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Home My WebLink About208-1612023-0220_Surface_Abandon_MPU_S-41A_bn Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2/20/2023 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector MPU S-41A Hilcorp Alaska LLC PTD 2081610; Sundry 322-518 2/20/2023: I traveled to Hilcorp’s MPU S-41A and met with Josh McNeal to discuss what they had already competed on the well’s plugging and abandonment. He said the well had a 30-inch by 20-inch insulated conductor and they had already welded a “donut” over it. Josh and I went over to inspect the well and it was found to have good hard cement. You could clearly see the 9 5/8-inch pipe string. It was found to be cut off 5 feet below the tundra level. I inspected the marker plate (20-inch diameter; ¼-inch thick). It had the correct oil company name, well name, and PTD and API numbers. Everything looked good. I OK’d then to weld the marker plate and backfill the hole. Attachments: Photos (3) 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.08 14:44:41 -08'00' 2023-0220_Surface_Abandon_MPU_S-41A_bn Page 2 of 3 Surface Abandonment – MPU S-41A (PTD 2081610) Photos by AOGCC Inspector B. 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W |fVerified, How? Other (specify incomments) Offshore? El Subsequent - Date AOG[{Notified: 9/18/2020 ' Operator: Hi|corpAlaska, LLC OperatorRep: Jon Arend Wellbore Diagram Avail? 6� Well Pressures (pui): Tubing: O - Fluid inCellar? [] ' |A: O BPV|nstaUed7 El DA: 0' VRP|ug(s)|nstaUed7 LJ Wellhead Condition All ofthe valves onthe appeared ingood working order with working gauges onthe Tubing, |Aand OA. There are noVR ' Plugs nrBPVinstalled. Condition ofCellar Good Condition. I did not observe and excessive water in cellar, trash or any sheen. `^ Surrounding Surface Condition Everything looked good. | did not see debris orsheen around the pad. Comment,, | verified the location using the pad map. ' Supervisor Comments Photos (2) attached � Monday, September 28'2O20 a CD (h ItT aC'4 � N X 0 m O C CV O V Q U Q m Q C N � — U 3 ^ Q O YJ Gni C (0 Q QU•^c�v� V O 30�� Cl) Qaa .. EI . STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMOSION SEP 2 3 2015 • REPORT OF SUNDRY WELL OPERATIONS ` 1.Operations Abandon U Plug Perforations Fracture Stimulate U Pull Tubing LlOperations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Inspect Well ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: e +ate Hilcorp Alaska,LLC Development[ • Exploratory ❑ 208-161 1. 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23401-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380110/ADL0380109 ^ MILNE PT UNIT UGNU S-41A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): .....Mia" N/A MILNE POINT/UGNU UNDEFINED OIL ' 11.Present Well Condition Summary: Total Depth measured 7,605 feet Plugs measured Surface&283 feet true vertical 3,807 feet Junk measured 601 feet Effective Depth measured Surface feet Packer measured 3,968 feet true vertical Surface feet true vertical 3,385 feet Casing Length Size MD ND Burst Collapse Conductor 120' 20" 120' 120' Production 4,140' 9-5/8" 4,140' 3,477' 6,870psi 4,760psi Liner 3,637' 7" 7,605' 3,735' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet 4-1/2" 12.6#/L-80/Hyd 563 N/A N/A Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/IBT-Mod N/A N/A 3,968(MD) Packers and SSSV(type,measured and true vertical depth) C-2 ZXP N/A 3,385(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A scpy EU 'I r JI5 Treatment descriptions including volumes used and final pressure: N/A �® 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070..25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑l Exploratory❑ Development[ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP[ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Stan Porhola Email sporholac hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature +� 0 ' ' _ Phone 777-8412 Date 9/22/2015 /aa6'i S �J/�RBDM SEP 2 5 2015 Form 10-404 Revised 5/2015 ,"•' Submit Original Only • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hilcorp.LLC Well Name: MPS-41A Oper.Rep: Bill Kruskie PTD No.: 208-161 Oper.Phone: 1-907-670-3387 Location Verified? Yes Oper.Email: wkruskie(Sthilcora.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Date AOGCC Notified: 08/21/15 Suspension Date: 10/29/12 Type of Inspection: Subsequent Sundry No.: 312-411 Wellbore Diagram Avail.? Yes Photos Taken? Yes Well Pressures(psi): Tubing 0 IA 0 OA 0 Condition of Wellhead: Good,no visable leaks and all gauges are installed,wellhouse,well head sign installed,well has two working vales in the tree. Condition of Surrounding Surface Location: Good. Follow Up Actions Needed: No Comments: Map on location. Attachments: Pictures REVIEWED BY: Area map Insp.Supry WBS Comm PLB 12/2014 MPS-41A 2015 Suspended Well Inspection Form . ,. H Gen 5 Wellhead:FMC d w dry ole 5M MPU S-41 A Radigan Wellhead w dry Hole Tree Q, Orig.KB Elev.=72' Tubing head:11"x 4-112", "` Orig. GL Elev. =38.1' FMC tbg hanger TCII wl 4""H"BPV Ilihr..ra 11».La.1.1.1I 20" Barrier#2-15.7 ppg Arctic 92 Ibift,H-40 Welded 112' Set 1 cement from-283' Insulated to surface / Top of barrier#1-283' 15.8 ppg Class G Daily Operation report from 11/12/2008 reported 12 bbls of cement observed at surface during ,--Cement Retainer at 477' the 9-5/8"casing job Also.cement The junk has been milled is visiblesible from surface when lookingAIN. and pushed to 601'. past the landing ring. Injectivity has been estab- lished. 475 bbls of 15.8 ppg Class Top of fish unknown.Recovered G to fill wellbore -1786'(43 joints). 3345'of com- pletion in hole. l.. 4.5"NDPG multi drop tbg gauge There are no DPZ's present 9 5/8"47#,L-80,BTC between the Ugnu and surface Csg.drift ID=8.525". I Csg.ID=8.681" > 3968' Burst=6870 psi 7"x 9-5/8"C-2 ZXP Collapse=4750 psi X Liner Top Pkr. _ '4.5"SLB DCIN Chem Inj Mandrel 9-5/8"Casing Shoe 4140' ir- ,tea 4.5"WFD Pump Seating Nipple �_ S�0 4.5"12.6 ppf,L-80,Hydril 563 SC tbg01114.5"WFD Drain Sub/3996 psi shear (Drift ID 3.833" -Capacity=.0152 bpf) XO 4-1/2"HYD x 3-1/2"IBT 3.5"9.3 ppf,L-80.IBT-Mod Tbg 1 ■ i (Drift ID 2.867" -Capacity=.0087 bpf) ; eOW.1 i 3.5"NDPG multi drop Annular gauge Imll•I ; 3.5"NDPG multi drop tbg gauge 7"26#,L-80,BTC-M Casing Csg.ID=6.276"Csg drift ID=6.151" WFD PCP Stator XXXL 327-6000 Burst=7240 psi Collapse=5410 psi I 3.5"NDPG single drop tbg gauge MI It 3.5"WLEG Top of MPS-41 7"Casing Stub @ 4275'MDI I 1 I 7"29#slotted liner from MPS-41 P&A'di• 4800'-4880' 7"L-80 Casing 5250'-6250' TD:5077' 6800'-7600' 8-1/2"Hole 7"26*solid liner 4000'-4800' I 4880'-5250' i 1 6250'-6800' I I MPS-41 Open Hole Sidetrack 7"Liner Shoe @ 7605'MD c__ = d Well Inclination @ shoe=90 degrees Ugnu Horizontal 8-1/2"Hole DATE REV BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS-41 Pilot hole&Horizontal Sidetrack WELL*:MPS-41A 8/24/10 REH FCO-run CHOPS completion-4ES API NO:50-029-23401-01-00 8/10/2012 Doyon 14 Attempt to de-complete-Install Kill String. 1 • • no 011111 "MI Eli►. rY , (J . tom_• rt WELL NAME MPS-41A 4.r I,-aaof x rsliq .1 • 41 4 . - _ • ":.`,"7-',' a 2.l �I I « i �ralr. 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Yes Oper.Email: Milne-WellsiteSupervisors(0 hi If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 10/29/12 Date AOGCC Notified: 08/20/15 Sundry No.: 312-411 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 - Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: Two gate valves. Condition of Surrounding Surface Location: Good - Follow Up Actions Needed: None Comments: Location verified by site map. Photos taken by operator available upon request. - Attachments: none / REVIEWED BY: l Insp.Supry 37,e 1(5611 Comm l PLB 06/2014 SCANNED SEP 1 5 2016 2015-0823_Suspend_MPU_S-41A_cs.xlsx RECEIVED STATE OF ALASKA NOV 2 12012 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG V la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended ' 1b. Well Class 20AAC 25.105 20AAC 25.110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero . =' Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 10/29/2012 208 - 161 - 312 - 411 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 12/07/2008 50 029 43401 - 01 - 00 • 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/12/2008 MPS -41A 3224' FSL, 518' FEL, SEC. 12, T12N, R10E, UM 8. KB (ft above MSL): . 71.53' 15. Field / Pool(s) Top of Productive Horizon: 4559' FNL, 2629' FEL, SEC. 07, T12N, R11 E, UM GL (ft above MSL): ' 37.79' , Milne Point / Ugnu Undefined ' Total Depth: 9. Plug Back Depth (MD +TVD) 4502' FNL, 1356' FEL, SEC. 07, T12N, R11 E, UM Surface Surface 4b. Location of Well (State Base Plane Coordinates, NAD: 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x - 565493 y - 5999889 Zone ASP4 , 7605' 3807' ADL 380109 & 380110 TPI: x- 568196 y - 5997410 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 569469 Y - 5997478 Zone- ASP4 None 18. Directional Survey: 0 Yes IN No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1397' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR / GR / RES, DEN / NEU w /ACAL, IFR / CASANDRA 4140' 3477' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 92# H -40 Surface 120' Surface 120' 48" 260 sx Arctic Set (Approx.) 9 -5/8" 47# L -80 36' 4140' 36' 3477' 12 -1/4" 630 sx DeepCrete, 116 sx Class 'G' 7" 26# L -80 3968' 7605' 3385' 3807' 8 -1/2" Uncemented Slotted Liner 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ",12.6# x 3 -1/2 ", 9.2 #, L -80 Unknown None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. MAR ® � 2013 WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ® No SCANNED G 1 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 477' - PBTD Cement Retainer, 475 Bbls Class 'G' 283' - 477' 14 Bbls Class 'G' Surface - 283' 21 Bbls Arctic Set 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested: Production For OIL -BBL: GAS -MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL - BBL: GAS - MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes _i No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ? f,ifi6 . i0V 26 2C 6 Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE / / -1.-/3 Submit Original Onl 29. GEOLOGIC MARKERS (List all formations an kers encounter 30. FORMATION TESTS NAME MD TVD Well Tested ?. Yes ® No Permafrost Top 37.79' 37.79' If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 1451' 1435' results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. M87S 4473' 3632' None M87F 4721' 3717' M8OT 4789' 3735' M8OT 6324' 3765' M8OT 6774' 3777' / Formation at Total Depth: 31. List of Attachment: Summary of Daily Drilling Reports and Well Work summary, Well Schematic Diagram. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin, 564 -4387; Sean.McLaughlin @bp.com Email: Joseph.Lastufka @bp.com Printed Name: Title: Drilling Technologist n:Jo Stu 41 / 1 / .Z Signatur...... Phone 564 4091 Date: 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 Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only • • Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/25/2012 12:00 - 00:00 12.00 RIGU P DECOMP SB PRODUCTION PED UP RIG S- RISERTAND, Y SET WHILE WELL HOUSE ON M -39 PULLED BPV FOR PRODUCTION WORK AFTER SETTING FLOWLINE. -ADRONT OF MPROS -41S , AND PREP SITE PADS TO LEVEL MOVE PAD RIG IN OVER WELL 9/26/2012 00:00 - 03:00 3.00 RIGU P DECOMP RIG STANDBY WHILE ROADS AND PADS LEVEL PAD IN FRONT OF MPS -41A. 03:00 - 07:00 4.00 RIGU P DECOMP SET MATS AND PREP TO MOVE RIG OVER WELL MPS -41A. =DEEP CLEAN AND KILL WT FLUIDS ON STANDBY ON TEXACO PAD. 07:00 - 09:30 2.50 RIGU P DECOMP PJSM, MOVE OVER AND SPOT RIG OVER WELL MPS -41A. -SHIM RIG, SET LANDINGS AND STAIRS, INSTALL HAND RAILS. 09:30 - 10:30 1.00 RIGU P DECOMP SKID RIG FLOOR INTO DRILLING POSITION. 10:30 - 12:00 1.50 RIGU P DECOMP RIG FLOO, MAKE _ U -TU BE, AIR, R STEAM AND UP GAS WATER BUSTER LINES. 12:00 - 16:00 4.00 RIGU P DECOMP TOD RIG UP, , WASHER AND BERM, SET FLOOR BREAK SET TRAILER A C, RIG UP BEAVER SLIDND E, DID ONNECTED A DERRICK POWER INSPECTION, BRING ON SEA WATER. -ACA, SE SHUT DOWN BOILER TION DRILL FIRE TE SHUT T EMD OW RGENCY N, AND SCR SHUT DOWN. ALL WORKED CORRECTLY RIG ACCEPT AT 12:00 16:00 - 19:00 3.00 PULL P DECOMP T LA 3500 FOR 5 CHARTED EST UBRIC MINUTES , 250 AND LOW/ PULL BACK HIGH PRESSURE VALV E 19:00 - 22:00 3.00 PULL P DECOMP RIG UP AND TEST LINES, IA AND TUBING, PUMP LINES FOR BULLHEADING 22:00 - 00:00 2.00 PULL P DECOMP P WITH 290 PUMP BBL 5 DEEP BBLS CLEAN ER MINUTES AND 78 BBL DOWN DEEP IA CLEAOW A 1.4 MINUTE CHASE B I T PILLS WBBLS ITH S PER EA WATER TOTAL K ES IA AND 156 FORA STOKES DO WN 580 TUBING. STO IA= 1250 DOWN PSI, TUBING= 760 PSI. TOTAL OF 736 BBLS PUMPED. 9/27/2012 00:00 - 01:00 1.00 WHSUR P DECOMP PUMP 5 BARRELS PER UWN WITH 290 BBL DEEP CLEAN MIN AND TES 78 DO BBL IA DEEP CLEAN DOWN TUBING AT 1.4 BARRELS PER MINUTE. CHASE BOTH PILLS WITH SEA WATER FOR A TOTAL OF 580 BARRELS DOWN N DOW TUBING. IA= 1250 IA PSI D TUBING BARRELS = 760 PSI DURING CIRCULATION. - IEND EDU HAD 250 SHUT N PSI W AND LL A IA HAD MONITOR 310 PSI. . T LEFT SHU T IN FOR 30 MINUTES. TUBING HAD 200 PSI AND IA HAD 270 PSI. Printed 11/19/2012 11:34:28AM a A Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 03:00 2.00 WHSUR P DECOMP - PERFORMED STEP DOWN BLEED OFF TEST. BLED DOWN 50 PSI ON TUBING AND 40 ON CASING WITH A TOTAL OF 5.5 BBLS BLED. SHUT IN FOR 20 MINUTES WITH NO INCREASE. BLEED DOWN 50 PSI ON TUBING AND 40 PSI ON IA (100/190) SHUT IN FOR 20 MINUTES WITH NO INCREASE. - INDICATIONS ARE WELL WAS CHARGED DURING BULLHEADING OPERATIONS. 03:00 - 06:00 3.00 WHSUR P DECOMP -STARTED BLEEDING TUBING DOWN FROM 100 PSI TO 30 PSI, IA WAS 190 DOWN TO 130. - SWITCHED OVER TO IA TO BLEED DOWN. 06:00 - 07:00 1.00 WHSUR P DECOMP SHUT IA IN, PRESSURE AT 20 PSI, MONITOR WELL. -OPEN IA BLEED OFF .5', BBL 07:00 - 07:30 0.50 WHSUR P DECOMP SHUT IN IA FOR 15MINUTES, PRESSURE AT 17 PSI, VERIFIED IA IS DEAD. -OPEN UP IA, ZERO PRESSURE, SHUT IN SECURE WELL BULLHEADED 736 BBLS TOTAL, BLEED OFF RETURNS = 84 BBLS TOTAL 07:30 - 08:00 0.50 WHSUR P DECOMP-.-PJSM WITH DRILL SITE MAINTENANCE, INSTALL TWO WAY CHECK -PRESSURE TEST LUBRICATOR TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 CHARTED MINUTES. BOTH TEST GOOD. 08:00 - 09:00 1.00 WHSUR P DECOMP RIG UP ON IA WITH INJECTION LINE 09:00 - 10:30 1.50 WHSUR P DECOMP ATTEMPT IA TEST FROM BELOW WITH 500 PSI, UNABLE TO OBTAIN A GOOD TEST -RIG UP AND TEST FROM ABOVE 250 PSI LOW/ 2000 PSI HIGH FOR 5 CHARTED MINUTES, BOTH TEST GOOD 10:30 - 12:00 1.50 WHSUR P DECOMP PJSM WITH FMC ON NIPPLE DOWN TREE, FMC TO BLEED OFF PRESSURE ON HANGER VOID - NIPPLE DOWN TREE AND STAND BACK IN CELLAR 12:00 - 16:00 4.00 BOPSUR P DECOMP NIPPLE UP BOP STACK 16:00 - 18:00 2.00 BOPSUR P DECOMP CHANGE OUT LOWER RAMS FROM SOLID 4 -1/2" TO VBR'S 2 -7/8" X 5" RAMS 18:00 - 00:00 6.00 BOPSUR P DECOMP RIG UP AND TEST BOP, 3.5 TEST JOINT, 2 XT 39 FULL OPENING SAFETY VALVE, 250 PSI LOW/ 2000 PSI HIGH FOR 5 CHARTED MINUTES EACH, -BOP DRILL -6 BBL TO FILL GAS BUSTER. - TESTED ANNULAR, MANUAL IBOP, 2 X 4" FOSV, 4" DART VALVE, 4" KILL LINE IN PITS, VALVES # 1, 5, 6, 8, 12, 13, 14 - FILLING HOLE THRU IA CONTINUALLY AND CHECKING PIT LEVELS EVERY 30 MINUTES. AVG 10 -12 BBLS/HR LOSS. * *JOHN CRISP (AOGCC) WAIVED WITNESS TO TEST (CALLED @ 20:30 9/27/12) ** Printed 11/19/2012 11:34:28AM firth America ALASKA c w Y 0 . -x i9n S umma r ■ Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:OOAM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS-41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/28/2012 00:00 - 07:00 7.00 BOPSUR P DECOMP CONTINUE TEST BOPE'S, TEST UPPER RAMS (WITH 3.5" PIPE (NORMAL TEST AND MPL TEST) AND WITH 4.5" PIPE (NORMAL TEST AND MPL TEST)), LOWER PIPE RAMS (WITH 3.5" PIPE (NORMAL TEST AND MPL TEST) AND WITH 4.5" PIPE (NORMAL TEST AND MPL TEST)), HYDRAULIC AND MANUAL CHOKE RAW -DOWN, 07:00 - 11:30 4.50 BOPSUR P - DECOMP RIG UP DRILL SITE MAINTENANCE TO PULL TWO WAY CHECK WITH DUTCH RISER 11:30 - 12:00 0.50 BOPSUR P - DECOMP TEST TWO WAY CHECK, 250 PSI LOW/ 3500 PSI HIGH FOR 5 CHARTED MINUTES 12:00 - 13:00 1.00 PULL P - DECOMP RIG DOW LUBRICATOR AND DUTCH RISER. FIRE DR LL/ RIG EVACUATION 13:00 - 14:00 1.00 PULL P — DECOMP RIG UP TCII ON 4" DRILL PIPE, SCREW INTO , HANGER AND PULL BANGER TO RIG FLOOR. - HANGER PULL WEIGHT =15K 14:00 - 15:00 1.00 PULL ( P . , DECOMP SCREW TOP DRIVE INTO4 "DRILL PIPE AND CIRCULATED BOTTOMS UP. 5.5 BBL AT 50 i PSI. .. - STATIC LOSS RATE= 12 BPH 15:00 - 15:30 0.50 PULL Ill , DECOMP LAY DOWN HANGER AND RIG UP TO PULL 4.5 _ TUBING 15:30 - 17:30 2.00 PULL - Ka DECOMP " "LAY DOWN 48 JOINTS OF 4.5 12.6# TUBING 17:30 - 18:30 •1 PULL c P DECOMP DEMOBILIZE 4.5 HANDLING EQUIPMENT FROM RIG FLOOR, PICK UP WEAR RING AND TEST PLUG 18:30 - 19:30 1.00 PULL P DECOMP PULL ISOLATION SLEEVE AND INSTALL �� " .. WEAR RING 19:30 - 20:30 1.00 FISH P DECOMP MOBILIZE BOTTOM HOLE ASSEMBLY TO RIG - FLOOR 20:30 - 22:00 1.50 FISH P-- 11111 — DECOMP MAKE UP BOTTOM HOLE ASSEMBLY #1 22:00 - 00:00 2.00 FISH P DECOMP PICK UP DRILL PIPE FROM PIPE SHED 1X1 AND SINGLE IN TO HOLE FROM 222' TO 1446' 9/29/2012 00:00 - 00:30 0.50 FISH P -_ DECOMP CONTINUE TO PICK UP DRILL PIPE FROM 1446' AND RUN IN HOLE. TAG FISH AT 1562'. 00:30 - 02:00 1.50 FISH P DECOMP PICK UP AND ESTABLISH FISHING PARAMETERS. - 4 BPM AT 120 PSI. - UP WEIGHT = 80K LBS; DOWN WEIGHT = 75K LBS; ROTATING WEIGHT = 75K LBS. - 80 RPM; 3 -5K FT -LBS TORQUE. WASH DOWN OVER FISH TO 1577'. SET 6K LBS DOWN AND SET ON TOP OF FISH. FISH DID NOT MOVE DOWNHOLE FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM. 02:00 - 05:00 3.00 FISH P DECOMP LAY DOWN SINGLE JOINT OF 4" DRILL PIPE. CHANGE FROM LONG BALES TO SHORT BALES AND RIG UP TO PULL OUT OF THE HOLE. PULL SLOWLY FROM 1552' TO 317' -- PULLING OUT OF THE HOLE. 05:00 05:30 0.50 FISH P ■- DECOMP FLOW CHECK WELL O 10 MIN PRIOR TO PULLING BHA. STAND ND BACK CK 2 STANDS OF 4 -3/4" SPIRAL COLLARS. Printed 11/19/2012 11:34:28AM 1' ti r e Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 06:30 1.00 FISH P DECOMP STAND BACK 4 -3/4" DRILL COLLARS - CLEANED 10 -15 POUNDS OF DEBRIS OUT OF SHOE - RETRIEVED 50 -60 POUNDS OF METAL OUT OF JUNK BASKET. -LAY DOWN JUNK BASKET AND WASH PIPE EXTENSION 06:30 - 07:00 0.50 FISH P DECOMP " MAKE UP 8 -1/8" OVER SHOT WITH BUMPER SUB AND OIL JAR WITH 6 4-3/4" DRILL COLLARS. 07:00 - 08:00 1.00 FISH P DECOMP RUN IN HOLE FROM 206' TO 1536', PICK UP SINGLE JOINTS FROM PIPE SHED. - TAGGED FISH AT 1562' 08:00 - 09:30 1.50 FISH P DECOMP ATTEMPT TO ENGAGE OVERSHOT ON FISH 4 TIMES TO SEE IF GRAPPLE IN GAUGE, UNABLE TO ENGAGE, - ROTATE DRILL PIPE 20 RPM AND SLACK OFF WITH OVER SHOT, UNABLE TO ENGAGE. -PUMP 7 BARREL PER MINUTE AT 210 PSI, LATCH ON TO FISH, PICK UP 128', FISH CAME OFF, SLACK OFF AND CHASE FISH DOWN, LATCH UP AGAIN, FISH CAME LOOSE AGAIN WITH 228K -CHASE FISH DOWN TO 1603', SET 20K ON FISH, VERIFIED FISH AT 1603' -FLOW CHECK WELL FOR 10 MINUTES, HOLE TAKING FLUID 09:30 - 11:00 1.50 FISH P DECOMP PULL OUT OF HOLE FROM 1603' TO 222' 11:00 - 12:00 1.00 FISH P DECOMP FLOW CHECK FOR 10 MINUTES, WELL TAKING FLUID - CONTINUE PULL OUT OF HOLE, STAND BACK DRILL COLLARS. - LAY DOWN OVER SHOT ASSEMBLY AND PICK UP SPEAR ASSEMBLY AND CROSS OVER 12:00 - 12:30 0.50 FISH P DECOMP LUBRICATE RIG 12:30 - 13:30 1.00 FISH P DECOMP PICKUP BOTTOM HOLE ASSEMBLY #3. -RUN IN HOLE TO 1602' - ESTABLISH PUMP PARAMETERS (SLOW PUMP RATES) 13:30 - 14:00 0.50 FISH P DECOMP TAG FISH AT 1602', SLACK OFF 5K -10K, PUMP 3 BPM AT 240 PSI, PRESSURED UP TO 1200 PSI WHEN TAGGED FISH TOP, PICKED UP AND PRESSURE DROPPED OFF TO 240 PSI. - CONTINUE TO SLACK OFF ONTO FISH WITH THE SAME RESULTS MULTIPLE TIMES. - TURN PUMP OFF AND TRY ENTERING FISH TOP, THEN TRIED WITH A COUPLE TURNS TO THE RIGHT WITH NO SUCCESS. PICK UP WEIGHT= 77K, SLACK OFF WEIGHT= 67K 14:00 - 15:30 1.50 FISH P DECOMP FLOW CHECK FOR 10 MINUTES, WELL TAKING FLUID -PULL OUT OF HOLE FROM 1602' TO 210', STAND BACK DRILL COLLARS AND LAY DOWN SPEAR 15:30 - 17:30 2.00 FISH P DECOMP MAKE UP BOTTOM HOLE ASSEMBLY #4, 8 -1/2" JUNK MILL, 2 BOOT BASKETS, 6 DRILL COLLARS -RUN IN HOLE FROM 219' TO 1602' Printed 11/19/2012 11:34:28AM . . • AFE No Common Well Name: MPS-41 Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 21:30 4.00 FISH P DECOMP TAG FISH AT 1602', PUSHED FISH DOWN H OLE TO 1611' G= 80K, SLACK OFF W PICK EIGHT UP = WEI 80K, ROTATING HT WEIGHT= 80K, GA PE= , ON= 0, PSI OFF= 670, RPM= 100, TORQUE 450PSI ONI =2 -3 TORQUE LLON OFF = MINUT 1 K, WEIGHT ON BIT= 10 -15K 21:30 23:00 1.50 FISH P DECOMP FLOW CHECK FOR 10 MINTUES, WELL TAKING FLUID -PULL OUT OF HOLE FROMM 1611' TO 219', STAND BACK DRILL COLLARS, BREAK OUT MILL ASSEMBLY, JUNK BASKETS EMPTY 23:00 - 00:00 1.00 FISH P DECOMP MAKE UP BOTTOM -HOLE ASSEMBLY #5, 8 " X " O E RU IN HOLE 4 -9/16 FD M S 232 O TO F 897 SHOE 9/30/2012 00:00 - 00:30 0.50 FISH P DECOMP RUN IN HOLE FROM89T TO 1611' WITH BHA #5, DRESS OFF FISH WITH 8 -1/8" WASH OVER ASSEMBLY- SWALLOWED 15' OF FISH WITH WASHOVER ASSEMBLY 00:30 - 01:00 0.50 FISH P DECOMP ESTABLISH W ' - PICK UP WEIGHT SLO =80K , SLACK RATES OFF AT WEIGHT 1561 =80K, ROTATION WEIGHT = 80K, TORQUE =3 -5K, WEIGHT ON BIT =3 -6K, - TAG FISH AT 1611' TO 1621' 01:00 - 01:30 0.50 FISH P DECOMP CIRULATE BOTTOMS UP WITH 5 BPM AT 140 P SI 01:30 - 02:00 0.50 FISH P DECOMP PULL OUT OF HOLE FROM 1621' TO 222', FLOW CHECK WELL FOR 10 MINTUES AT BHA FOR NON SHEARABLES ACROSS BOP STACK. 