I. ) " ..:: ‘,.. ,- ,. C. 1 Ai e N „iv l, j i, j • : 1.:I. .1 CD ep.....„ i .01 • i , .1. I) ..., , , i - 1 I. . . . „ .... „. • ; IP __. _!, ... ' 1 - -r: 0 ...$ : . (....) • . . * I t• „.. ;4'6 1W". 01 S k i ,.... ,,,, i ... . ,,, . .... .1 °/.1 • i, * .1* 1 i 0 . . 11 .... ,.... -.1 ,,, ID ID . . :v • .11 ‘jdi '• 17: 0 . .7 —I • ", "- : " i 11 '..' • . —91 .•• .„. i, • v v. 1 1/. 1 - Ls * * ' i • i '" • • ' ..1./ I') o'''. • " f• 1 I I' Jr i'..1 4 .• ". /1" . 01 ' • • " J.... 114 J.. ',LP J.. ' 1 11 ..„: '.... ,.. ',;-... • " 1.•";■ 0. ' ...■- Ni; ., —A " • IA .-,. : :-Ti • 1••■ II/ 111 ■, — r • a . : • . N. at' ... ' .... - ' d. .1. ' 1 1 eld ' ' ,,.... 1 1 3 3 • * ' a in ' r , 171 i..:... r • ' il 1. ill . " .,•• ,— NI „,..- • • . 0 t•- •• 1■1 1 ,..,, .1 ,•• 1./ ..`'. •I• III a i .. -,..,- li tie —. • e . i : „ 1 1 o . ,., -1 ere 1.1 I 11 * * . f • lj 0 a 1 ...a . o • • ni .„ Jr! 1 li 1 . ° • 4.0 , . 9 ) a g g,J ilia a, i lila t'a ..... e r .0 e 111 II P. i eTt •..r. * * ,.... ^7.:*. II/ :II, 0 • , d ire• 1)1 • .r. ' i d i j N . .., ji ' r 'V ' k r. 44 ,-....,.. ---I ... P., .II. ..i i '• Co 4,4 ro I Schltimhergel Attachment #9— Directional Plot and Plans I TAZ VstitAnz t* gg. ■ . „•.• "■: ":: Page 14 of 20 , . • Ahtna 1.19A 10/100 Proposal Schlumbevger CU .:1* Irx C...s.' ...!3: *"., ....-:. ". ! * ...:r. *,"././...:•1 ' : 0 C 7 4; . * I, i " r ; :/..erro [...e. 7, 3 1 TA zt•rt::::11-::,..;4.i:ri ' K: :f:.f..3i.1:: *.I7tr .., 4■Tt Cm .: • /,', !.,. ; 0",.: ....::: - .*. ' : x :... -i: ..vi., ri-A34”:4! ',vi: . 4-ot T:.(s?-1;01., , . : _ _ Comt": 0:: " r, ,-, Ali r:' ‘....t-.: - ,1' "'"..`, N.:. :,+:::" f/tt/I:0 ":.. r';')t :'.• " ( , *,/,., :t; tln : t : ,: „ ..,. - ,: t: , ! ;to (::- ):: :;c - :i' --.... . --- . ..- - -1.:r I :F El: C ....,.... :-'...: C".; .: ..57. ..,..... 1: '::c. ,.. -:- : :: '::: :.; c...e = .1S- ::-:.- - .4.- _ ..,.. : i'..: . .. — - 1: c:: : :6 '.:::: :1: ' . — :.:....- . - - 't... - 14: . .... * 1: c:: - .... - ...,..r . — 1: 'C':: : .:„. ...... - -: ..)... -....:. .. :.:•-,' . ... .,..- -- . 4::, i '.. ::: :-": ,:,..: =.:7:- !: :: 4: :.:.:- ., ... -- 4: :: Ahtna 1.19A 151100 Proposal Schlumberger EC : ,I '..i .u: • !./.. : tre. , ■.'t -. .:. 1. r. :: 'z rzi*I.././ ( .i./ • -4 '. .:'vr,•9 ,t". :41 t•ts/./i,:n i:// 0 S 7„,:n: , .. '.".: :,:::: Y. .. 7 1.3 • *.. ,, t - t: - :' , :f i --.'.: ' 3 . " //..i. •.: !.."././e.. ...t.ti .IA° .10:". V:4-t,V, •-;-..•., , .- .:-.:-.;---.; ' ..,.; :( ..rt .:, :::::- -0.3 7:e.,4*".•t0;',/ 1 .1,4: .i:. -1..". l: ' 4 ( :11 fa:0 .itt - :,:. Y. >' J";.:tt; V:4'0 L "/i•:/i7.01t4t . /......."../ =± (.../- V.4 0, .." 1..r.• G.' 4*.•:,1! :;::-./" . /::. 2. :,-;°: / r.t: 0 ect**: ": ...70. _ 1..,:frt: f - : ' , , :.›.:::1 ;:v.n7 .;:* /.t.:■!.;. "/.0 - "t; .:. .._ "'y -T;)e ' ..- ..:. ,.. -..:: ■. . - ..`:. _ _ --- - ..,..: , _ ..- .. : .. ... -- .: ... -1...` . ...- -r i ' " r E.: ( ::: . , .. - . ...... : :: :.1 (.: :. c:: -- .:. . . _ .. - ..1 - -* — 1: .'.. ' -' — - - .. ... - -..-: . . 2•::: C .. 1 .■.: '....7'... 3 '' ..' .. a . , ... ., . , . ... . . . . , - . . .. ., . .^:1!: :C ;!, 'I : : : ,.. ' ..* ''..' .' .■ .. 2 - .' ", ' S': '..1. . .. - ■::. !' ‘.. F. - . . - - ... . .. . . Page 15 of 20 I Attachment #10 — Baker Oil Tool Completion Proposal .And 7, C :c depr11, • r::1 3ad rit:Ltr !:o r: - C : : r: - 33 : 7 P:,.3 P3R :o 2 ;.; : T. PIE - pack:. Ric or d VCI:Li ie PT r: ov: aad Direnize nu:E ja 3:1 C sea:. Page 16 of 20 . - 0 • Baker Thru-Tubing F 7-- '3.C. , .tir :'%S.SE!..11:': y _ _ 2 !.. C. 411 _ r: Z _..::-. .: , , t ' CI :::. C.:1r ...--.:, f ":-'' ;:•:--..,. -7: • .1 . c - , i 1 ' ...-- _ f — . , . :_, ... i :23 k ::! -I' ::: : 7.---.-, MIMI 4- i . F .. 1 .` F:ic....:-. ",..- f ? - ,-..... — — E.7.; it • _ 1 :..: - 1 , •_-:4•' :L t :..4,t1: ',,v. 1., . . Page 17 of 20 . . . ,, .. • 0 Baker Thru-Tubing PER -- .' ! k,..Or p e Ko 111 H: 1 111 1 _ 1 :'-' ii F ::,, ..::,:..; 4 s :.= : -- ,..' y -.. ":".:: • ... - - ..... ,-...„ .... 1 I 1 Page 18 of 20 . • • • • Attachment #11 — VetcoGray Coil tubing hanger and head Data 4 COIL TUBING HANGER COMPANY MC DATE 413t2CC 7 — FIELD ?(Gr SRVC REP Rowcy Toon WELL# 5 DESCRIPTION 4' W.= Gy Co:' %brig Marc TOP CONNECTION 3 GS Baer Ftshneck BTM THREADS . PN# 1-C202224-1 COIL. WT GRADE SIZE 23'8' HT # 475Th HANGER DRIFTED IN HEAD ASSY# C2C2224-2 BPV 2' H . Typs DRIFTED L SN# : SPY DRIFTED WITH GRAPPLE INSTALLED MIN BORE 1 94 —„-- _ HANGER REDRESS KIT ON HAND SEAL TYPES GRAPPLE REDRESS KIT ON HAND - 77 EMI 1 11/16" ...... . .. ....... 4 ..... .„ .... Page 19 of 20 ., • . II • COIL TUBING HEAD COMPANY ronc: DATE 4i3;2c;c7 FIELD Ki:;1'; SRVC REP Rcwdy 70J2I . . WELL* 33 6 DESCRIPTION 4" 5M Coal T:thing I TOP CONNECTION 4 - 5M " MODEL IGC API RING R-39 PN# WA. SN# 51&'410 1Z PN# C110136 1 SIZE 2 ;16" 5M HT * L8E•61 SN# 34165-01 2 MODEL M RA ActuAthti _ . ASSY# G11C136-2 PM/ WA SN* .1; BOTTOM CONNECTION 4 5M SIZE 2 1 SM — API RING r R-3i , J,T,47,77.1, _ ACTUATED --7 1 - 7.: 7 TYPE { •'::7• MIN BORE 4 03 MODEL I- , .. PNN !WIC UPPER LOCK SCREWS SN* 1;2655 LOCK SCREWS FREE J LOCK OUT CAP INSTALLED OUT MEASUREMENT 4 ALL LDS CIRCLED t 7.7 TESTS PORTS CLEAR ? 1 'Th LOS MSRMNT WROTE ON tiFAD L ..... 2_ LS - MUST HAVE LUDE FITTING ON EACH SIDE' LOWER LOCK SCREWS LUKE FITTING ON EACH SIDE 1 LOCK SCREWS FREE r Y7 OUT MEASUREMENT 4" Liit3E FITTING CAPS TIGHT? . . IN MEASUREMENT TO LAND 3 5/8" ALL LDS CIRCLED 'y ES ____ DRIFTED WITH BPV L, ,,,:: L ......._-__ LOS MSRMN1 WROTT ON READ ''' 'I :' ; _ BPV SIZE 4" tli ripe DRIFTED WITH HANGER ............_ ......._ 1 &Er -..a. it;: , 4 3/Er 1 I - 4 1 M I . , 1 ;, ,,,.. ....... .... .......... .... mow 13- 7 7 1 NI •111 .11111 2:1 VIC . • , . , 1 , • . 4 f. • . 42 ---•', Page 20 of 20 May 31 07 08:32a Rut, Companies 43268732 p.1 RUTTER AND WILBANKS CORPORATION P. O. Box 3186 Midland, Texas 79702 (432)683 -1824 Fax (432)683 -1732 May 31, 2007 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Ahtna #1 -19 Sec. 19, T -4 -N CRM Near Glennallen, Alaska Gentlemen: Please allow Eddie Wright of PEI, Inc. to have access to copies of the documents that Rutter and Wilbanks Corporation has submitted to date with respect to the captioned well. He will be working with Mick Francisco on our re -entry of this well in early June for testing. Very truly yours, RUTTER AND WILBANKS CORPORATION / A. W. Rutter, Jr. Vice President AWRJR:csh • RECEIVED MAY 3 1 2007 RUTTER AND WILBANKS CORPORATION Alaska Oil & Gas Cons. Commission P. O. Box 3186 Anchorage Midland, Texas 79702 (432)683 -1824 Fax (432)683 -1732 May 30, 2007 Steve Davies Alaska Oil and Gas Conservation Commission 333 W. 7"' Avenue, Suite 100 Anchorage AK 99501 Dear Steve: I believe the engineer working for Mick Francisco will be in your office on Friday and he can answer any questions you may have about what we plan to do at that time. Hopefully this will be received before he arrives on Friday morning. If you have any questions, please feel free to call me at any time. Very truly yours, RUTTER AND WILBANKS CORPORATION A. W. Rutter, Jr. Vice President AWRJR:csh Enclosures RECEIVED STATE OF ALASKA MAY 3 1 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage la. Type of Work: lb. Current Well Class: Exploratory ® Development Oil ❑ 1c. Specify if well is proposed for. Drill ❑ Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas p 2. Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11. Well Name and Number: Rutter and Wilbanks C.rporation Bond No. Ahtna 1 - 19 3. Address: 301 S . Main St., Suite B 6. Proposed Depth: 12. Field /Pool(s): P. 0. Box 3186, Midland, TX 79702 MD: 4300' ND: 4300' 4a. Location of Well (Govemmental Section): 7. Property Designation: surface: 1139.4' FEL, 2224.2' L Sec. 19 Sec. 19, T -4 -N CRM Top of Productive Horizon: T4N, '3W, CRM 8. Land Use Permit: 13. Approximate Spud Date: Same Ahtna Surface 5/28/07 Total Depth: 9. Acres in Property: 14. Distance to Nearest Same 640 acres Property: 1139 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 527867 y- 2964256 Zon. - (Height above GL): 2017 feet Within PoccA 16. Deviated wells: Kickoff depth: 4190 fe: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 15 deg es Downhole: 4500# Surface: 2200# 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Lengt' MD ND MD ND (including stage data) A1 19. PRESENT WELL CONDITION SUMMARY (To be complet. . • - - . rill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): E -ith MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Ce - V. me MD ND Conductor /Structural 781 1 1 -3/R" 78' 78' surface 1207.7' 9 -5/8" 1226' 1226' Intermediate 1896.7' 7" 1915' 1915' Production 6.h19 s" 4639' . 4639' Liner 588' 3-1/2" 5165' 5165' Perforation Depth MD (ft): Perforation Depth ND ( • 4508 -4530, 4474 -4530, 4387, 4382, 4232 -50 20. Attachments: Filing Fee l� BOP Sketch E Drilling Program ❑ Time Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Flui , Program ❑ 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name /A. W tter Jr. j Title Vice President / I Signature / �� Phone (432)683 -1824 D- e 5 - - / Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 205 -015 50- 099 - 2005 -00 Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ❑ Other: Samples req'd: Yes❑ No ❑ Mud log req'd: Yes❑ No❑ H measures: Yes No ❑ Directional svy req'd: Yes❑ No❑ APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate ORIGINAL. • 411,____________ d k_ 4 -5/8. OD ACME 2 -7/8' 8RD I.D. THREADS ^� 0 " 1 -13/16 1DM r1 2' 1502 iii 93 -1/2' V t `ZAI I c.) /o) 2 -9/16 10M i 1/ III ill , ii I 11 lOM ...ramie. -- r i ....�. AM Irl II Irl 26 -1/' 2 . 1 mil 1 � • � i � •1 ■■ , ■ . � ir, c '� c V 4111111 I f I I ifli1 wl 32.00° a ° i 32.00 �• 11 10M T Ii ! I IrI ' = Irl A 26 -1/2` It _.O O.! G.1 j. �� 1 I an' un -- 32.00° 11 �� � ! 32.00' --- I 'il � *� it lOM I 7 I � rtt Irl ' i mm 33.12' 25 -1/4' � .� , = le �■11` �o o� ` ■ UN i f i 71 INI Ai I ' ' l t p 13 -5/8 5M nu I ■� ?JI 111 1 n �ji •'1 �M 2 1.00' �' � 30.25' 7' OD CSG I' I Pill 111,11 111 13 -3,8 OD CSG 2 -7/8' OD TBG III 9 -5/8' OD CSG ALL DIMENSIONS ARE APPROXIMATE 5' OD CSG VETCO GRAY SYSTEMS ENGINEERING vetcogray' 13 -3/8 X 9 -5/8 X 7 X 5 X 2 -7/8 ❑D, 10M MSP ASSEMBLY DRAWN BYE C. EICE DATE: 21 JAN 2005 -- REFERENCE: RUTTER AND WIeaNKS, a501033 DRAWING NO. ENG. APPR.: DATE: x1v -C ' SCALE: NA PROJECT NO.: SP - 5672A • • Rutter .and ilfultantes C .AMINO' SI-10 Welibore Schematic (8129/05) vl Corretion: . ., : 2-7/8" 65# L -80 EUE 8rd Tubing to .