02:00 - 03:30 1.50 FISH P DECOMP STAND BACK 4 -3/4" DRILL COLLARS, LAY DOWN 8 112" DRESS OFF SHOE AND PICK UP BHA #6 03:30 - 04:00 0.50 FISH P DECOMP O' I LI AR 8 IN 1/ OVERSHOT LE TO 1539 WWI EXTENSICUT IP ON, ESTABLISH P/U WEIGHTS -80K, SLACK GU OFF WEIGHT -80K 04:00 - 04:30 0.50 FISH P DECOMP RIH AND TT 1', W FT WITH OVERSHOT FISH , SET 161 15, K SWALLO TO ENGAGE ED 6 FISH, PICKUP AG WEIGHT A 150K 04:30 - 07:00 2.50 FISH P DECOMP W FISH FROM ' (BOTTOM FISHING POOH ASSEMBL Y) TO 1100 WORK TIGH T PIPE AT 1550' (175K) 07:00 - 08:00 1.00 FISH P DECOMP T FLOW CK H FOR NON SHEAIRABLES ACROSS THE AT STAC K. -STAND 10 MIN TE BACK 4-3/4 CHE DRILL COLLARS 08:00 - 09:00 1.00 FISH P DECOMP LAY DOWN CROSS ND P CROSS OVERS TO PULL TUBI 09:00 - 10:00 1.00 FISH P DECOMP PJSM A DOWN BAKER FISHING PICK U TOOLS -LAY DOON WLN Y BHA #6 10:00 - 12:00 2.00 FISH P DECOMP PJSM ON RIG LAY DOWN TUBING MOBILIZED TOOLS UP AND NEEDED FOR LAY DOWN 4.5 TUBING TO RIG FLOOR, RIG UP TUBING EQUIPMENT ON FLOOR -LOSS RATE FROM MIDNIGHT TO NOON WAS 67 BBLS @ 5 -6 BBLS/HOUR Printed 11/19/2012 11:34:28AM I o Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 16:30 4.50 FISH P DECOMP PJSM, LAY DOWN 4.5 TUBING, PULLING TIGHT ON EVERY JOINT. STARTED PULLING AT 120K, AND PICKUP WEIGHT INCREASED EVERY JOINT UNTIL WE GOT TO 250K. -LAY DOWN 28 JOINTS, TUBING STOPPED MOVING, WILL NOT MOVE UP OR DOWN. MAX. PICK UP WEIGHT 250K. - - PARTIAL CLAMP RETRIEVED, HAIR BALL/ BIRDS NEST OF APPEARING TO BE WADDED UP CLAMPS AND STAINLESS STEEL TUBING,IS VISIBLE BELOW THE 9.125 ID WEAR RING (33.4' BELOW RIG FLOOR) -18" OF 4.5" COMPLETION TUBING ABOVE RIG FLOOR, MADE UP CROSS OVER WITH FULL OPEN SAFETY VALVE - CASING IS 9.625" WITH ID OF 8.681" -WELL BORE IS SECURE 116:30 - 00:00 7.50 FISH N DPRB DECOMP CIRULATE OVERTOP OF THE HOLE, WAIT ON TOOLS FOR NEXT BHA AND DECISION ON PLAN FORWARD. CLEANED UP ON RIG, PERFORMED PM WORK ORDERS, LOCATED CROSSOVERS NEEDED FOR NEXT RUN AND "PUT ON RIG FLOOR. -LOSS RATE FROM NOON TO MIDNIGHT WAS 90 BBLS, TOTAL OF 157 BBLS LOST THE PAST 24 HRS. 7 -8 BBLS/HR LOSS DURING THE PAST 12 HOURS. AVG LOSS PER HOUR FOR THE DAY IS 6.5 BBLS /HR 10/1/2012 00:00 - 06:00 6.00 FISH N DPRB DECOMP CIRCULATE OVER TOP OF THE HOLE, MONITOR WELL FOR LOSSES/ GAINS. - MOBILIZE 5" HANDLING EQUIPMENT AND TOOLS NEEDED FOR NEXT OPERATION TO RIG FLOOR; NEW WIRE ROPE TO RIG FLOOR FOR MAN RIDER AND HYDRAULIC HOISTS. WORK ON PREVENTIVE MAINTENANCE WORK ORDERS, CHANGED OUT BRAKE COOLANT PUMP UNDER RIG FLOOR, SLING INSPECTION, WORK ON MUD PUMP POP OFF. - WELDER WORK ON INSTALL NEW FUEL STATION ON RIG - REBUILT DOG COLLARS. 06:00 - 12:00 6.00 FISH N DPRB DECOMP MONITOR WELL FOR LOSSES/ GAINS, CIRCULATE ACROSS THE TOP OF THE HOLE - CONTINUE TO WORK ON MUD PUMP POP OFFS, REPLACE MAN RIDER AND HYDRAULIC HOISTS WIRE ROPE - CLEANING AND PAINTING IN THE PITS. - WELDER WORK ON INSTALL NEW FUEL STATION ON RIG -TOUR LOSSES FROM MIDNIGHT TO NOON IS 84.5 BBLS @ 7 BBLS/HR 12:00 - 14:30 2.50 FISH N DPRB DECOMP CONTINUE TO MONITOR WELL FOR LOSSES/ GAINS, CIRCULATE ACROSS THE TOP OF THE HOLE - CONTINUE WORK TO CHANGE OUT HOIST WIRE ROPE, PAINTING IN PITS - WELDER WORK ON INSTALL NEW FUEL STATION ON RIG 14:30 - 17:30 3.00 FISH N DPRB DECOMP PRE JAR INSPECTION ON TOP DRIVE AND DERRICK Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 18:30 1.00 FISH N DPRB DECOMP PJSM, MAKE UP BHA #7- SURFACE JAR ASSEMBLY CIRCULATE OVER TOP OF THE HOLE, MONITOR WELL FOR LOSSES/ GAINS. - ATTEMPT TO SPEAR INTO TUBING, BUT SPEAR WOULD NOT GO INTO TUBING. EDGE OF TUBING INSIDE OF COLLAR LOOKED SWEDGED IN. -HAND CUT (TUBING CUTTERS) TUBING RIGHT BELOW COLLAR AND TRIED TO RUN SPEAR AGAIN. SPEAR WOULD NOT GO IN. HAND CUT ANOTHER SECTION OF TUBING (4 INCHES) AND ATTEMPTED TO RUN SPEAR INTO TUBING AGAIN. WAS ABLE TO GET SPEAR AND PACKER INTO TUBING. (TUBING WAS SLIGHTLY DEFORMED (EGG SHAPED)). 18:30 - 20:30 2.00 FISH N DPRB DECOMP CIRCULATE OVER TOP OF THE HOLE, MONITOR WELL FOR LOSSES/ GAINS. - JAR DOWN ON TUBING , BROKE FREE AND WENT DOWN ABOUT 5 FEET. CONTINUE JARRING AND IT BROKE FREE ON THE UP STROKE AT 160K, CAME UP 3 FEET ABOVE ORIGINAL STUCK POINT, AND WOULD NOT GO DOWN. CAN NOT COCK JARS AT THIS PICK UP WEIGHT. STRING WAS PICKING UP AT 140K. STOPPED AND CALLED TOWN FOR PERMISSION TO TRY TO PULL THIS JOINT ABOVE ROTARY TABLE. DISCUSSED PLAN FORWARD WITH JAMES WILLINGHAM AND GOT APPROVAL TO PULL STAND UP AND BREAK OFF PROVIDED NO "DEBRIS" COMES ACROSS BOP STAND. 20:30 - 21:00 0.50 FISH N" DPRB DECOMP PICK UP ON 4.5 TUBING STRING AND BRING NEXT COLLAR TO RIG FLOOR WHILE MONITORING DEBRIS BALL. PICK UP WEIGHT =230K, -BREAK JOINT OFF AND LAY DOWN, DEBRIS STAYED BELOW THE 9.125 ID WEAR RING. "WELL SITUATION: 2' OF 4.5" TUBING STICKING UP THRU FLOOR SECURED WITH SLIPS, CROSSOVER AND FOSV STABBED INTO THE TOP OF THE STUMP WITH THE FOSV CLOSED. DEBRIS IS LOCATED IMMEDIATELY BELOW THE WEAR RING (IN THE WELL HEAD), NO JUNK OR DEBRIS LOCATED IN THE STACK. WELL CAN BE SECURED WITH PIPE RAMS (2 7/8" X 5" VBRS) AND ANNULAR BAG WITH THE BLIND/SHEAR RAMS AS LAST RESORT. - JUNK/DEBRIS APPEARS TO CONSIST OF WADDED UP CLAMPS AND TUBING AND HEAT TRACE. - CIRCULATE OVER TOP OF THE HOLE, MONITOR WELL FOR LOSSES/ GAINS. 21:00 - 22:30 1.50 FISH N DPRB DECOMP LAY DOWN BHA #7- SURFACE JAR ASSEMBLY. - CONDUCT POST JARRING TOP DRIVE AND DERRICK INSPECTION - CIRCULATE OVER TOP OF THE HOLE, MONITOR WELL FOR LOSSES/ GAINS. Printed 11/19/2012 11:34:28AM ;,1% ° Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 FISH N DPRB DECOMP CONTINUE TO MONITOR WELL FOR LOSSES/ GAINS, CIRCULATE ACROSS THE TOP OF THE HOLE -WAIT ON TOOLS FOR NEXT OPERATION. -TOUR LOSSES FROM NOON TO MIDNIGHT -73 BBLS @ 6 BBLS /HR. TOTAL LOSSES FOR DAY -157.5 @ 6.5 BBLS. /HR *TOTAL JOINTS OF 4.5" TUBING RECOVERED FROM WELL =39 (1657.49 FT). TOTAL LENGTH OF TUBING IN HOLE 3403.69 FT. 10/2/2012 00:00 - 06:00 6.00 FISH N DPRB DECOMP CONTINUE TO MONITOR WELL FOR LOSSES/ GAINS, CIRCULATE ACROSS THE TOP OF THE HOLE -WAIT ON TOOLS FOR NEXT OPERATION, MOBILIZED TOOLS NEEDED TO CUT TUBING TO RIG FLOOR. - PREVENTIVE MAINTENANCE ON RIG, PRESSURE TEST HP LINES ON MUD SYSTEM (ANNUAL PM) - RECEIVE AND STRAP 2 -78" DRILL PIPE FOR TUBING CUTTING OPERATIONS. 06:00 - 10:30 4.50 FISH N DPRB DECOMP CONTINUE TO MONITOR WELL FOR LOSSES/ GAINS, CIRCULATE ACROSS THE TOP OF THE HOLE - PREVENTIVE MAINTENANCE ON RIG,PAINTING IN PUMP ROOM AND MUD PITS, WELDERS CONTINUE TO WORK ON NEW FUEL STATION ON RIG AND RESKIN EXTERIOR WALLS WITH CORRUGATED SHEET METAL, CLEAN RIG. 10:30 - 12:00 1.50 FISH N DPRB DECOMP MAKE UP BHA #8 AND RUN IN HOLE, TAGGED UP AT 86' - LOSSES FOR TOUR = 81.5 BBLS @ 6.8 BBLS PER HOUR 12:00 - 13:30 1.50 FISH N DPRB DECOMP CUT TUBING AT 75' DOWN, PSI =200, STAGING UP TO 1200 PSI. RPM =60, TORQUE =0 13:30 - 14:30 1.00 FISH N DPRB DECOMP TRY TO SLACK OFF WITH CUTTERS OPEN, WOULD NOT SLACK OFF, CONTINUE CUTTING 4.5 TUBING, PSI =1200, RPM =60, TORQUE =0. 14:30 - 16:30 2.00 FISH N DPRB DECOMP PULLED OUT OF HOLE AND LAY DOWN CUTTER, DRILL PIPE AND REMAINING BHA ASSEMBLY -RIG UP TO PULL 4.5 TUBING 16:30 - 17:00 0.50 FISH N DPRB DECOMP PULL 4.5 TUBING OUT OF HOLE, PICK UP WEIGHT = 266K. -LAY DOWN (1) ONE JOINT OF 4.5 TUBING AND (1) ONE CUT -OFF JOINT OF 4.5 TUBING (LENGTH = 29.20 FT). *TOTAL OF 40 JOINTS OF 4.5" TUBING HAVE BEEN PULLED OUT OF THE HOLE PLUS THE ONE CUT JOINT. 17:00 - 22:00 5.00 FISH N DPRB DECOMP -LAY DOWN 4.5 HANDLING EQUIPMENT. - PERFORM WEEKLY DERRICK INSPECTION - CHANGE OUT LONG BAILS WITH SHORT BAILS -PICK UP HANDLING TOOLS FOR NEXT OPERATION. Printed 11/19/2012 11:34:28AM dd Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 FISH N DPRB DECOMP MONITOR WELL LOSSES/ GAINS, CIRCULATE WHILE FOR WAITING ON TOOLS FOR NEXT RUN IN THE HOLE - RECEIVED 6" SPIRAL DRILL COLLARS, LOAD SHED, STRAP, RECORD TALLY - E= BBLS PER HOUR TOTAL S FOR LOSSES TOUR 67 FOR BBLS THE @ 6 PAST 24 HOURS= 157.5 10/3/2012 00:00 01:00 1.00 FISH N DPRB DECOMP MONITOR WELL AINS MOBILIZE BHA #9 FOR TO RIG LOSSES/ FLOOGR. 01:00 - 02:00 1.00 FISH N DPRB DECOMP PJSM VALVE ON TESTING 4.5 IF FULL OPEN SAFETY - TEST TO 250 PSI LOW/ 2000 PSI HIGH FOR FIVE MINUTES - CHARTED. 02:00 - 03:30 1.50 FISH N DPRB DECOMP PJSM'ON MAKING UP BHA #9. MAKE UP 8.5" FLAT BOTTOM MILL, BUMPER JARS, OIL JARS, 625" DC AND 1 JT 4 DP. DEBRIS IS VISIBLE BELOW WELL HEAD AND THE 9.125 ID WEAR RING 03:30 - 04:00 0.50 FISH N DPRB DECOMP RUN IN HOLE W/ BHA #9. TAG DEBRIS/FISH AT 32 FT BELOW ROTARY TABLE. -SCREW INTO TOP DRIVE AND ATTEMPT TO PUSH DEBRIS DOWN HOLE. -MADE SEVERAL ATTEMPS FSH/DEBRIS DOWN HOLE W/ TO 10K W/O PUSH SUC 04:00 - 04:30 0.50 FISH _._ N DPRB DECOMP BHA #10. RECONFIGURE BHA #9: REPLACE JT OF 4" DP WITH 6.25" DC #2. 04:30 - 05:00 0.50 FISH N DPRB DECOMP RUN IN HOLE WITH BHA #10. -TAG AT 32 FT. -SET DOWN W/ 15K ATTEMPTING TO FISH/DEBRIS DOWNHOLE W/O SUCCESS. 05:00 - 06:00 1.00 FISH N DPRB DECOMP PULL BHA #10 OUT OF HOLE AND STAND BACK. - MONITOR WELL FOR LOSSES/ GAINS, CIRCULATE OVER THE TOP 06:00 09:00 3.00 FISH N DPRB DECOMP MAKE UP BHA #11. - A # 11. -MAKE UP MOBILIZE 8 -1/2 " X 7" FOR SHOE EXTENSION, BOOT BASKET, BUMPER JAR, OIL JAR AND (2) 6.25" DC'S. -STAND BACK BHA #11. -SPOT CLEAN AND PAINT RIG. - MONITOR WELL. 09:00 - 10:00 1.00 FISH N DPRB DECOMP RUN ESTABLISH IN0 HOLE WITH PARAMETERS: BHA #11. 5 BPM AT 30 PSI AND 30 RPM W/ 2 -4 K TORQUE. SW =57K. MILL/WASHOVER: 32 TO 35 FT. POOH TO CHECK SHOE. "WEAR RING PULLED OUT OF HOLE ON WASH PIPE. Printed 11/19/2012 11:34:28AM rrr�rrjo a ;; Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12:00 2.00 WHSUR N DPRB DECOMP CLEAN METAL DEBRIS FROM WASH PIPE AND REMOVE WEAR BUSHING FROM WASH PIPE. - MONITOR WELL FOR LOSSES/ GAINS. - INSPECT WELL HEAD/ WEAR RING FOR DAMAGE W/ FMC TECH. *WEAR RING APPEARED TO HAVE BEEN WEARING ON THE ID OF WELL HEAD. WEAR RING OK TO RERUN. -LOSSES FOR TOUR= 52 BBLS @ 4.3 BBL PER HOUR 12:00 - 12:30 0.50 FISH N DPRB DECOMP LUBRICATE RIG. 12:30 - 13:00 0.50 WHSUR N DPRB DECOMP RUN IN WITH WEAR RING W/O SUCCESS. -SET 1 FT HIGH. OF SEAT. - REMOVE WEAR RING. 13:00 - 14:00 1.00 FISH N DPRB DECOMP RUN IN HOLE WITH BHA #11. - TAG AT 35 FT. - ESTABLISH PARAMETERS: 1 BPM @ 40 PSI, RPM= 30, W/ 3-4 K TORQUE. WOB= 5 -7K. -MILL: 35 TO 36 FT. - STALL TOP DRIVE AT 10K. -PULL OUT OF HOLE AND RECOVER 30 LBS. OF METAL. 14:00 - 14:30 0.50 FISH N DPRB DECOMP RUN HOLE WITH BHA #11. -MILL: 35 TO 36.5 FT. -PUMP PRESSURE INCREASED TO 120 PSI W/ TORQUE =0. -PULL OUT HOLE AND NO METAL RECOVERED. - RUN IN HOLE AND ATTEMPT TO MILL. - PUMP PRESSURE AT 120 PSI AND 0 TORQUE. -SHUT DOWN PUMPS AND TORQUE INCREASED. 14:30 - 15:00 0.50 FISH N DPRB DECOMP PULL OUT OF HOLE AND DRAIN STACK. - OBSERVE 4.5" TUBING STUB AT 32 FT. 15:00 - 16:00 1.00 FISH N DPRB DECOMP MAKE UP BHA # 12. -LAY DOIWN BUMPER JARS AND PICK UP WASH PIPE EXTENSION. 16:00 - 17:00 1.00 FISH N DPRB DECOMP RUN IN HOLE WITH BHA #12. -MILL: 36 TO 39 FT. -AT 39 FT, PUMP PRESSURE INCREASED UP TO 180 PSI. 17:00 - 17:30 0.50 FISH N DPRB DECOMP PULL OUT OF HOLE AND RECOVER 5 LBS OF METAL DEBRIS. 17:30 - 18:00 0.50 FISH N DPRB DECOMP RUN IN HOLE W/ BHA #12. -MILL: 39 TO 42 FT. -AT 42 FT PUMP PRESSURE INCREASED TO TO 180 PSI AND STALL TOP DRIVE. 18:00 - 19:00 1.00 FISH N DPRB DECOMP PULL OUT OF HOLE AND RECOVER 10 LBS OF METAL DEBRIS. 19:00 - 19:30 0.50 FISH N DPRB DECOMP RUN IN HOLE WITH BHA #12. -MILL 0 FT. TORQUE =0. -PULL OUT OF HOLE AND RECOVER 20 LBS METAL DEBRIS. 19:30 - 20:00 0.50 FISH N DPRB DECOMP RUN IN HOLE WITH BHA #12. - MILL: 42 TO 43 FT. 20:00 - 20:30 0.50 FISH N DPRB DECOMP PULL OUT OF HOLE AND RECOVER 1 LBS OF METAL DEBRIS. Printed 11/19/2012 11:34:28AM e Common We ll N MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date (hr) From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 20:30 - 21:00 0.50 FISH N DPRB ER 10LBS DECOMP RUN IN HOLE WITH BHA #12. MILL: 43 TO 44 FT. PULL OUT OF HOLE AND RECOV OF METAL DEBRIS. (ft) 21:00 22:30 1.50 FISH N DPRB DECOMP MAKE UP BHA # 13. CHANGE OUT WASH OVER SHOE AND PICK UP WASH PIPE EXTENSION. 22:30 23:00 0.50 FISH N DPRB DECOMP RUN IN HOLE WITH BHA # 13. -MILL: 44 TO 45 FT. 23:00 23:30 0.50 FISH N DPRB DECOMP PULL OUT OF HOLE AND NO METAL DEBRIS IN MILL RECOVERED. 23:30 - 00:00 0.50 FISH N DPRB DECOMP RUN }N HOLE WITH BHA #13. MILL 45 TO 45.5 FT. *TOTAL FLUID LOSS FOR 24 HRS: 132 BBL. *ESTIMATE 75 LBS OF METAL DEBRIS RECOVERED FOR DAY. 10/4/2012 00:00 - 01:30 1.50 FISH N DPRB DECOMP MILILINGWITH BHA #13, CONT. MILL: 45.5 T047 FT. 3,0 BPM AT PSI AND 40 RPM WITH 2 -4K TORQUE. 01 :30 - 02 :00 0.50 FISH N DPRB DECOMP PULL UT OF HOLE NO METAL L RECOVERED. _ N DPRB DECOMP RUN IN HOLE WITH BHA # 13 02:00 - 04:00 2.00 FISH . -TAG AT 47 FT. L :07EUTRTDE FT. L P LL L OF HOLE AND NO META RECOD. 49.5 SHOE WORN. 04:00 - 04:30 0.50 FISH N DPRB DECOMP P E BHA #14. - CHANGMAKE U OUT MILL SHOE. 04:30 - 05:30 1.00 FISH N DPRB DECOMP RUN IN HOLE WITH BHA #14. -TAG AT 32 FT. -PULL OUT OF HOLE. -DRAIN AND VAC STACK. - OBSERVE METAL DEBRIS AT WELL HEAD. 05:30 - 07:00 1.50 FISH N DPRB DECOMP WASH OVER/CLEAN OUT: 32 TO 49.5 FT. -8 BPM AT 70 PSI WITH 50 RPM AND 4K TORQUE. -4 BPM AT 30 PSI WITH 70 RPM AND 3K TORQUE - A TO , PUSHING PRESSURE FLUID ME DOWN HOLE. 180 PSI - SLOWED PUMPS DOWN TO 0.5 1.50 FISH BPM WSTARTED R T T 30 PSI. 07:00 08:30 N DPRB DECOMP MILL WITH BHA #14. -MILL: 49.5 TO 52 FT. -0.5 BPM AT 30 PSI AND 40 RPM. 08:30 09:00 0.50 FISH N DPRB DECOMP PULL OUT OF HOLE WITH BHA #14 FROM 52 FT TO 33 FT. - , SLACK AND ROTATE PULLING WHILE 100K PULLING OFF UP ON TO 50K STRING. -BROKE FREE, CONTINUE PULL OUT OF HOLE FROM 33 FT TO SURFACE. 09:00 09:30 0.50 FISH N DPRB DECOMP CLEAN METAL DEBRIS FROM WASH PIPE ASSEMBLY. - RECOVER 40 LBS OF METAL. *FLOW CHECK THE WELL, WELL FLOWING. *SHUT IN WELL WITH BLIND /SHEARS. Printed 11/19/2012 11:34:28AM Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:00 0.50 FISH N DPRB DECOMP MONITOR PRESSURE. - 0 PSI ON CASING. *MAKE APPROPRIATE LEVEL 0 NOTIFICATIONS. 10:00 - 11:00 1.00 FISH N DPRB DECOMP FILL GAS BUSTER WITH 6 BBLS. - WAITED UNTIL FLOW FROM FILLING GAS BUSTER STOPPED. 11:00 - 12:00 1.00 FISH N DPRB DECOMP OPEN CHOKE TO GAS BUSTER AND PITS. -VERIFY NO FLOW. -OPEN SHEAR/ BLIND RAMS -NO FLOW, MONITOR WELL FOR 30 MINUTES TOUR LOSSES = 144 BBLS AT 12 BBLS PER HOUR 12:00 - 13:30 1.50 FISH N DPRB DECOMP CONTINUE TO MONITOR WELL LOSING FLUID SLOWLY 13:30 - 15:30 2.00 FISH N DPRB DECOMP LAY DOWN BRA #14. MOBILZE TUBING CUTTING TOOL. -BLOW DOWN TOP DRIVE, GAS BUSTER AND CHOKE. -CIRCULATE OVER TOP OF WELL. 15:30 - 16:30 1.00 FISH N DPRB DECOMP PJSM TO MAKE UP BHA # 15. MAKE UP TUBING CUTTER ON 2-7/8 PAC PIPE. -VAC OUT STACK TO 40 FT TO METAL DEBRIS. -4-1/2" TUBING STUB NOT VISIBLE. 16:30 - 17:00 0.50 FISH N DPRB DECOMP LAY DOWN BHA # 15 AND HANDLING TOOLS -RIG UP STACK WASHER ON 4" DRILL PIPE - MONITOR WELL, CIRCULATE OVER THE TOP OF WELL. 17:00 - 18:00 1.00 BOPSUR N DPRB DECOMP WASH STACK AND FUNCTION RAMS. -WASH STACK AND TUBING SPOOL SECOND TIME. 18:00 - 18:30 0.50 BOPSUR N DPRB DECOMP DRAIN STACK AND INSTALL TEST PLUG. 18:30 - 00:00 5.50 BOPSUR N DPRB DECOMP TEST BOP EQUIPMENT. -250 PSI LOW/ 2000 PSI HIGH WITH 3 -1/2" TEST JOINT AND 4 -1/2" JOINT FOR FIVE CHARTED MINUTES EACH. -MPL TEST ON EACH RAM CAVITY WITH BOTH TEST JOINTS AT BOTH TEST PRESSURES. -TEST: (2) XT 39 FULL OPEN SAFETY VALVES, (1) XT 39 DART VALVE AND (1) 4 -1/2" IF FOSV. *NOTE: FAIUPASS MPL TEST ON LOWER (2 -7/8" X 5" VBR) W/ BOTH TEST JOINTS. *- INITIAL TEST FAILED. PRESSURED WITH KOOMEY AND TEST PRESSURE. BLED PRESSURES AND RETESTED, PASSED. - KOOMEY DRAWDOWN TEST. - CONTINUOUS FILL AND MONITOR HOLE FILL DURING TESTING. *ALL TESTS PERFOMRED IN ACCORDANCE WITH AOGCC, BP AND DOYON SPECS. "CHUCK SCHEVE, AOGCC WAIVED WITNESSING BOPE TEST, 16:30 10 -4 -12. *FLUID LOSS FOR TOUR = 15 BBLS @ 1.3 BBLS PER HOUR. *TOTAL FLUID LOSS FOR 24 HRS= 159 BBLS *ESTIMATE 40 LBS OF METAL DEBRIS RECOVERED FOR DAY. Printed 11/19/2012 11:34:28AM 44444t 4' 44 <444 44.47 4444" 4 444 4 4 444%44444,44 444 , Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/5/2012 00:00 - 06:00 6.00 BOPSUR N DPRB DECOMP TEST BOP EQUIPMENT, CONT. - 250 PSI LOW AND 2000 PSI FOR 5 CHARTED MINUTES. -TESTS WITH 3 -1/2" TEST JOINT. -RIG DOWN TEST JOINT. -TEST BLIND /SHEARS. - RIG DOWN TEST EQUIPMENT. *CONTINUOUS FILL AND MONITOR HOLE FILL DURING TESTING. 06:00 - 07:00 1.00 BOPSUR N DPRB DECOMP RIG DOWN TEST JOINT. -PULL TEST PLUG. - INSTALL WEAR RING AND 4 LOCK DOWNS. -BREAK TOP DRIVE CONNECTION. 07:00 - 08:00 1.00 FISH N DPRB DECOMP CIRCULATE OVER HOLE AND MONITOR FLUID. 08:00 - 08:30 0.50 FISH N DPRB DECOMP MOBILIZE TOOLS NEEDED FOR UPCOMING MAGNET RUN IN THE HOLE. 08:30 - 11:00 2.50 FISH N DPRB DECOMP PJSM ON MAKING UP BHA #15: MAGNET, BIT SUB, CROSSOVER AND 4" DRILLPIPE. -RUN IN THE HOLE WITH ASSEMBLY AND TAG 43.5 FEET. -RUN IN AND OUT OF HOLE SEVERAL TIMES RECOVERING METAL DEBRIS. *ESTIMATED METAL DEBRIS RECOVERED AT 35 POUNDS. 11:00 - 11:30 0.50 FISH N DPRB DECOMP RIG DOWN BHA #15 AND LAY DOWN TOOLS. - MOBILIZE TOOLS NEEDED FOR UPCOMING BHA #16. 11:30 - 14:00 2.50 FISH N DPRB DECOMP PJSM ON MAKING UP BHA #16. SHOE, WASH PIPE EXTENSION, OIL JARS AND (2) 6 -1/4" DC. - MAKE UP BHA #16. - RUN IN THE HOLE AND TAG AT 43 FEET. - ESTABLISH PARAMETERS AT 1.5 BPM WITH 30 PSI, 60 RPM WITH 2K TORQUE. -PU 58K, SO 58K, ROT 58K, WOB 5 -7K. - WASHOVER: 43 TO 51 FT. 14:00 - 16:00 2.00 FISH N DPRB DECOMP STALL TOP DRIVE AT 10K. -WORK PIPE AND INTIATE ROTATION PULLING UP TO 43 FT. - FISHING ASSEMBLY STUCK AND UNABLE TO ROTATE AND CIRCULATE AT 43 FT. - START TO JAR, WORK UP FROM 125K, WITH 15 TORQUE. -WORK PIPE, CONT. PULL 135K WITH 15 TORQUE. -PULL 145K, 165K, 175K, SEVERAL TIMES. -PULL 200K AFTER JARS HIT. PULL 185K AND THEN 225K SEVERAL TIMES. -PULL 250K AFTER JARS HIT AT 15:30 AND PUMPED 10 BBLS W/O RETURNS. 16:00 - 17:00 1.00 FISH N DPRB DECOMP DERRICK, TOP DRIVE AND BLOCK INSPECTION. - PUMP STACK AND MONITOR AT THE WEAR RING. -BACK OUT (4) LOCK DOWN SCREWS ON WEAR RING. Printed 11/19/2012 11:34:28AM Opera ton,Sunttm4 Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 19:00 2.00 FISH N DPRB DECOMP WORK STUCK FISHING BHA, CONT. -PUMP 2 BPM AT 240 PSI (5 BBLS TOTAL AT 18:00) -JAR UP TO 195K WITH 17 TORQUE SERVAL TIMES, CONT. -JAR UP TO 195K WITH 20 TORQUE SEVERAL TIMES, CONT. -JAR UP 210K THEN PICK UP TO 250K SEVERAL TIMES, CONT. -JAR UP TO 220K THEN PULL UP TO 250K SEVERAL TIMES, CONT. JAR UP TO 225K THEN PULL UP TO 275K SEVERAL TIMES, CONT. 19:00 - 20:00 1.00 FISH N DPRB DECOMP DERRICK, TOP DRIVE AND BLOCK INSPECTION. -PUMP 1 BPM AT 70 PSI FOR A TOTAL OF 2 BBLS. 20:00 - 21:00 1.00 FISH N DPRB DECOMP PJSM MOBILIZE` PUPS TO RIG FLOOR AND MAKE UP. -MAKE UP LIFT CAP, 6 FT 4.5 IF PUP JOINT, X- OVER:, IF(B) X XT39 (P) AND FOSV. -MAKE UP LIFT CAP, 10 FT 4.5 IF PUP JOINT W/ X -OVER: IF(B) X H90 (P) AT THE READY. 21:00 - 22:30 1.50 FISH N DPRB DECOMP "JAR PIPE, CONT. -SET THE JARS OFF AT 225K PICK UP TO 275K. - NO MOVEMENT IN FISHING ASSEMBLY AND AT MAX PULL PER DOYON. -PUMP 1 BBL AT 1 BPM AT 130 PSI. 22:30 - 00:00 1.50 FISH N DPRB DECOMP PJSM ON OPERATIONS FOR CONTROLLED BACKOFF OF DRILL COLLARS. -SET SLIPS ON DC IN ROTARY TABLE W/ COLLAR CLAMP. - SECURE 52 FT DC W/ ROPES USING STABBING BOARD. - BREAK OUT DRILL COLLAR FROM TOP DRIVE QUILL (LEAVING XT 39 X -OVER) - PICK UP 6 FT PUP W/ X -OVER AND FOSV IN CLOSED POSITION. - LATCH IN ELEVATORS AND MAKE UP TO DRILL COLLAR. -RIG DOWN ROPES. -SET SLIPS AND CLOSE ANNULAR W/ 1500 PSI CLOSING PRESSURE. - CONTROLLED BACK OFF W/ 22K AT X -OVER BETWEEN DRILL COLLARS AND OIL JARS AT 7 FT BELOW ROTARY TABLE. -PICK UP AND MAKE UP 10 FT PUP W/ FOSV INTO X -OVER ABOVE OIL JARS. - CLOSE FOSV AND SECURE WELL. *FLUID LOSS FOR DAY: 21 BBL. 10/6/2012 00:00 - 00:30 0.50 FISH N DPRB DECOMP PJSM ON LAYING DOWN COLLARS. -LAY DOWN (2) 6.25 DRILL COLLARS, X -OVER: H -90 (P) X XT 39 (B) , FOSV AND 6 FT PUP JOINT. 00:30 - 01:00 0.50 FISH N DPRB DECOMP PJSM ON CHANGING OUT TO LONG ELEVATOR BALES. - RIG DOWN SHORT BALES. - MOBILIZE LONG BALES AND RIG UP. -FILL PIPE WITH 3.0 BBLS AT 70 PSI. Printed 11/19/2012 11:34:28AM 0,14;; i Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 03:00 2.00 FISH N DPRB DECOMP PJSM ON RIGGING UP SURFACE JARS. -PICK UP 14 FT 5" DP PUP JOINT AND SURFACE JARS. -LAY DOWN FOSV. - MAKE UP SURFACE JARS TO FISHING ASSEMBLY. -FILL PIPE WITH 2.3 BBL AT 110 PSI. 03:00 - 03:30 0.50 FISH N DPRB DECOMP "`MAKE UP BHA #17 - PRE -JAR DERRICK, TOP DRIVE, ELEVATORS AND BLOCK INSPECTION. -PUMP 3 BBLS DOWN HOLE 10 SPM WITH 80 PSI. 03:30 - 05:00 1.50 FISH N DPRB DECOMP JAR ON FISHING ASSEMBLY WITH SURFACE JARS. -JARS FIRING DOWNAT 100K. -NO MOVEMENT IN STRING. -LET JARS COOL OFF AND CHECK DRILLING LINE AND MEZZANINE FOR ANY DAMAGE. -JAR ON FISH ASSEMBLY, CONT. 05:00 - 05:30 0.50 FISH N DPRB DECOMP SURFACE JARS WOULD NOT FULLY CLOSE. - ATTEMPT TO CLOSE WITH OUT SUCCESS. -LAY DOWN SURFACE JARS AND SCREW INTO STRING. 05:30 - 06:30 1.00 FISH N DPRB DECOMP JAR ON FISHING ASSEMBLY WITH OIL JARS. - FIRING JARS 225 TO 250K, PULLING TO 275K. - ATTEMPT TO JAR SEVERAL MORE TIMES, NO MOVEMENT IN STRING. - PUMP 3 BBLS DOWN HOLE AT 11 SPM WITH 70 PSI. 06:30 - 07:30 1.00 FISH N DPRB DECOMP PJSM ON CHANGING OUT SAVER SUB FROM XT -39 TO 4.5 IF. - MOBILIZE TOOLS AND CHANGE OUT SAVER SUB. -LAY DOWN CROSSOVER SUB XT -39 BY 4.5 IF. - LAY DOWN (2) 4.5 IF PUP JOINTS, (1) CROSSOVER 4.5 H -90 BY 4.5 IF. -LAY DOWN LONG ELEVATOR LINKS. - MAKE UP CROSSOVER FROM H-90 TO 4.5 IF TO FOSV. - INSTALL FOSV ON TOP OF 6.25 OIL JARS AND CLOSE. 