� , surface ` 13 -318" 68# L -80 Conductor a 78' BGL. Sliding sleeve w1 2.313" ID "X" Shoe squeezed wl 18.3 bbls cmt. profile( 4,406' i ' I it 2 -7/8" tubing , , 3 ` . T -2 On -Off tool vwl 1.875" ID "X" profile g 4,452' pr Weatherford krrowset IX mechanical set packer a 4,453' .: 1 it + 1 pup 2 -718" tubing 9 -518" 40# L -80 BTC Surf Csg g 1,226'. C rntd to surf wi 20 bbls Permafrost cmt 6 Wireline entry guide 4,492' ,: bbls Class G. fi Welbore Fluid Above Pkr: fn 9.0 ppg KCI brine w/ oxygen scavenger and corrosion inhibitor. Top 20' is diesel for ' { ,2 7" 26# L -80 BTC Intermediate Csg a 1,915'. freeze protection. : , g surf wt 66 bbls Class "G III II Top of 5" cement a 3,200' (CBL) EII x tel eel,, 4474' — 4490' 1.688" Pwrapri 45° Phase, 7. Top of 3 -112" liner a 4,577' - 4508' — 4530' 1.688" Pwrsprl 45° Phase, 7. Liner Hanger:' TIVV EJ -IB -SC w/ Type S Packer ! rimiro Csg c i 4,639' 5 17.8# L -80 STL Intermediate C Weatherford E -IRBP (Inflatable, ` - w/ 53 bbls Class "0" Retrievable Bridge Plug) at 4635 ft. ta Welbore Fluid Below Mx: _ ° Open Perforations: 4674' — 4680' 1 11116" PS EJ 45° Phase 7.5 : 9.0 ppg KCI brine wi oxygen 4922' — 4940' 1.56" HSD PJ 60° Phase 6 SPF scavenger and corrosion 4923' — 4929' 1 11116" PS EJ 45° Phase 7.5 : inhibitor. Top 20' is diesel for L" 4932 -4938' 1 11116" PS EJ 45° Phase 7.5: freeze protection. 5010' — 5020' 1.56" HSD PJ 60° Phase 6 SPF 5076'— 5084' 1.56" HSD PJ 60° Phase 6 SPF PBTD 5,099' 3 -1 8.8# L -80 STL Production Lnr @ 5,165'. c wjp 0906105 TD 5,165' MD & TVD to TOL w! 5 bbls Class "0" Rutter & Wilbanks Corporan Date: 05/30/7 NO. 2593 Inv No Date Description B/W Amt Discount Amount 053007 5/30/2007 Filing fee -Drag Permit Ahtna 0.00 0.00 100.00 TOTAL CHECK 100.00 4q + I $, IQd tlNl .I � 1 III' 1 p V 1 7 � 1' V,i i "}�E� . R ter , , ' Wi l banks Cor porat i on Western Natio Bank e p 11 II } I IIN I Midl Tex s Ij t I t il l - i I ,N I� ; 11 O Box 3 18£ , i1 II ''ll ll9� I ' I ° li IIlill � 1.1,% 5 I I 1 - � - I i'H 61 l�l I � 7i 1111,1 I II 'I �. li 21t 1, P ll � 1�ltd T � 11fi3 r "' I l yl r _ I I I I IOP'I " -ip !' - i IY l.1 ^ !!q oun Pil M V :4 i" � . * iri f * *4• * One H un d r e d A 0 0 /1 00 Do llars 30 00 Ill I � I Y I 1VI - - 1 � A I� di l i „ A ` 1r t�lll�ll 1 r il 1s''. d I l ryl t " s . 1 III ,N 1411 1 plp,l1 I V 1 y - 1 q l 11 1 Q, l & . Consery at Comm ssi .1 " - ,i74 . �, .I' ", 15� .�...z, �'i" 'a v,...d'11'�Jil�il °�d 911i��l�lols i�' 259 3��'�: L630 80 L11 ' . . 0 • Rutter and Wilbanks Corporation Ahtna #1 -19A Plugback, Sidetrack and Test Project Summary 25 April 2007 M S Francisco — Houston, TX Ed Burrell- Schlumberger- Kenai, Alaska Eddie Wright — PEI — Houston, TX Revision 1 — 24 May 2007 Revision 2 — 7 June 2007 Page 1 of 6 0 • Workover Objective: Phase 1 — P &A existing perforations and plug back the well. Plug and abandon perforations at 4230 - 4250', 4382', and 4387' with an mechanical plug set at ±4220' and dump bail a minimum of 25' of cement on top. This abandonment is in accordance with 20 AAC 25.112, Well Plugging Requirements, Section C, Plugging of cased portions of a wellbore, Paragraph 1, concerning perforated intervals, Subpart E which states: "if the perforations are isolated from the open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and .... a minimum of 25 feet of cement placed on top of the plug with a dump bailer." Phase 2 — Side track at ±4140' to a depth of ±4280' TVD A. Begin cutting a window in the exiting 5" casing string at approximately 4,140' and finish window at approximately 4149', sidetrack and drill to a depth of approximately 4,280' TVD, achieving a minimum of 10' of displacement from the original hole at 4230' TVD, all utilizing coiled tubing unit, mud motors and under pressure. B. Flow test the well to ascertain reservoir fluids. Phase 3 — Completion or P &A To be determined by results of the flow test, reservoir fluids and discussions with Rutter and Wilbanks and partners. A completion operation envisions a production packer, tail pipe, packer seal assembly, coil tubing hanger, and coil tubing. Page 2 of 6 • Current Condition: The original well, Athna #1 -19, was drilled to a total depth of 3,705'. The drill string became