07:30 - 10:00 2.50 FISH N DPRB DECOMP RIG DOWN TOP DRIVE TORQUE TUBE. - CHANGE OUT SAVER SUB, GRABBERS, AND BELL GUIDE FOR 4.5 IF. -POST JAR TRAVELLING EQUIPMENT INSPECTION. -PUMP 3 BBLS DOWN HOLE 10 SPM WITH 84 PSI. 10:00 - 10:30 0.50 FISH N DPRB DECOMP RIG UP LONG ELEVATOR LINKS. -MAKE UP 4.5 IF PUPS. - LAY DOWN 5 INCH FOSV. - MAKE UP CROSSOVER FROM 11-90 TO 4.5 IF ON 4.5 IF PUPS. 10:30 - 12:00 1.50 FISH N DPRB DECOMP RIG UP TO STEAM HEAT THE WELL HEAD. -STEAM WELL HEAD. -PUMP 3 BBLS DOWN HOLE 10 SPM WITH 81 PSI. *SPILL DRILL, RESPONSE TIME 1 MINUTE AND 56 SECONDS. *LOSSES FOR TOUR 17.5 BBLS. Printed 11/19/2012 11:34:28AM � 'b; • �: is v:: y; �s'„ � - , 3 ;- Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 19:30 7.50 FISH N DPRB DECOMP STEAM WELL HEAD, CONT. - CHANGE OUT SHORT CABLE ON PIPE SKATE. - CHANGE OUT EASY TORQUE LINES. -PUMP 1 BPM, STOPPED PUMPING WHEN 170 PSI WAS REACHED FIRST TIME. - PUMPED A TOTAL OF 1.5 BBLS. *EVERY TIME AFTER .6 TO .8 BBLS WERE PUMPED ON HOURLY BASIS. "AT 18:30 PUMPED EVERY TWO HOURS. *AT 21:00 PUMPED .9 BBLS AT 170 PSI. 19:30 - 21:00 1.50 FISH N DPRB DECOMP RESUME JARRING WITH OIL JARS. -FIRE JARS AT 225. TO 250K, OVERPULLING TO 275K. - TORQUE SET AT 20, PICK UP TO 175K, -JAR BOTH WAYS WITH TORQUE TO 175K AND 225K THEN PULL UP TO 275K. - FIRE JARS, PULL TO 300K AND HOLD FOR 10 MINUTES. 21:00 - 22:00 1.00 FISH N DPRB DECOMP POST JAR INSPECTION OF TOP DRIVE, BLOCKS AND DERRICK. *ON INSPECTION OF DRILL FLOOR (2) 0.5 OUNCE KEY STOCK PIECES WERE FOUND. * CONFIRMED TO BE KEEPER PIN FOR MAIN HINGE PIN ON 350T ELEVATORS. *ELEVATORS WERE AT 13 FT FROM RIG FLOOR. *NOTIFICATION OF DROPPED OBJECT MADE TO WTL. *TRACTION REPORT #2012 -IR- 4251120 FILED. *PICTURES TAKEN FOR DOCUMENTATION. *NO WITNESS TO FALLING OBJECT AND NO PERSONNEL WERE ON RIG FLOOR DURING JARRING OPERATIONS. * DOYON HSE REP ON LOCATION. *CALLED FOR REPLACEMENT ELEVATORS. 22:00 - 23:00 1.00 FISH N DPRB DECOMP CLEAR FLOOR OF ALL TOOLS NOT NEEDED FOR OPERATIONS. - MOBILIZE SURFACE JARS AND CROSS OVERS TO RIG FLOOR. - INPSECT AND CHANGE OUT TO REPLACEMENT 350T 5 INCH ELEVATORS. 23:00 - 00:00 1.00 FISH N DPRB DECOMP RIG UP SURFACE JARS. - LAY DOWN PUP JOINTS. - MAKE UP CROSSOVERS, SURFACE JARS AND PUP JOINT. *TOTAL FLUID LOSS FOR 24 HOURS: 23 BBL. 10/7/2012 00:00 - 01:00 1.00 FISH N DPRB DECOMP MAKE UP SURFACE JARS, CONT. -MAKE UP CROSSOVERS AND PUP JOINTS. -MAKE UP TO FISHING ASSEMBLY. - PRE -JAR DERRICK, TOP DRIVE AND BLOCK INSPECTION. 01:00 - 02:30 1.50 FISH N DPRB DECOMP BEGIN SURFACE JARRING OPERATIONS. - FIRING AT 150K. - ADJUST JAR TENSION SEVERAL TIMES. 02:30 - 03:30 1.00 FISH N DPRB DECOMP POST JAR DERRICK, TOP DRIVE, BLOCK AND ELEVATOR INSPECTION. -FILL PIPE WITH 3.1 BBL AT 130 PSI. 03:30 - 04:30 1.00 FISH N DPRB DECOMP RESUME SURFACE JARRING OPERATION. - FIRING AT 150K. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 05:00 0.50 FISH N DPRB DECOMP FILL PIPE WITH 3.5 BBL AT 250 PSI. - PRESSURE AND BLEED CYCLE (250 TO 500 PSI) MULTIPLE TIMES OBSERVING SMALL TRICKLE DOWN FLOWLINE. 05:00 - 06:00 1.00 FISH N DPRB DECOMP TORQUED TO 20K WITH TOP DRIVE AND 1/8 TURN OF ROTATION. - OSCILLATED TORQUE AND REPEATED PRESSURE AND BLEED WITH 10 BBL FLUID. - VARYING HOOK LOAD BETWEEN 50K AND 250K. -NO UP OR DOWN MOVEMENT IN PIPE. 06:00 - 06:30 0.50 FISH N DPRB DECOMP MONITOR WELL FOR 30 MINUTES. - NO VISIBLE FLOW OR GAIN. 06:30 - 08:30 2.00 FISH N DPRB DECOMP ADD BUMPER JARS BELOW THE SURFACE JARS. -JAR WITH SURFACE AND BUMPER JARS. -NO MOVEMENT IN STRING. - LAY DOWN BUMPER JARS. -JAR WITH SURFACE JARS. -FILL PIPE WITH 2.3 BBLS TO 125 PSI. 08:30 - 09:30 1.00 FISH N DPRB DECOMP POST JAR DERRICK, TOP DRIVE, BLOCK AND ELEVATOR INSPECTION. 09:30 - 10:30 1.00 FISH N DPRB DECOMP _SURFACE JARRING, CONT. - FIRING AT 125K. -NO MOVEMENT IN STRING. - FILL PIPE WIHT 2.5 BBLS TO 120 PSI. 10:30 - 12:00 1.50 FISH N DPRB DECOMP SUSPEND JARRING OPERATIONS. - PER TOWN ORDERS. -WILL RESUME OPERATIONS UPON NEW OPERATION PLAN FORWARD FROM TOWN. - INSTALL 4.5" FOSV AND SECURE WELL. 12:00 - 18:00 6.00 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. - MONITOR WELL, CONT. -POST JAR DERRICK, TOP DRIVE, BLOCK AND ELEVATOR INSPECTION. -POST JARRING OPERATION INSPECTION OF ALL AREAS OF RIG. *FOUND MINOR LOOSE BOLTS AND NUTS ON TOP DRIVE AND TIGHTENED SAME. *FOUND ONE DERRICK LIGHT NOT WORKING. REPAIRED. - PUMP 0.3 BBLS AT 200 PSI @ 14:00. - CHANGE OUT MAN RIDER TUGGER. - CHANGE OUT SELF RETRACTING FALL PROTECTION. -CLEAN AND PREP CENTRIFUGE ROOM FOR PAINT. *HOLD TABLE TOP MAN DOWN DRILL. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ _ (ft) 18:00 - 00:00 6.00 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. -CLEAN AND PREP CENTRIFUGE ROOM, CONT. - INSULATE STORAGE AREAS IN FRONT OF THE RIG. *RECEIVED PHONE CALL FROM AOGCC, CHUCK SCHEVE AT 19:45 10 -07 -12 IN REGARD TO CURRENT STATUS OF WELL. *TOLD MR SCHEVE THAT JARRING OPERATIONS HAD BEEN SUSPENDED. WE DID HAVE NON - SHEARABLES ACROSS STACK. (OIL JARS AND WASH PIPE). WELL IS DEAD AND IS SHUT IN WITH ANNULAR PREVENTER AND FOSV. WELL IS BEING MONITORED AND FILLED. OPERATIONS PLAN FORWARD IS TO BE FORMULATED TOMORROW. NOTIFIED WTL OF PHONE CONVERSATION. *TOTAL FLUID LOSS FOR 24 HOURS: 19 BBLS. 10/8/2012 00:00 - 06:00 6.00 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. -FILL PIPE WITH 0.3 BBLS AT 75 PSI. - INSTALL RUBBER SEALS ON WIND WALLS. - 'DEMOBILIZE MAN RIDER TUGGER FROM RIG FLOOR TO SHOP. - PAINT CENTRIFUGE ROOM, CONT. -PAINT PUMP ROOM. - INSPECT LANYARDS AND HARNESSES ON RIG. - GENERAL HOUSEKEEPING AND MAINTENANCE. 06:00 - 12:00 6.00 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. - WORK ON STEAM TABLE CONNECTIONS. - PAINT CENTRIFUGE ROOM, CONT. -PAINT PUMP ROOM, CONT. -PAINT AROUND BOILER #1 AND ENGINE #2. - ELECTRICIAN CHANGING OUT LIGHT COVERS ON RIG. - WELDER WORKING ON FRONT OF RIG. - GENERAL HOUSEKEEPING AND MAINTENANCE. *FIRE DRILL, RESPONSE TIME 2 MINUTES AND 39 SECONDS. *LOSSES FOR TOUR 1 BBL. 12:00 - 17:00 5.00 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. - PAINT CENTRIFUGE ROOM, CONT. - PAINT PUMP ROOM, CONT. -PAINT IN MUD PITS. - WELDER WORKING ON FRONT OF RIG. - GENERAL HOUSEKEEPING AND MAINTENANCE. - WINTERIZE AREAS AROUND THE RIG. 17:00 - 18:30 1.50 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. - BREAK DOWN CROSSOVERS, SURFACE JARS. -CLEAN A ND CLEAR FLOOR OF ALL TOOLS NOT REQUIRED FOR UPCOMING OPS. - MOBILIZE GUIDE SHOE, OVERSHOT AND CROSSOVERS TO RIG FLOOR. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS-41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 00:00 5.50 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. -LOAD 2 JOINTS OF 5 INCH HWDP AND 2 JOINTS 4.5 INCH IBT TUBING IN PIPE SHED. - PAINT CENTRIFUGE ROOM, CONT. - PAINT PUMP ROOM, CONT. -PAINT IN MUD PITS, CONT. -WORK ON SLING INVENTORY. -AT 22:30 PUMPED 0.3 BBLS AT 70 PSI. *TOTAL FLUID LOSS FOR 24 HOURS: 2 BBL. 10/9/2012 00:00 - 06:00 6.00 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. -GENERAL MAINTENANCE, PAINTING AND HOUSEKEEPING. - MONITOR WELL. -SHUT IN DRILL PIPE PRESSURE = 0, SHUT IN CASING PRESSURE- 0. (04:00 AM). 06:00 - 12:00 6.00 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. - GENERAL MAINTENANCE, AND HOUSEKEEPING. -PAINT BY BOILER #1, CENTRIFUGE ROOM PUMP ROOM AND CEILING ABOVE DRAWWORKS. -MONITOR WELL. 12:00 - 18:30 6.50 FISH N DPRB DECOMP SUSPENDED OPERATIONS, CONT. - GENERAL MAINTENANCE, AND HOUSEKEEPING. -MP-2'S ON CATS PIPESHED CABLES -PAINT IN PITS AND INSIDE OF WINDWALLS. - MONITOR WELL. 18:30 - 21:30 3.00 FISH N DPRB DECOMP PLAN FORWARD AGREED TO BY TOWN AND PERMISSION GRANTED TO RESUME OPERATIONS. - VERIFY PRESSURE =0 AND OPEN ANNULAR. -DRAIN STACK AND FOUND STACK CLEAN AND CLEAR TO WEAR RING. - REMOVE FOSV AND CROSSOVERS, CEMENT HOSE AND PUP JOINT. -PICK UP JOINT OF 5 INCH HWDP, SCREW INTO HWDP W/ TOP DRIVE AND TORQUE TO 30K. -PULL 150K 2 TIMES, ATTEMPT MANUAL BACK OFF AT NEUTRAL POINT. - CONNECTION BROKE AT THE CROSSOVER ABOVE OIL JARS W/ 24K TORQUE. - - TORQUE TO 35K AND ATTEMPT MANUAL BACK OFF W/ 30K TORQUE W/O SUCCESS. - LAYDOWN JOINT OF HWDP AND MAKE UP 5 FT 5" DRILL PIPE PUP. Printed 11/19/2012 11:34:28AM 6 s Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 00:00 2.50 FISH N DPRB DECOMP PJSM ON 11 -3/4" WASH PIPE WITH OVERSHOT BACK OFF. - LOAD 11 -3/4" WASH PIPE W/ OVERSHOT INTO PIPESHED AND LOAD ON SKATE. -RUN IN HOLE WITH 11 -3/4" WASH PIPE AND OVERSHOT TO 20 FT. -PULL BUSHINGS AND RIG UP SPIDER. -SET SLIPS, UNLATCH ELEVATORS AND SCREW INTO TOP OF 11 -3/4" WASH PIPE ASSEMBLY. - CONTINUE IN HOLE TO 28 FT AND PICK UP TO 200K TO ENGAGE GRAPPLE. - - ENGAGED SECOND FROM BOTTOM 8 -1/8" WASH PIPE EXTENSION. -SLACK OFF TO 60K. - INSTALL WASH PIPE TORQUE CLAMP. -APPLY LEFT HAND TORQUE AND BROKE AT 14K. - COMPLETE BACK OFF WITH 10 ROUNDS. - PICKED UP AND NO OVER PULL. -PULL OUT OF HOLE AND FOUND TORQUE STRAPS HAD BROKE. *11 -3/4" WASH PIPE CHANGE OVER, OVER SHOT BOWL AND CUT LIP SHOE LEFT IN THE HOLE, (4 FT). 10/10/2012 00:00 - 02:30 2.50 FISH N DPRB DECOMP INSPECT, CLEAN AND FIELD DRESS 11 -3/4" WASH PIPE PIN. -RUN IN HOLE TO 20 FT AND SCREW INTO 11 -3/4" WASH PIPE ASSEMBLY. -NO RECOVERY ON RUN #1. -MAKE SECOND ATTEMPT AND RECOVER CHANGE OVER, OVERSHOT BOWL AND CUT LIP GUIDE. 02:30 - 06:00 3.50 FISH N DPRB DECOMP BREAK CUT LIP GUIDE. - LAYDOWN 11 -3/4" WASH PIPE ASSEMBLY. - CHANGE OUT GRAPPLE. - PICK UP 11 -3/4" ASSEMBLY AND TORQUE CUT LIP GUIDE. - SECURE WELL WITH FOSV AND CLOSED ANNULAR. -WELD (4) 3" X 12" TORQUE STRAPS ACROSS CHANGE OVER AND OVERSHOT BOWL. 06:00 - 07:30 1.50 FISH N DPRB DECOMP RUN IN HOLE WITH 11 -3/4" WASH PIPE ASSEMBLY FOR BACKOFF ATTEMPT #2. - ENGAGE FISH AT 26 FT AND PULL 200K TO ENGAGE GRAPPLE. - BACK OFF WITH 28K TORQUE. - COMPLETE BACK OFF WITH 7 ROUNDS. *RECOVER: X -OVER, OIL JARS, BOOT BASKET AND (1) 8 -1/8" WASH PIPE EXTENSION. *MEASURE TO TOP OF FISH AT 28 FT. *8 -1/8" WASH PIPE FISH REMAINING: (2) 8 -1/8" WASH PIPE EXTENSION AND MILL SHOE. (13.7 FT). 07:30 - 08:30 1.00 FISH N DPRB DECOMP MONITOR WELL AND MOBILIZE 4.5" IBT TUBING. - TAKE PICTURES OF THE FISH. - LAY DOWN FISHING BHA. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 09:30 1.00 BOPSUR N DPRB DECOMP FLUSH THE BOP STACK. - 96 SPM WITH 50 PSI. - 60 RPM WITH NO TORO. - BLOW DOWN KILL LINE AND CHOKE. 09:30 - 10:00 0.50 FISH N DPRB DECOMP MOBILIZE HANDLING TOOLS FOR 4.5" IBT TUBING TO THE RIG FLOOR. 10:00 - 10:30 0.50 FISH N DPRB DECOMP MAKE UP (2) JTS 4.5" IBT TUBING. (DRIFT RUN). RUN IN HOLE AND TAG AT 49.5 FT. LAY DOWN TUBING. 10:30 - 12:00 1.50 FISH N DPRB DECOMP CLEAN AND CLEAR RIG FLOOR OF 4.5" HANDLING TOOLS. - MONITOR WELL. *2 POUNDS OF CUTTINGS RECOVERED FROM DITCH MAGNETS. 12:00 - 13:30 1.50 FISH N DPRB DECOMP MONITOR WELL VIA TRIP TANK -WAIT ON PLAN FORWARD. 13:30 - 16:00 2.50 FISH N DPRB DECOMP PJSM ON BULLHEAD OPERATIONS. - BULLHEAD 130 DEG 8.6 PPG SEAWATER. - ALLOW TO BLEED DOWN TO 1000 PSI THEN RE- PRESSURE TO 2000 PSI. - REPEAT CYCLE INJECTING AT TOTAL OF 15 BBLS. 16:00 - 16:30 0.50 FISH N DPRB DECOMP MONITOR WELL TO TRIP TANK. -NO FLOW. 16:30 - 00:00 7.50 FISH N DPRB DECOMP RESUME BULLHEAD CYLE OPERATIONS. - BULLHEAD 130 DEG 8.6 PPG SEAWATER - PRESSURE UP TO 2000 PSI WITH 11 STROKES. - PAINT IN THE PIPESHED, CENTRIFUGAL ROOM, PITS AND PUMP ROOM. - INSULATE AROUND CAT #3 AND MOTORMAN ROOM. *AOGCC, BOB NOBLE, NOTIFIED OF UPCOMING BOPE TEST, 18:00 ON 10- 10 -12. (24 HOUR NOTICE). REQUESTED UPDATE AT 6 AM. *FLUID LOSS FOR 24 HOURS: 27 BBLS. 10/11/2012 00:00 - 02:00 2.00 FISH N DPRB DECOMP BULLHEAD OPERATIONS, CONT. - PRESSURE UP FORMATION 2000 PSI AND BLEED TO 1000 PSI. *WITH 8.5 120 DEG SEAWATER. 