stuck. Fishing operation were unsuccessful and left a fish in the hole with top of fish at 1967'. The well was plugged back and bypassed to a depth of 4,640' where a 5" intermediate production casing was run and cemented at 4,639'. Drilling continued to 5,165' where a 3 -1/2" production liner was run and cemented on 6/25/05. Perforations from 4,674 - 5,084' were tested with no success in the summer of 2005. In 2006, attempts to re- complete the well utilizing a Perf Drill tool were unsuccessful after attempting to mill windows at 4,387' and 4,382'. By an amendment letter dated 10/18/06 to the AOGCC, a zone from 4,232- 4,250' was perforated and tested, but the well did not flow. The well did build pressure to 2,100 psig in 4 hours, but bled to 0 after 1/3 of a barrel flowback. On 10- 25 -06, a single joint of tubing was run below the tubing hanger and landed in the tubing spool to facilitate spotting a diesel pill at surface for freezing considerations and operations were suspended. Reservoir Conditions: The zone of interest (4,230') was drilled with 19.4 ppg mud to offset the high pressure water zones shallower in the well under the 7" casing shoe at 1,914'. It is thought that this overbalance forced mud solids into the pore spaces and inhibited any production. Estimated pore pressure in the zone of interest is 18.3 ppg equating to 4,125 psi at 4,320'. Mud log indicates a drill rate increase from 5 fph to 10 fph at 4,320'. II Page 3 of 6 • • Procedure: Phase 1 — Isolate perforations per 20 AAC 25.112 Well Plugging Requirements, Part C — Plugging of cased portions of a wellborn, Paragraph 1 Perforated Intervals, - Subpart E. 1. Check all casing annulus and SITP pressures. 2. Rig up a flowback tank with a gas buster, if required. 3. Bleed off any pressure to tank. Monitor well to ensure well is dead. 4. Move in and rig up electric line and lubricator. Test lubricator to 5,000 psig. 5. Make gauge ring run to insure setting depth for bridge plug can be reach. During run, a Temperature Survey /CCL /GR log may be run. Set a mechanical bridge plug at ±4220'. 6. Make multiple bailer runs to dump a minimum of 25' of cement on top of bridge plug. Estimated top of cement may be between 4180 - 4195'. Leave well shut in for sufficient time for cement to set. Collect and observe surface samples of cement. 7. Bleed off pressure and monitor well to ensure it is dead. 8. Nipple down the Christmas tree. 9. Rig up and pull tubing hanger and single joint of tubing. 10. Install pre- tested (from top) 5 1/8" 5K x 4 1/8" 5K tubing head, 2 ea. x 4 1/8" 5K valves, and 11" 10K x 4-1/8" 5K adapter on top of tubing spool. 11. Run in with electric line and tag top of cement. Run GR /CCL log for tie -end to whip stock setting depth.. 12. Rig down and release electric line. Page 4 of 6 • • Phase 2 — Side track at ±4,140' to an approximate depth of 4,280' TVD 1. Prepare location for coiled tubing operations. 2. Mobilize 2 -3/8" coiled tubing unit. 3. Rig up 2 3/8" unit on wellhead and test BOPs to 5,000 psig. A coil tubing run may be required to establish correlation to PBTD. 4. Pick up and run 5" whipstock on coiled tubing per service company procedures. 5. Space out and set whipstock to start window at a depth of ±4,140'. 6. Pick up and run a straight hole motor, window mill, and dressing mill to mill a window in 5" casing off of whip stock. Estimated length of window is ±8.9'. a. Directional control of the sidetrack is not required. b. Take pressure readings to evaluate pump pressure and back pressure effects. Establish flow rates at approximately one barrel per minute increments. Record pump pressure with back pressure increments of 250 psig from zero to 750 psig as measured at the discharge manifold choke. c. After window has been cut, pullback into casing, shut in well and monitor SITP to establish a BHP. d. Continue to mill approximately 10' of new formation. Pullback into casing, shut in well and monitor SITP to establish a BHP. e. Pressure up and conduct a leakoff test to a 20 ppg EMW. Increase the pressure in 0.25 bbl increments and plot pressure. When pressure departs from straight line, contact Mick Francisco (713- 301 -2216) and Eddie Wright (713- 823 -7789) in Houston to discuss further operations. i. If the drilling fluid weighs 9.5 ppg and hole depth is 4150' TVD, then the maximum test pressure is 2,266 psig. f. Pull out of hole and measure window mill and reaming mill. If mill is under gauge, run a motor and dressing mill to dress window. 7. Run a bent - housing motor and drilling assembly and continue drilling the well to a depth of approximately 4,280' TVD per directional plan. Page 5 of 6 • a. Circulate minimal weight drilling fluid to minimize formation invasion. b. During drilling operations, pullback into casing and evaluate formation pressure increases by shut in well and monitor SITP to establish a BHP. c. Maintain sufficient backpressure at surface to balance formation pressure. Increase drilling fluid weight when back pressure exceeds 1,000 psig or when back pressure causes drilling problems with downhole motor. d. Evaluate and report formation pressure build up and estimated bottom hole pressures. 8. Circulate hole clean. 9. Pull coil out of hole. 10. Rig up flowback equipment. Equipment may include an open top tank and gas buster for initial testing. 11. Open well and flow to tank to verify formation fluids. If sufficient gas is shown, flow gas through flare line to estimate gas flow and possibly obtain samples. Note: Capacity of 5" at 4,250' is approximately 70.3 barrels. 12. Shut well in for pressure build up. Estimate BHP and EMW. Note: DO NOT KILL WELL! 13. Further activities will be established after reservoir fluids are determined. Phase 3 — Completion or P &A Procedures will be developed pending results of flowback. Page 6 of 6 • • RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19 API No.: 50- 099 - 50005 -00 RKB 2037.0 18.3 Current Wellbore Schematic GL 2018.7 10/28/06 Depth Casing /Cement Completion: 2 -7/8" 6.5# L -80 EUE Tubing Li 78' BGL 13 -3/8" 68# L -80 Conductor Shoe Squeezed with 18.3 bbls 12 -1/4" Z 1,226 9 -5/8" 40# L -80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" Z 1,915 7" 26# L-80 BTC Intermediate Wellbore Fluid Above Packer: 66 bbls Class G to surface 9.0 ppg KCL brine with oxygen scavenger and corrosion inhibitor. Top 20' is diesel for freeze protection. 3,200 Top of cement (CBL) E -Line Perfs: 4232 4250 = =_ Drill Perf Tool Channel: 4382 —_ 4387 — Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner 4,635 Weatherford E -IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L -80 STL Intermediate Perforations: 4674 4680 = 53 bbls Class G 4922 4940 =_ 4923 4929 4932 4938 5010 5020 — 5076 5084 =_ 5,099 PBTD 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 • I RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -1 9 API No.: 50- 099 - 50005 -00 Proposed Plugback Welibore Schematic RKB 2037.0 18.3 6/6/07 GL 2018.7 Depth Casing /Cement Completion: 2 -7/8" 6.5# L -80 EUE Tubing 78' BGL 13 -3/8" 68# L -80 Conductor Shoe Squeezed with 18.3 bbls 12 -1/4" L 1,226 9 -5/8" 40# L -80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" 1,915 7" 26# L -80 BTC Intermediate Wellbore Fluid Above Packer: 66 bbls Class G to surface 9.0 ppg KCL brine with oxygen scavenger and corrosion inhibitor. Top 20' is diesel for freeze protection. 