02:00 - 02:30 0.50 FISH N DPRB DECOMP MONITOR THE WELL. -LET PRESSURE BLEED DOWN. - MOBILIZE TOOLS FOR UPCOMING BACK OFF OPERATION. 02:30 - 03:30 1.00 FISH N DPRB DECOMP PJSM ON MAKING UP 11 3/4" WASHPIPE ASSEMBLY. - VERIFY 0 PRESSURE. OPEN CHOKE - NO FLOW. - OPEN BLIND SHEARS AND 10 MINUTE FLOW CHECK, NO FLOW. -DRAIN STACK AND VERIFY CLEAR. -BLOW DOWN CHOKE AND KILL LINES. Printed 11/19/2012 11:34:28AM 4 sp o Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 05:30 2.00 FISH N DPRB DECOMP RUN IN HOLE WITH 11 -3/4" WASH PIPE ASSEMBLY FOR BACK OFF ATTEMPT #2 AT 32 FT. -TAG UP AT 29.80 FT FROM ROTARY TABLE SCREWED IN WITH TOP DRIVE. - ATTEMPT SEVERAL TIMES TO GET OVER TOP OF FISH WITHOUT SUCCESS. -20 TO 40 RPM WITH 5 -10K WOB, NO TORQUE AND WOULD NOT DRILL OFF. -SET UP TO 30K WOB WITHOUT ROTATION. NO OVER PULL ON PICK UP. -HANG ASSEMBLY IN ELEVATORS ATTEMPTING TO GET OVER FISH WITHOUT SUCCESS. -NO SIGN ON GRAPPLE, STOP OR TATTLE TALE THAT FISH ENTERED OVERSHOT BOWL. 05:30 - 08:30 3.00 FISH N DPRB DECOMP FILL HOLE AND MONITOR. -NEW PLAN FORWARD FROM TOWN BEING FORMLATED. -PAINT IN CENTRIFUGE ROOM, RIG FLOOR, ABOVE BOILER #1 AND HALLWAYS, CONT. 08:30 - 09:30 1.00 FISH N DPRB DECOMP DRAIN AND VAC STACK. -MEASURE DOWN TO TOP OF FISH AT 28.8 FT W/ DERRICK TAPE. - MEASURE OUTSIDE OF FISH TO 30.4 FT W/ DERRICK TAPE. - MOBILIZE TOOLS FOR MAGNENT RUN. 09:30 - 10:00 0.50 FISH N DPRB DECOMP PJSM ON MAGNENT RUN OPERATION. -RUN IN THE HOLE WITH MAGNET TO TOP OF WASH PIPE AT 29 FT. -PULL OUT OF HOLE AND RECOVER SOME METAL DEBRIS. 10:00 - 12:00 2.00 FISH N DPRB DECOMP LAY DOWN MAGNENT ASSEMBLY. - MONITOR THE HOLE. -RIG UP TO RESUME BULLHEAD PRESSURE AND BLEED INJECTION CYCLES. - PRESSURE TO 2000 PSI AND BLEED TO 1000 PSI. RE- PRESSURE. -PAINT ON RIG FLOOR, ABOVE BOILER #1, AND ABOVE AIR COMPRESSOR #1, CONT. 12:00 - 16:30 4.50 FISH N DPRB DECOMP BULLHEAD PRESSURE AND BLEED CYCLE, CONT. -PAINT IN CENTRIFUGE ROOM, CELLAR, FUEL LINES OUTSIDE. - INVENTORY OF PARTS VANS. Printed 11/19/2012 11:34:28AM e Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 19:00 2.50 FISH N DPRB DECOMP MOBILIZE CUTTER TOOLS TO RIG FLOOR. -MAKE UP 1 JOINT 5" DP, CROSSOVER, 6.5" STABILIZER AND 5.5" MULTI - STRING CUTTER. -RUN IN THE HOLE TO 33.8 FT TO CUT 8 -1/8" WASH PIPE. - INITIAL PARAMETERS AT 40 RPM AND 200 PSI PUMP PRESSURE. -INCREASE PSI TO 400, NO TORQUE INCREASE. -INCREASE PSI UP TO 500 , NO TORQUE INCREASE. - PULL OUT OF HOLE AND INSPECT CUTTERS, NO WEAR ON CUTTERS. -RUN IN HOLE AND SET ON DEPTH, ROTATE AT 40 RPM AND PRESSURE TO 1200 PSI W/ 0 TORQUE. - SURFACE INDICATIONS OF COMPLETE CUT. -CUT OFF WAS NOT RECOVERED WHEN CUTTER PULLED. LAYDOWN CUTTER STAB AND CROSS OVER. 19:00 - 20:00 1.00 FISH N DPRB DECOMP PICK UP SPEAR ASSEMBLY. -MAKE UP 1 JOINT OF 5" DP, CROSSOVER, SPEAR W/ 7.187 INCH GRAPPLE AND 7.5" NO GO. -RUN IN THE HOLE WITH SPEAR TO 29 FT AND BOTTOM ON NO GO. -PULL OUT OF THE HOLE AND RECOVER CUT -OFF. -LAY DOWN SPEAR ASSEMBLY AND 5" DP. *RECOVERY: 4.81 FT OF 8 -1/8" WASHPIPE EXTENSION W/ CLEAN CUT. * *AOGCC, BOB NOBLE WILL BE ON SITE TO WITNESS BOPE TESTING 10 -12 -2012 AT 08:00. 20:00 - 21:00 1.00 BOPSUR N DPRB DECOMP RECOVER WEAR RING. -DRAIN STACK. -PICK UP RUNNING TOOL AND ENGAGE WEAR RING AND REMOVE. - INSPECT WEAR RING AND LAY DOWN RUNNING TOOL. *WEAR BUSHING DID NOT SHOW OBVIOUS SIGNS OF DAMAGE. 21:00 - 22:00 1.00 BOPSUR N DPRB DECOMP WASH STACK. - MAKE UP 1 JOINT OF 5" DP, CROSSOVER AND STACK WASHER. - MEASURE IN BY 5 FT STICK TO CONFIRM DEPTH OF WASHING. -PUMP 14 BPM AT 100 PSI W/ 20 RPM. - RECIPROCATE STACK WASH FROM CASING BOWL THRU ANNULAR PREVENTER W/ MULTIPLE PASSES. -LAY DOWN STACK WASHER, CROSSOVER AND 5" DP. Printed 11/19/2012 11:34:28AM - North America - ALASKA • • i, tion rY Summa R R. a rt _ � Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:00 1.00 BOPSUR N DPRB DECOMP MAKE UP TEST PLUG TO 4" TEST JOINT AND RUN IN HOLE. -BACK OUT TEST JOINT. -FLUSH KILL LINE FOR AIR, SHUT SHEAR RAM, FLUSH AIR OUT OF CHOKE LINE. -SHUT IN WITH BLIND SHEARS. *SHELL TEST TO 250/3500 PSI FOR 5 MINUTES -OK. -BLOW DOWN LINES. 23:00 - 00:00 1.00 FISH N DPRB DECOMP -PJSM FOR DRILLING LINE SLIP AND CUT OPERATION. -RIG UP TO. SLIP AND CUT. BEGIN CONTINUOUS HOLE FILL AND MONITORING. 10/12/2012 00:00 - 02:30 2.50 FISH N DPRB DECOMP SLIP AND CUT DRILLING LINE, CONT. -LAY DOWN LONG BALES. -SLIP AND CUT DRILLING LINE. -GREASE AND INSPECT TOP DRIVE AND BLOCKS. 02:30 - 06:00 3.50 BOPSUR N DPRB DECOMP RIG UP BOPE TEST EQUIPMENT. -PICK UP 4" TEST JOINT. -LAY DOWN TOOLS AND MOBILIZE TOOLS FOR UPCOMING BOPE TEST. -RIG UP TO CIRCULATE ACROSS THE WELL DOWN INJECTION LINE WITH RETURNS THROUGH THE CEMENT LINE. - MONITOR HOLE FILL. - PAINT CENTRIFUGE ROOM, WASHING MACHINE AREA AND PUMP ROOM, CONT. 06:00 - 06:30 0.50 BOPSUR N DPRB DECOMP PJSM ON BOPE TEST. -FILL STACK WITH WATER. - FLUSH OUT SOAPY BRINE FROM LINES. 06:30 - 12:00 5.50 BOPSUR N DPRB DECOMP BOPE TEST. - PRESSURE TEST ANNULAR PREVENTER 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST 3.5 X 6 UPPER VBR AND CHOKE VALVES 1, 12,13,14 AND UPPER IBOP. -TEST GAS ALARMS ON THE RIG. *59 STROKES TO FILL CHOKE MANIFOLD AND GAS BUSTER. *AOGCC, BOB NOBLE ON LOCATION TO WITNESS BOPE TESTING. 12:00 - 19:30 7.50 BOPSUR N DPRB DECOMP BOPE TEST, CONT. -TEST CHOKE VALVES 1,2,4,5,6,7,8,10. -TEST (2) 4" FOSV, 4" DART VALVE, (2) 4.5" FOSV AND MANUAL IBOP. -TEST HCR, KILL, CHOKE VALVES. - TEST KILL LINE VALVE IN THE PITS. - TEST 3.5 x 6 VBR AND 2 -7/8 X 5 VBR WITH 4" TEST JOINT TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. - MANUAL PRESSURE LOCK TEST WAS GOOD ON 3.5 X 6 VBR W/ 4" AND 5" TEST JOINTS. - MANUAL PRESSURE LOCK TEST FAILED ON 2 -7/8 X 5 VBR WITH 5" TEST JOINT. - KOOMEY RAM TEST ON BOTH VBR WITH 5" TEST JOINT WAS GOOD. - KOOMEY DRAWDOWN TEST. *CHANGE OUT 0-RINGS BELOW SUPER CHOKE BETWEEN VALVES 5 AND 9. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 21:00 1.50 BOPSUR N DPRB DECOMP PJSM FOR RAM CHANGE OPERATION. - REMOVE MOUSE HOLE. - CHANGE OUT 2 -7/8 X 5 VBR TO 5" SOLID BODY RAMS IN SINGLE RAM CAVITY. - INSTALL MOUSE HOLE. 21:00 - 00:00 3.00 BOPSUR N DPRB DECOMP BOPE TEST, CONT. -TEST 5" SOLID RAMS TO TEST 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. -PULL 5" TEST JOINT. - TEST BLIND SHEAR RAMS AND MANUAL PRESSURE LOCKS ON BLIND SHEAR RAMS -OK. * FLUID LOSS FOR 24 HOURS: 0 BBL 10/13/2012 00:00 - 01:00 1.00 BOPSUR N DPRB DECOMP BOPE TEST, CONT. -TEST CHOKE VALVES 3 AND 9. -TEST HYDRAULIC AND MANUAL CHOKE ON CHOKE MANIFOLD. -BLOW DOWN CHOKE AND KILL LINE. 01:00 - 01:30 0.50 BOPSUR N DPRB DECOMP RIG DOWN 'BOP TEST EQUIPMENT. - BREAK OUT CROSSOVERS AND PULL TEST PLUG. 01:30 - 05:00 3.50 FISH N DPRB DECOMP BEGIN RIG UP OF CASING JACK EQUIPMENT. -NIPPLE DOWN RISER AND FLOW LINE. -PICK UP (2) 7 FT 13 -5/8" SPACER SPOOLS AND MAKE UP ON RIG FLOOR. - NIPPLE UP SPACER SPOOLS TO TOP OF ANNULAR. -HOLE FILL AND MONITORING, CONT. 05:00 - 12:00 7.00 FISH N DPRB DECOMP WAIT ON CASING JACK SYSTEM EQUIPMENT. - DERRICK INSPECTION. - GENERAL CLEANING AND HOUSEKEEPING. - CHANGE OUT BREAKER BOX ON #2 CAT ENGINE. -PAINT IN PITS AND CENTRIFUGE ROOM, CONT. *RIG EVACUATION SHUT DOWN TEST, ALL SWITCHES WORKED. 12:00 - 18:00 6.00 FISH N DPRB DECOMP WAIT ON CASING JACK SYSTEM EQUIPMENT, CONT. -PAINT IN PITS AND CENTRIFUGE ROOM, CONT. -PREP RIG FLOOR FOR UPCOMING CASING JACK OPS. -WELD ON STAIRS BEHIND THE DRAWWORKS AND ADD WEATHER STRIPPING. - CLEAN AND PREP HOPPER ROOM FOR PAINT. -CLOSE BLIND RAMS AND FILL SURFACE LINES. - BULLHEAD: PRESSURE TO 2000 PSI ONCE EVERY HOUR, AND LET BLEED OFF. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 00:00 6.00 FISH N DPRB DECOMP WAIT ON CASING JACK SYSTEM EQUIPMENT, CONT. - BULLHEAD: PRESSURE TO 2000 PSI ONCE EVERY HOUR, AND LET BLEED OFF, CONT. -STAGE PAINTING SUPPLIES ON THE RIG. -CLEAN AND PREP HOPPER ROOM FOR PAINT, CONT. -PAINT ON THE RIG FLOOR. - MOBILIZE BAKER TOOLS TO THE RIG FLOOR. -MAKE UP SPEAR ASSEMBLY AND LAY DOWN IN PIPE SHED. - OFFLOAD 7" CASING ASSEMBLY TO PIPE SHED. *BULLHEAD A TOTAL OF 1.9 BBLS, TAKING 0.7 BBLS FOR PRESSURE CYCLE. 10/14/2012 00:00 - 02:30 2.50 FISH N DPRB 43.00 DECOMP PJSM ON MOBILIZING AND RIG UP CASING JACK EQUIPMENT. - MOBILIZE EQUIPMENT TO RIG FLOOR. -SET IN BOTTOM PLATE WITH (3) 150 TON HYDRAULIC JACKS AND SECURE TO 13 -5/8" RISER SPOOL. -SET IN TOP PLATE WITH 13 -5/8" CASING HEAD. 02:30 - 12:00 9.50 FISH N DPRB 43.00 DECOMP WAIT ON INSPECTION AND FINAL RIG UP OF CASING JACK EQUIPMENT. - GENERAL PAINTING AND HOUSEKEEPING AROUND RIG. - BULLHEAD DOWN CASING TO 2000 PSI ON HOURLY BASIS. 12:00 - 15:00 3.00 FISH N DPRB 43.00 DECOMP FINAL INSPECTION AND APPROVAL OF PROCEDURES FOR CASING JACK OPERATION. - CLEANING AND PAINTING IN HOPPER ROOM, CENTRIFUGE ROOM AND THROUGHOUT RIG. - INSPECT CURRENT RIG UP OF JACKS ON RIG FLOOR. - BULLHEAD DOWN TUBING WITH MAX PRESSURE OF 2000 PSI, CONT. - WELD ON NEW FUEL STATION ON FRONT OF THE RIG. - ADJUST CABLE ON THE PIPE SKATE. Printed 11/19/2012 11:34:28AM it , Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 00:00 9.00 FISH N DPRB 43.00 DECOMP PJSM ON INSTALLING BAKER FISHING SPEAR ON BHA, USING FMC EMERGENCY SLIPS AND JACKING OPERATIONS. -RUN IN HOLE WITH SPEAR W/ EXTENSION AND NO GO, 5" DP PUP, CROSSOVER TO 7" BTC, 7" L80 CASING PUP. -TAG ON 8 -1/8" WASH PIPE AT 33.8 FT WITH NO GO. -PICK UP TO 150K TO INSURE SPEAR IS ENGAGED. - SLACK OFF TO 100K AND SET 7" CASING SLIPS WITH JACKS EXTENDED 4 ". -CLOSE ANNULAR TO PREVENT ANYTHING FROM FALLING IN THE HOLE DURING OPS. - ENGAGE HYDRAULIC JACKING UNITS SLOWLY, WATCHING PRESSURES. - PRESSURE UP TO 1000 PSI AT 90K AND MONITOR. - PRESSURE UP` TO 2000 PSI AT 180K AND MONITOR. -PRESSURE UP TO 2500 PSI AT 225K AND MONITOR. -PRESSURE UP TO 3000 PSI AT 270K AND MONITOR. *NOTE: CACULATED FORCE= PSI*90 (30 LBF PER PSI PER JACK) - BEGIN JACKING OPERATIONS. *JACK CYCLE #1 MAX PRESSURE 4770 PSI AT 429K. - MOVE PIPE 2 ". - BLEED PRESSURE AND DISENGAGE SLIPS FROM BOWL. *JACK CYCLE #2. -JACKS EXTENDED 2" AND PULL TO200K AND ENGAGE SLIPS. - MAX PRESSURE 3600 PSI AT 324K. - MOVE PIPE 4.5 ", TOTAL JACKED =6.5 INCHES. -BLEED PRESSURE AND DISENGAGE SLIPS FROM BOWL. *JACK CYLE #3. -JACKS EXTENDED TO 2" AND PULL TO 200K AND ENGAGE SLIPS. -MAX PRESSURE 4600 PSI AT 414K. - MOVE PIPE 5 ", TOTAL JACKED =11.5 INCHES. - BLEED PRESSURE AND DISENGAGE SLIPS FROM BOWL. *FLUID LOST TO WELL FOR 24 HOURS: 2.2 BBL. 10/15/2012 00:00 - 01:00 1.00 FISH N DPRB 42.00 DECOMP JACK STUCK 8 -1/8" WASH PIPE OPERATIONS, CONT. -JACK CYCLE #4. -4800 PSI AT 430K. (MAX SET BY TOWN). -MOVE PIPE 1 ", TOTAL JACKED 12.5 INCHES. -BLEED HYDRAULIC PRESSURE. - SUSPEND JACKING OPERATIONS. Printed 11/19/2012 11:34:28AM 2 s L Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 12:00 11.00 FISH N DPRB 42.00 DECOMP SUSPENDED JACKING OPERATIONS, CONT. - BULLHEAD DOWN CASING TO 2000 PSI AND BLEED ON HOURLY BASIS. - REST BOOTS AND COOTS TECHS. - FABRICATE PLATES TO ASSIST IN DISENGAGING SLIPS FROM BOWL. - GENERAL HOUSEKEEPING AND PAINTING, CONT. 12:00 - 18:00 6.00 FISH N DPRB 42.00 DECOMP SUSPENDED JACKING OPERATIONS, CONT. PJSM FOR JACKING OPERATIONS. -INSPECT RIG UP OF CASING JACK EQUIPMENT. - CHANGE OUT 5" ELEVATORS. -CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS. - GENERAL PAINTING AND HOUSEKEEPING AROUND RIG, CONT. -WELD ON FUEL BOX OUTSIDE IN FRONT OF THE RIG. - RECEIVE ORDERS FROM TOWN TO RESUME JACKING OPERATION TO 530K. 18:00 - 21:30 3.50 FISH N DPRB 42.00 DECOMP > RESUME JACKING OPERATIONS. -JACK CYCLE #4, CONT. - REACH MAX PRESSURE AT 5900 PSI TO 530K. (MAX SET BY TOWN). - REPEAT 5 TIMES TO 5900 PSI WITHOUT MOVEMENT. - MOVE PIPE 2 ", TOTAL JACKED 14.5 INCHES. -BLEED HYDRAULIC PRESSURE. -RIGUP 1" BOTTOM PLATE, (3) 100 TON JACKS, 1" TOP PLATE AND DRIVE BUSHING WITH 7" CASING SLIPS. - DISENGAGE CASING SLIPS FROM CASING HEAD. -RIG DOWN SLIP JACKING EQUIPMENT. - SUSPEND CASING JACKING OPERATIONS. 