3,200 Top of cement (CBL) 4,195 TOC - placed with dump bailer 4,220 Mechanical Plug E -Line Perfs: 4232 4250 Drill Perf Tool Channel: 4382 4387 Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner Zr‘e.<7N 4,635 Weatherford E -IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L -80 STL Intermediate Perforations: 4674 4680 53 bbls Class G 4922 4940 4923 4929 — —_ 4932 4938 5010 5020 5076 5084 =_ 5,099 PBTD e/ S4441 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 • • RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19A API No.: 50- 099 - 50005 -00 Proposed Side Track Wellbore Schematic RKB 2037.0 18.3 6/10/07 GL 2018.7 Depth Casing /Cement Completion: 2 -7/8" 6.5# L -80 EUE Tubing L 78' BGL 13 -3/8" 68# L-80 Conductor Shoe Squeezed with 18.3 bbls 12 -1/4" Z 1,226 9 -5/8" 40# L-80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" Z 1,915 7" 26# L-80 BTC Intermediate Wellbore Fluid Above Packer: 66 bbls Class G to surface 9.0 ppg KCL brine with oxygen scavenger and corrosion inhibitor. Top 20' is diesel for 3,200 Top of cement (CBL) freeze protection. Top of Whip Stock at 4129' ±4,140 Top of Window Whip Stock Anchor at ±4,153' ±4,149 Bottom of Window TOC - placed w/ dump bailer 4180 -4195 Mechanical Plug 4,220 Evaluate zone ±4,230- 4,250' E -Line Perfs: 4232 4250 Drill Perf Tool Channel: 4382 4387 End of Side track at ±4,280' Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner 4,635 Weatherford E -IRBP (Inflatable Ret. BP) 4,639 5" 17.8# L-80 STL Intermediate Perforations: 4674 4680 = 53 bbls Class G 4922 4940 4923 4929 4932 4938 5010 5020 5076 5084 5,099 PBTD 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 1 • RUTTER & WILBANKS CORPORATION Sec 4, T4N, R3W AHTNA #1 -19A API No.: 50- 099 - 50005 -00 Proposed Completion Welibore Schematic RKB 2037.0 18.3 6/20/07 GL 2018.7 Depth Casing /Cement Completion: 2 -3/8" Coil Tubing 78' BGL 13 -3/8" 68# L -80 Conductor Shoe Squeezed with 18.3 bbls 12 -1/4" Z 1,226 9 -5/8" 40# L -80 BTC Surface 20 bbls Permaforst & Class G 8 -1/2" Z 1,915 7" 26# L -80 BTC Intermediate Welibore Fluid Above Packer: 66 bbls Class G to surface 9.0 ppg KCL brine with oxygen scavenger and corrosion 3,200 Top of cement (CBL) inhibitor. Top 20' is diesel for freeze protection. ► ► 4,100 Packer with seal assembly Top of Whip Stock at 4129' 4,125 End of Tubing ±4,140 Top of Window Whip Stock Anchor at ±4,153' ±4,149 Bottom of Window TOC - placed w/ dump bailer 4180 -4195 Mechanical Plug 4,220 Evaluate zone ±4,230- 4,250' E -Line Perfs: 4232 4250 Drill Perf Tool Channel: 4382 —_ 4387 End of Side track at ±4,280' Top of cement 4,536 (placed with dump bailer) 4,577 Top of 3 -1/2" Liner 4,635 Weatherford E -IRBP A 6 (Inflatable Ret. BP) 4,639 5" 17.8# L -80 STL Intermediate Perforations: 4674 4680 53 bbls Class G 4922 4940 4923 4929 4932 4938 5010 5020 —_ 5076 5084 =_ 5,099 PBTD / 'Ss 5,165 3 -1/2" 8.8 L -80 STL Prod. Liner Total Depth (MD & TVD) 5,165 P.O. BOX 3146 • MIDLAND, TEXAS 79702 oice Number Invoice Date Explanati Gross Am • Deductions Amount Paid Application fee for Permit 100.00 to drill (Form 10 -401) for tna #1 -19A WESTERN NATIONAL BANK R UTTER AND WILBANKS 7o i Od 2 d xpj 88 1163 MIDLAND, TEXAS CORPORATION *We �•1 ?.._.1_._ Nets P.O. BOX 3146 • MIDLAND, TEXAS 79702 //�6f�� v�// ?stelae Vendor No. Check Date Check No. Amount 6 -15 -07 7703 $100.00 Pay ** *ONE HUNDRED AND NO /100 * ** the rder of ALASKA OIL & GAS CONSERVATION COMM. RUTTER AND WILBANKS CORPORATION ATTN: TOM MAUNDER • 333 W 7th AVE. STE. 100 •,..._,.. ANCHORAGE, AK 9 9 5 01 � �, " � ='� "02388311' 1:LL63073701: 8096980 Le I TRANSMITTAL LETTER CHECKLIST WELL NAME / V7 - ,V,G, A/9 PTD# Development Service ✓ Exploratory Stratigraphic Test Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK i ADD-ONS ` TEXT FOR APPROVAL LETTER (OPTIONS) APPLIES I MULTI LATERAL The permit, is for a new wellbore segment of existing well (If last two digits in I API number are . Permit No. , API No. 50- - - between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), (f), ail records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - ) from records, data and logs acquired for well SPACING / The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing 1 exception. assumes liability of any protest to the spacing exception that may occur. the DRY DITCH ! i / All dry ditch sample sets submitted to the - Commission must be in SAMPLE I no reater than 30' sample intervals from below the g � p permafrost or I from where samples are first caught and 10' sample intervals through target zones. Please note the following, special condition of this N !t Conventional / production or production testing of coal bed methane is not allowed I for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing i program Rev: I '25i06 C:'Jody\transmittal checklist WELLJER -GHEcK ST Field & Pool Well Name: AHTNA 1 -19A Program EXP Well bore seg ii PTD#: 2070850 Company RUTTER AND WILBANKS CORPORATION __ Initial Class/Type EXP / PEND _GeoArea 815 _ __ Unit 00000 On /Off Shore On Annular Disposal ❑,i Administration 1 Permit fee attached No 2 Lease number appropriate NA 3 Unique well name and number Yes 4 Well located in a defined pool No Exploratory well 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included No 9 Operator only affected party Yes 10 Operator has_appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 6/15/2007 13 Can permit be approved before 15 -day wait Yes III- 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre- production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(f.1.A)42.A -D) NA Engineering 18 Conductor string provided NA Conductor installed in Ahtna 1 -19 (205 -015). 19 Surface casing protects all known USDWs NA Surface casing installed in Ahtna 1 -19. 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing installed in Ahtna 1 -19. 21 CMT vol adequate to tie -in long string to surf csg NA Production casing installed in Ahtna 1 -19. 22 CMT will cover all known productive horizons No Open hole completion planned. 23 Casing designs adequate for C, T, B & permafrost NA Original well met design specifications. 24 Adequate tankage or reserve pit Yes Steel tanks provided for drilling fluids. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 307 -193 26 Adequate wellbore separation proposed Yes Nearest segment is original wellbore. 27 Ifdiverter required, does it meet regulations NA BOP stack will already be in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Hole to be drilled using dynamic overbalance using 9.5 ppg fluid and applied pressure. Underbalanced drilling TEM 6/15/2007 29 BOPEs, do they meet regulation Yes not planned. gkiv\ 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 3679 psi. 10K equipment planned. 5000 psi BOP test planned. 411 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S was not reported when the original penetration was drilled. 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures Yes 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 6/15/2007 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] Yes Eddie Wright - 432 - 683 -1824 I Date: Geologic Engineering Commissioner: Date Public Date Need proposed deviation survey and filing fee. • Commissioner: issioner D 1 s (1 I 5/1 e-/-r-D7 A (