21:30 - 22:00 0.50 FISH N DPRB 42.00 DECOMP RELEASE SPEAR. -SCREW INTO TOP DRIVE TO RELEASE THE SPEAR. - CONFIRM 0 PSI PRESSURE AND OPEN ANNULAR. - ROTATE 1 TURN TO THE RIGHT TO DISENGAGE SPEAR AND PICK UP TO CONFIRM. -SET DOWN ON NO-GO. -BACK OUT OF TOP DRIVE AND LATCH UP ELEVATORS. -PULL SPEAR ASSEMBLY OUT OF HOLE. 22:00 - 23:00 1.00 FISH N DPRB 42.00 DECOMP PJSM ON RIG DOWN OF TOP PLATE AND CASING HEAD. -RIG DOWN 2" TOP PLATE WITH CASING HEAD - SEPERATE CASING HEAD FROM TOP PLATE. -DEMOB FROM RIG FLOOR. 23:00 - 00:00 1.00 FISH N DPRB 43.00 DECOMP PJSM ON LAYING DOWN BHA OPERATION. -LAY DOWN 7" CASING JOINT AND 5" DRILL PIPE PUP JOINT. - CHANGE OUT SPEAR GRAPPLE. - LOAD OUT 2" TOP PLATE AND ROTARY DRIVE BUSHING FOR MODIFICATION AT GBR. *FLUID LOSS FOR 24 HOURS = 2 BBL. Printed 11/19/2012 11:34:28AM # t # # Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/16/2012 00:00 - 01:30 1.50 FISH N DPRB 42.00 DECOMP PJSM ON PICKING UP BHA OPERATION. -PICK UP 5" DC, 5.75' FLEX PIPE PUP JOINT AND SPEAR ASSEMBLY. -LEAVE HANGING IN ELEVATORS. 01:30 - 12:00 10.50 FISH N DPRB 42.00 DECOMP BULLHEAD TO CASING TO 2000 PSI AND LET BLEED ON HOURLY BASIS. - MODIFY 2" TOP PLATE AT GBR WITH SKIRT TO ACCOMADATE ROTARY DRIVE BUSHING. - GENERAL HOUSEKEEPING AND PAINTING. *2.8 BBLS TOTAL PUMPED DOWN TUBING DURING TOUR. 12:00 - 19:30 7.50 FISH N DPRB 42.00 DECOMP BULLHEAD TO CASING TO 2000 PSI AND LET BLEED ON HOURLY BASIS, CONT. - MODIFY 2" TOP PLATE AT GBR WITH SKIRT TO ACCOMADATE ROTARY DRIVE BUSHING, CONT. - GENERAL HOUSEKEEPING AND PAINTING,CONT. - INVENTORY PARTS VAN. 19:30 - 21:30 2.00 FISH N DPRB 42.00 DECOMP PJSM START JACKING OPERATIONS. -JACK MAX PSI 720K, HELD, REPEATED SEVERAL TIMES. - JACKED 720K AND RELAXED SEVERAL TIMES TO TRY TO FATIGUE DEBRIS IN HOLE. *GAINED 7 ", STOPPED TO REEVALUATE OPTIONS. 21:30 - 22:30 1.00 FISH N DPRB 42.00 DECOMP PJSM TO DISENGAGE JACKS. - DISENGAGE SPEAR AND PULL TO RIG FLOOR. -RIG DOWN TABLE ASSEMBLY. - REMOVE 3.54" SPEAR EXTENSION FROM BHA AND RE TORQUE TO SPECS. (BHA# 28) - INSTALL TABLE ASSEMBLY AND RUN IN HOLE TO STOP RING. - GET 2" SAFETY FACTOR ON JACKS AND INSTALL SLIPS. 22:30 - 23:30 1.00 FISH N DPRB 42.00 DECOMP JACKING OPERATIONS, CONT. - GAINED AN ADDITIONAL 3.5" FOR A TOTAL OF 10.5" TODAY - STOPPED JACKING OPERATIONS AND CONSULT WITH TOWN ON OPTIONS. DECIDED TO SET UP FOR CUTTING OPERATIONS PENDING APPROVAL. *MAX JACKING FORCE OF 720K. 23:30 - 00:00 0.50 FISH N DPRB 42.00 DECOMP PJSM DISENGAGE SPEAR AND PULL TO RIG FLOOR. -CLOSE BLIND RAMS - REMOVE TABLE ASSEMBLY. - BREAK DOWN BAKER BHA. 10/17/2012 00:00 - 01:00 1.00 FISH N DPRB 42.00 DECOMP LAY DOWN BHA THROUGH BEAVER SLIDE. -PICK UP BAKER CUTTER TO RIG FLOOR. 01:00 - 02:30 1.50 FISH N DPRB 42.00 DECOMP PUMPING DOWN TUBING WITH BLIND RAMS CLOSED TO 2000 PSI AND LET BLEED DOWN. - PULL AND LAY DOWN (2) 7 FT 13 -5/8" SPACER SPOOLS. 02:30 - 04:00 1.50 FISH N DPRB 42.00 DECOMP PUMPING DOWN TUBING WITH BLIND RAMS CLOSED TO 2000 PSI AND LET BLEED DOWN. - INSTALL BELL NIPPLE AND RISER FLOWLINE. Printed 11/19/2012 11:34:28AM z ^ -44 Arf,A Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 04:30 0.50 FISH N DPRB 42.00 DECOMP PUMPING DOWN TUBING WITH BLIND RAMS CLOSED TO 2000 PSI AND LET BLEED DOWN. - SERVICE BREAK STRING CUTTER AND INSTALL KNIVES. 04:30 - 06:00 1.50 FISH N DPRB 42.00 DECOMP PUMPING DOWN TUBING WITH BLIND RAMS CLOSED TO 2000 PSI AND LET BLEED DOWN (3 CYCLES TOTAL FROM 01:45 AM TO 06:00 AM 2.6 BBLS TOTAL BULLHEADED DOWNHOLE). -PAINTING PUMP ROOM, PIPE SHEDS AND PITS. -CUT STRAPS FOR MASTER BUSHINGS ON JACKING ASSEMBLY. - INSTALL MASTER, BUSHINGS. -PICK UP AND MAKE UP BHA # 29 (STRING CUTTER) /STASILIZERIX- OVER/2 JTS 5 "' DP. 06:00 - 08:30 2.50 FISH N DPRB 42.00 DECOMP BULLHEAD TO CASING TO 2000 PSI AND LET BLEED ON HOURLY BASIS, CONT. 08:30 - 09:00 0.50 FISH N DPRB 42.00 DECOMP MAKE UP 5.5 BAKER M.S. CUTTER WITH STABILIZER. -RUN IN THE HOLE TO 39 FEET. 09:00 - 10:00 1.00 FISH N DPRB 42.00 DECOMP CUTTING OPERATIONS -CUT FISH WITH 52 SPM AT 1020 PSI WITH 80 RPM. - TORQUE AT 3K, PRESSURE DROP 200 PSI. -PULL OUT OF THE HOLE. 10:00 - 10:30 0.50 FISH N DPRB 42.00 DECOMP PULL OUT OF THE HOLE, CONT. -LAY DOWN BAKER CUTTER. - PICK UP BAKER SPEAR AND GRAPPLE. 10:30 - 11:30 1.00 FISH N DPRB 42.00 DECOMP SPEAR TUBING. -PULL WITH 100K OVER PULL 4 TIMES WITH NO -GO. -PULL OUT OF THE HOLE. -PICK UP THE 5.5 M.S. BAKER CUTTER. -RUN IN THE HOLE TO 39 FEET. 11:30 - 12:00 0.50 FISH N DPRB 42.00 DECOMP CUTTING OPERATIONS. -CUT WINDOW AT 39 FEET WITH 80 RPM. - TORQUE AT 3K AND 52 SPM WITH 1020 PSI. - PSI DROPPED TO 840. -PULL OUT OF THE HOLE AND LAY DOWN 5.5 BAKER M.S CUTTER. *TOTAL 3 BBLS PUMPED DURING 12 HOUR TOUR. 12:00 - 14:30 2.50 FISH N DPRB 42.00 DECOMP PJSM MAKE UP BAKER SPEAR, RUN IN THE HOLE. -MAKE UP TO THE TOP DRIVE. - ENGAGE AND ATTEMPT TO PULL FISH. -PULL TO 150K TO CONFIRM GRAPPLE IS SET. - INCREASE PULL BY 10K INCREMENTS UP TO 190K. -MADE DECISION TO RIG UP JACKING SYSTEM. -BROKE OUT OF TOP DRIVE. - RELEASE GRAPPLE WITH 1 TURN TO THE RIGHT. -PULL OUT OF THE HOLE AND LAY DOWN THE SPEAR. - LAY DOWN 2 JOINTS OF 5" DRILL PIPE. Printed 11/19/2012 11:34:28AM 4 ffi• ` r. 4 Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 18:00 3.50 FISH N DPRB 42.00 DECOMP PJSM NIPPLE DOWN THE RISER EQUIPMENT. SUCK OUT STACK, BLOW DOWN HOLE FILL LINE. -BLEED OFF LINE, REMOVE FLOW LINE, RISER, BELL NIPPLE. - NIPPLE UP 2 7" SPACER SPOOLS ON THE RIG FLOOR AND ATTACH TO TOP OF ANNULAR BOP. 18:00 - 19:30 1.50 FISH N DPRB 42.00 DECOMP MAKE UP BAKER SPEAR ASSEMBLY. MAKE UP JACKS, BUSHING ASSEMBLY. -TEST JACKING SYSTEM. 19:30 - 21:00 1.50 FISH N DPRB 42.00 DECOMP PJSM CHECK FOR PRESSURE BELOW, AT O PSI. -OPEN BLIND SHEAR RAMS. - RUN IN THE HOLE WITH ASSEMBLY. - SPEAR FISH, PICK UP TO 150K. - SLACK OFF TO 70K. -CLOSE BAG ELEMENT TO REDUCE CLOSING PRESSURE TO 350 PSI. - INSTALL 5 " SLIPS AND SET INTO BUSHINGS. -SLACK OFF THE BLOCKS TO TOP DRIVE WEIGHT. 21:00 - 21:30 0.50 FISH N DPRB 42.00. DECOMP JACKING OPERATIONS. MAX JACKING PRESSURE OF 720K. 21:30 - 00:00 2.50 FISH N DPRB 42.00 DECOMP PJSM REMOVE SLIPS. - REMOVE ALL PRESSURE ON THE JACKS. - SCREW INTO WITH TOP DRIVE. -APPLY DOWN WEIGHT AND TURN 1 TO THE RIGHT TO RELEASE BAKER GRAPPLE. -BREAK OUT OF TOP DRIVE. - PULL ASSEMBLY TO THE RIG FLOOR. -RIG DOWN THE TABLE ASSEMBLY. -BREAK BHA DOWN. -CLEAR RIG FLOOR OF ALL TOOLS AND EQUIPMENT NOT NEEDED FOR UPCOMING OPS. - REMOVE RISERS. 10/18/2012 00:00 - 02:00 2.00 FISH N DPRB 42.00 DECOMP LAY DOWN RISERS, CONT. -LOWER JACKING PLATE. - BRING UP RISERS. - SUCK OUT STACK TO INSPECT FISH 02:00 - 09:00 7.00 FISH N DPRB 42.00 DECOMP NIPPLE UP BELL NIPPLE AND FLOWLINE - CLOSE BLIND RAMS - BULLHEAD TO CASING TO 2000 PSI AND LET BLEED -WAIT ON APPROVAL FROM TOWN 09:00 - 12:00 3.00 BOPSUR N DPRB 42.00 DECOMP BOP STACK LEAKING -BLEED OFF TUBING AND CHECK TORQUE ON BOPE STACK AT TUBING SPOOL. 12:00 - 15:30 3.50 BOPSUR N DPRB 42.00 DECOMP PJSM CHECK TORQUE ON BOPE STACK, CONT. -CHECK TORQUE ON FLANGES AND REMOVE TURNBUCKLES ON STACK. - REMOVE STACK YOLK, TORQUE UP BOLTS ON ANNULAR BOP. - REINSTALL YOLK AND INSTALL ALL PINS AND KEEPERS. - ATTACH TURNBUCKLES AND SECURE STACK. - MOBILIZE BAKER TOOLS TO THE RIG FLOOR. Printed 11/19/2012 11:34:28AM #." I Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 16:00 0.50 BOPSUR N DPRB 42.00 DECOMP PRESSURE TEST CONNECTIONS ON BOPE STACK. -TEST BLIND SHEAR RAMS TO 2000 PSI -HELD PRESSURE FOR 5 MINS, GOOD, BLED OFF. 16:00 - 17:00 1.00 FISH N DPRB 42.00 DECOMP PJSM MAKE UP BAKER BHA. - MAKE UP PUP JOINT, CROSSOVER, BIT SUB, BOOT BASKET, PILOT MILL. 17:00 - 00:00 7.00 FISH N DPRB 42.00 DECOMP PJSM, RUN IN THE HOLE TO 31.5 FEET, PICK UP A COUPLE INCHES. - START MILLING OPERATIONS, 100 RPM AT 0 TORQUE -40 PSI AT 7 BPM, WEIGHT ON BIT 3 -5K. -PUMP 'HIGH-VIS 'SWEEP EVERY 30 MINS. -PULL OUT OF HOLE AFTER MILLING 2 FOOT. -PULL OUT OF HOLE AND CHECK MILL AND BOOT BASKET, *BOOT BASKET WAS CLEAN AND MILL LOOKED TO BE IN GOOD SHAPE. -RUN IN THE HOLE TO 35.5 FEET AND CONTINUED TO MILLING OPERATIONS. -STOP MILLING AT 38' (TOTAL OF 6.5' MILLED) * * *NOTIFIED AOGCC @ 18:30 OF INTENT TO TEST BOP'S TOMORROW- JOHN CRISP (AOGCC) CONFIRMED NOTIFICATION AT 19:45 * ** 10/19/2012 00:00 - 00:30 0.50 FISH N DPRB 42.00 DECOMP -POOH FROM 38' -CLEAN 2 GAL MIXED METAL FROM BOOT BASKET (SS TUBING, COPPER WIRE, PIECES OF CLAMPS) - CLEANED SMALL AMOUNT OF DEBRIS FROM AROUND STRING - CHANGED OUT PILOT MILL FOR PACKER MILL -RIH TO 38' AND TAG FISH 00:30 - 05:00 4.50 FISH N DPRB 42.00 DECOMP MILL WITH PACKER MILL FROM 38' TO 40' - MILLING AT 70 RPM ON TOP DRIVE, WEIGHT ON BIT -2K, PUMP PRESSURE 40 PSI, 6.2 BBL/MIN PUMP RATE 05:00 - 07:00 2.00 FISH N DPRB 42.00 DECOMP 10 MINUTE FLOW CHECK, HOLE STATIC - LAY DOWN DRILL COLLARS, BOOT BASKET, BIT SUB, LONG BALES AND CROSS OVERS (BHA 34) 07:00 - 10:00 3.00 FISH N DPRB 42.00 DECOMP PICK UP XT -39 SAVER SUB AND CHANGE OUT 4-1/2" IF SAVER SUB. - CHANGE OUT GRABBER JAWS AND GUIDE BOWL - INSTALL SHORT BALES 10:00 - 11:00 1.00 BOPSUR N DPRB 42.00 DECOMP BLOW DOWN CHOKE AND KILL LINES, MAKE SURE CLEAR OF METAL DEBRIS - PICK UP 2 JOINTS OF XT -39 DRILL PIPE, MAKE UP BOP STACK WASHER AND FLUSH STACK WITH HIGH VIS SWEEP. - FUNCTION TEST BOP RAMS, PUMP @ 8.5 BPM, PRESSURE AT 40 PSI WITH 40 RPM. -DID GET METAL SHAVING AND DEBRIS BACK. -LAY DOWN DRILL PIPE SINGLES. -BLOW DOWN TOP DRIVE AND INSTALL WEAR RING. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:30 1.50 BOPSUR N DPRB 42.00 DECOMP TRANSFER 43/4" DRILL COLLARS FROM OFF DRILLERS SIDE TO DRILLERS SIDE IN DERRICK - MAKE UP FISHING MAGNET BHA - RIH TO 74', TAGGED UP -POOH TO CHECK MAGNET, VERY LITTLE METAL MATERIAL ON MAGNET -RN AGAIN AND TAGGED UP AT 74' -POOH, NO MATERIAL ON MAGNET 12:30 - 13:30 1.00 BOPSUR N DPRB DECOMP CLEAR RIG FLOOR OF JACKING EQUIPMENT 13:30 - 14:30 1.00 BOPSUR N DPRB DECOMP RIG UP TO TEST BOP AS PER PROCEDURES -JOHN CRISP (AOGCC) CALLED AT 14:00 TO WAIVE WITNESS OF BOP TEST 14:30 - 00:00 9.50 BOPSUR N DPRB DECOMP TEST 2 - XT -39 FOSV AND XT -39 DART VALVE 3500 PSI HI AND 250 PSI LO FOR 5 MIN EACH -HAD TROUBLE GETTING TEST PLUG TO SET IN LOWER WELLHEAD SPOOL -CALL FOR FMC WELLHEAD REP -FMC BROUGHT OUT REPLACEMENT PLUG AND INSPECTED WELLHEAD BOWL BEFORE APPLYING ANY PRESSURE ON TEST PLUG - FILLED GAS BUSTER -6 BBLS TO FILL -PERFORMED DERRICK INSPECTION -TESTED ALL COMPONENTS TO 250 LO /3500 HI. - PERFORMED DRAWDOWN TEST ON KOOMEY - PERFORMED DRAWDOWN TEST ON MANUAL CHOKE - PERFORMED DRAWDOWN TEST ON HYDRAULIC CHOKE - FAILED: RIG MECHANIC OVER TO TROUBLESHOOT 10/20/2012 00:00 - 02:30 2.50 BOPSUR N DPRB 42.00 DECOMP COMPLETED BOP TEST, PULL LOWER TEST PLUG AND INSTALL WEAR RING. - BLOW DOWN CHOKE AND KILL LINES AND CHOKE MANIFOLD. - PICK UP BAKER RUNNING TOOLS FOR NEXT OPERATION. - TROUBLE SHOOT SUPER CHOKE SEAT AND STEM: REPLACE CHOKE STEM AND SEAT, RETEST -GOOD 02:30 - 04:30 2.00 BOPSUR N DPRB 74.00 DECOMP PJSM, MAKE UP BHA #36 MILLING ASSEMBLY -RIH TO 74' AND HAD LIGHT TAG. -P /U 5' AND ESTABLISH MILLING PARAMETERS: 6.5 BBUMIN PUMP RATE @ 40 PSI, 100 RPMS WITH TORQUE LIMITER SET AT 5K -EASE BACK INTO HOLE TO 85', NO TAG -P /U 5' AND STOP ROTATION, EASE BACK INTO HOLE TO 103' -NO TAG -P /U 1 STAND DRILL PIPE AND RIH-NO TAG -P /U 1 STAND AND RIH. TAGGED AT DEPTH OF 205' Printed 11/19/2012 11:34:28AM S ' %.. Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 08:30 4.00 BOPSUR N DPRB 196.00 DECOMP ESTABLISH MILLING PARAMETERS: 6.5 BBUMIN PUMP RATE @ 40 PSI, 100 RPMS WITH TORQUE LIMITER SET AT 5K, WOB 3K - MILLED DOWN TO 208', FLOW CHECK, BLOW DOWN TOP DRIVE -PULL OUT OF HOLE TO 112', PICKED UP ONE 6 -1/■" DRILL COLLAR ADDED TO BHA, STAND BACK STAND IN DERRICK. -CONTINUE TO PULL OUT OF HOLE TO CHECK FACE OF MILL. 08:30 - 10:00 1.50 BOPSUR N DPRB 196.00 DECOMP BREAK JUNK MILL OFF AND RECOVERED ONE (1) POUND OF METAL DEBRIS 10:00 - 10:30 0.50 BOPSUR N DPRB 196.00 DECOMP LINE UP KILL LINE TO PUMP DOWN WELL BORE. -PURGE KILL LINE SHUT BLIND /SHEAR RAMS, BROUGHT PUMP PRESSURE UP TO 2K, PRESSURE SLOWLY BLEEDING OFF -WELL PACKED OFF WITH DEBRIS, BLEED OFF PRESSURE, BLOW DOWN KILL LINE 10:30 - 11:00 0.50 BOPSUR N DPRB 208.00 DECOMP MAKE UP BHA #37, ADDED 2 MORE DRILL COLLARS OF PIPE SHED TO 193', CONTINUED OUT OF DERRICK TO 208' -""DEBRIS /JUNK WENT DOWN HOLE 3' WHEN PRESSURE WAS APPLIED. ** 11:00 - 12:00 1.00 BOPSUR N DPRB 208.00 DECOMP START MILLING AT 208', ESTABLISH MILLING PARAMETERS: -8 BBUMIN PUMP RATE @ 110 PSI, 100 RMPS WITH TORQUE LIMITER SET AT 2K, WOB @ 8 -9K 12:00 - 13:30 1.50 BOPSUR N DPRB 208.00 DECOMP MILLING CONTINUE FROM 208' TO 208.1' -PICK UP WEIGHT= 65K, SLACK OFF WEIGHT= 65K, ROTATE WEIGHT= 65K, 8 BBU MIN @ 110 PSI, RPM= 110, TORQUE= 1 -2K, WEIGHT ON BIT= 12K 13:30 - 14:30 1.00 BOPSUR N DPRB 208.00 DECOMP FLOWCHECK- WELL STATIC -PULL OUT OF HOLE WITH BHA AND CHANGE OUT MILL 14:30 - 15:00 0.50 BOPSUR N DPRB 208.00 DECOMP RUN IN HOLE, TAGGED FISH AT 208' 15:00 - 18:00 3.00 BOPSUR N DPRB 211.00 DECOMP MILL FROM 208' TO 211' -PUW= 65K, SOW= 65K, ROT= 65K, 8 BBUMIN @130 PSI, RPM= 80, TORQUE= 1K, WOB= 4 -5K ESTABLISH SLOW PUMP RATES: PUMP #1- 20 SPM= 50 PSI. 30 SPM= 80 PSI. PUMP #2- 20 SPM= 50 PSI, 30 SPM= 80 PSI. 18:00 - 18:30 0.50 BOPSUR N DPRB 211.00 DECOMP SHUT BAG AND PRESSURE UP WELL TO 500 PSI. CONTINUED TO INJECT AT 500 PSI AT RATE OF 1.5 BBUMIN. -SHUT DOWN PUMPS, BLEED PRESSURE OFF AND OPENED BAG. LINE UP PITS TO MILL. Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 00:00 5.50 BOPSUR N DPRB 212.00 DECOMP MILL FROM 211' TO 212' PUW 65K, SOW 65K, ROT 65K, PUMP RATE @ 10 BBUMIN @ 190 PSI, 80 RPM @ 2-3 K TORQUE, WOB 5 -7K, - PERFORMED KICK WHILE DRILLING DRILL -@ 20:00 HAD 60 BBUHR LOSSES -@ 21:00, LOSSES SLOWED TO 30 BBUHR -@ 21:30, LOSSES CEASED - GELLED UP ALL FLUIDS IN PITS TOTAL LOSSES FOR 24 HRS = 115 BBLS 10/21/2012 00:00 - 01:30 1.50 FISH N DPRB 212.00 DECOMP CONTINUE TO MILL FROM 212' TO 212' - WEIGHT ON BIT = 8 -9K, PICK UP WEIGHT= 65K, SLACK OFF WEIGHT= 65K, ROTATE WEIGHT= 65K -PRESSURE ON BOTTOM= 180 PSI. PRESSURE OFF BOTTOM= 180 PSI. - LOSING 8 BBL/ HOUR WITH PUMPS ON @ 10 BBUMIN. 01:30 - 03:00 1.50 FISH N DPRB 212.00 DECOMP FLOW CHECK WELL- STATIC -BLOW DOWN TOP DRIVE, STAND BACK ONE STAND OF 4" DRILL PIPE & ONE STAND OF 6 -1/4" DRILL COLLARS -PULL OUT OF HOLE TO EMPTY BOOT BASKET AND INSPECT MILL. - EMPTIED 3 GAL METAL (COPPER, STAINLESS STEEL AND CLAMP PIECES) FROM BOOT BASKETS - AVERAGING 4 BBLS /HR LOSS - INSPECTED MILL: SLIGHT WEAR PATTERN ON OUTER EDGE WITH SMALL AMOUNTS OF WEAR ON INTERIOR OF MILL, STILL GOOD TO USE -RIH WITH SAME MILL AND BOOT BASKET CONFIGURATION. TAGGED AT 212' 03:00 - 07:30 4.50 FISH N DPRB 212.00 DECOMP M FROM 212' 25' -PUW ILL 65K, SOW 65K , R 65K, PUMP RATE @ 15 BBUMIN @ 488 PSI, 80 RPM @ 2 -5 K TORQUE, WOB 5 -7K, -LOSS RATE AT 03:15 = 25 BBLS/HR - LOSSES STOPPED AT 03:30 07:30 - 08:30 1.00 FISH N DPRB 212.50 DECOMP FLOW CHECK- W STATIC PULL OUT OF HOLE , BLOW DOWN TOP DRIVE , STAND BACK DRILL COLLARS -EMPTY JUNK BASKET, PARTS OF BURNING SHOE IN BASKET - INSTALL NEW 8.5 JUNK MILL 08:30 - 09:00 0.50 FISH N DPRB 212.50 DECOMP MAKE UP DRILL COLLARS AND 4" DRILL PIPE - ESTABLISH PUMP PARAMETERS 09:00 - 12:00 3.00 FISH N DPRB 213.77 DECOMP RUN IN HO, TAG FISH @ 213.77, CONTINUE MILLING WIT 12 BPM AT 220 PSI. - WEIGHT ON BIT= 5 -13K, 80 RPM, PICK UP WEIGHT= 65K, SLACK OFF WEIGHT= 65K, ROTATE WEIGHT= 65K - MILLED TO 214.60' -AVG LOSS RATE = 40 BBUHR BETWEEN 9:00 AM AND 12:00 NOON -12 HOUR FLUID LOSSES =177 BBL Printed 11/19/2012 11:34:28AM s z Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS-41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 18:00 6.00 FISH N DPRB 219.00 DECOMP CONTINUE MILLING FROM 214.60 TO 219' - PUW= 65K, SOW= 65K, ROT= 65K ,15 BPM AT 250 PSI, RPM= 80, TORUQE= 1 -2K, WOB= 13K -AVG LOSS RATE= 16.5 BBLS/HR BETWEEN NOON AND 18:00 - HOURLY LOSS RATE -NOON *TO 13:00 =35 BBLS /HR *TO 14:00 =16 BBLS/HR *TO 15:00 =20 BBLS /HR *TO 16:00 =16 BBLS/HR *TO 17:00 =13 BBLS /HR *TO 18 :00 =5 BBLS /HR 18:00 - 19:00 1.00 FISH N DPRB 219.00 DECOMP FLOW CHECK WELL, POOH, CHECK MILL AND EMPTY JUNK BASKETS. RECOVERED .5 GAL METAL. METAL FROM I-WIRE, CAP TUBE AND HEAT TRACE. - LARGER PIECES OF METAL ARE PRESENT VERSUS PREVIOUS RUNS. -SMALL PIECES OF METAL FOUND ON LIP OF BUMPER SUB AND ON LIP OF OIL JARS -SEE ENCLOSED PICTURES OF MILL AND DEBRIS FOUND IN BASKETS - MILL INSPECTION DETERMINED MILL IN -GOOD SHAPE AND WILL BE RE -RAN 19:00 - 19:30 0.50 FISH N DPRB 219.00 DECOMP MAKE UP BHA AND RUN IN HOLE. TAGGED BOTTOM AT 219' - ESTABLISH MILLING PARAMETERS 19:30 - 00:00 4.50 FISH N DPRB DECOMP CONTINUE MILLING FROM 219' T0220' -PUW= 65K, SOW= 65K, ROT= 65K ,15 BPM AT 250 PSI, RPM= 80, TORUQE= 1 -2K, WOB= 13K -AVG LOSS RATE = 11.5 BBLS/HR - HOURLY LOSS RATE -2000 *TO 21:00 =12 BBLS/HR *TO 22:00 =13 BBLS/HR *TO 23:00 =10 BBLS/HR *TO 24:00 =11 BBLS/HR - TOTAL LOSSES FOR 12 HR TOUR -146 BBLS -TOTAL LOSSES SINCE MILLING OPERATIONS STARTED -438 BBLS 10/22/2012 00:00 - 05:30 5.50 FISH N DPRB 287.00 DECOMP CONTINUE MILLING FROM 220' TO 287' -PUW= 65K, SOW= 65K, ROT= 65K ,15 BPM AT 250 PSI, RPM= 80, TORUQE= 1 -2K, WOB= 13K - AVG LOSS RATE = 11.5 BBLS/HR - HOURLY LOSS RATE -0000 *TO 01:00 =6 BBLS/HR *TO 02:00 =19 BBLS/HR *TO 03:00 =28 BBLS/HR *TO 04:00 =20 BBLS/HR *TO 05:00 =08 BBLS/HR -ROP INCREASED FROM .2' /HR TO 70- 120' /HR AT 04:15 AM. - CLEANING 3 LBS OF METAL FROM DITCH MAGNETS EVERY 2 HRS BETWEEN MIDNIGHT AND 6 AM 05:30 - 06:30 1.00 FISH N DPRB 287.00 DECOMP POOH TO CHECK MILL AND EMPTY BOOT BASKETS, RETRIEVED ONE POUND OF METAL DEBRIS -MAKE UP BOOT BASKETS AND MILL 06:30 - 07:00 0.50 FISH N DPRB 287.00 DECOMP LUBRICATE AND SERVICE THE RIG Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 07:30 0.50 FISH N DPRB 287.00 DECOMP RUN IN HOLE WITH BHA #38. -PICK UP TWO MORE 6 -1/4" DRILL COLLAR FROM PIPE SHED 07:30 - 12:00 4.50 FISH N DPRB 299.00 DECOMP TAGGED FISH @ 216' STARTED MILLING AT 218' -12 BPM @ 190 PSI, WEIGHT ON BIT 8 -10K, PICK UP WEIGHT= 67K, SLACK OFF WEIGHT= 67K, ROTATE WEIGHT= 67K - ESTABLISH PUMP PARAMETERS AT 226'. MUD WEIGHT= 8.5 PPG -MILLED DOWN TO 299' -12 HOUR LOSSES= 120 BBLS, WITH AVERAGE LOSE RATE OF 10 BBL PER HOUR. -125 POUNDS OF METAL RECOVERED AT ROCK WASHER - HOURLY LOSS RATE -0800 * TO 09:00 =6 BBLS/HR *TO 10'00 =10 BBLS /HR *TO 11:00 =12. BBLS/HR *TO 12:00 =1 5 BBLS /HR 12:00 - 13:00 1.00 FISH N DPRB 299.00 DECOMP CONTINUE MILLING FROM 299' TO 299', PUMPING 12 BPM AT 190 PSI. -WOB= 8 -10K, PUW= 67K, SOW= 67K, RTW= 67K - HOURLY LOSS RATE -1200 *TO 13:00 =5 BBLS /HR 13:00 - 13:30 0.50 FISH N DPRB 299.00 DECOMP RACK BACK ONE STAND OF 4" DRILL PIPE, PICK UP TWO JOINTS OF 6 -1/4" DRILL COLLARS -MAKE UP DRILL COLLARS AND THE ONE STAND OF 4" DRILL PIPE. 13:30 - 14:00 0.50 FISH N DPRB 300.00 DECOMP CONTINUE MILLING FROM 299' TO 300' PUMPING 12 BPM AT 210 PSI - PUW = 72K, SOW = 70K, RTW= 72K, WOB= 18K 14:00 - 14:30 0.50 FISH N DPRB 337.00 DECOMP DEBRIS BROKE FREE AND PUSHED DOWN FROM 300' TO 337' 14:30 - 17:00 2.50 FISH N DPRB 338.00 DECOMP CONTINUE MILLING FROM 337' TO 338'. PUMPING 12 BPM AT 210 PSI. - PUW= 72K, SOW= 70K, ROT= 72K, WOB= 18K - HOURLY LOSS RATE -1500 *TO 16:00 =17 BBLS/HR *TO 17:00 =6 BBLS/HR 17:00 - 19:00 2.00 FISH N DPRB 338.00 DECOMP FLOW CHECK - STATIC, RACK BACK ONE STAND OF 4" DRILL PIPE, PICK UP A 6 -1/4" DRILL COLLAR -RACK BACK ALL THREE STANDS OF DRILL COLLARS - EMPTIED BOOT BASKET AND CHANGED OUT MILL - FUNCTION RAMS AND OBSERVED METAL DEBRIS COMING OUT OF RAM CAVITY, FLUSH STACK. -JET FLOW LINE TO FREE ANY METAL DEBRIS IN FLOW LINE. - RETRIEVED 25 POUNDS OF METAL OUT OF BOOT BASKETS. 19:00 - 19:30 0.50 FISH N DPRB 338.00 DECOMP RUN IN HOLE, TAGGED FISH AT 337' Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 00:00 4.50 FISH N DPRB 342.00 DECOMP CONTINUE MILLING TO 342', PUMP 12 BPM AT 230 PSI. - PUW= 74K, SOW= 71 K, RPM= 100, TORQUE= 1 -2K, WOB= 15 -18K -12 HOUR LOSSES= 65 BBLS. FOR A TOTAL OF 185 BBLS LOST IN 24 HOURS -TOTAL LOSSES SINCE MILLING OPERATIONS STARTED -623 BBLS -LOSS RATE RANGING FROM 14 BPH T02 BPH FOR THE PAST 24 HOURS. -TOTAL OF 154 POUNDS OF METAL RECOVERED FROM SHAKERS. -HOURLY LOSS RATE -2000 *TO 21:00 =4 BBLS /HR *TO 22:00 =6 BBLS/HR "TO 23:00 =4 BBLS/I-jR. *TO 00:00 =6 BBLS/HR 10/23/2012 00:00 - 03:30 3.50 FISH N DPRB 601.00 DECOMP CONTINUE MILLING FROM 342' TO 601' -PUW= 75K, SOW= 76K, RPM= 100, TORQUE= 1 -2K, WOB= - HOURLY LOSS RATE -0000 "TO 01:00=6 BBLS/HR "TO 02:00 =8 BBLS /HR TO 03:00 =2 BBLS/HR 03:30 - 04:00 0.50 FISH N DPRB 601.00 DECOMP BLOW DOWN TOP DRIVE AND STAND BACK 4" DRILL PIPE IN DERRICK 04:00 - 04:30 0.50 FISH N DPRB 601.00 DECOMP 10 MIN FLOWCHECK -STAND BACK DRILL COLLARS IN DERRICK, LAY DOWN BOOT BASKETS AND MILL 04:30 - 05:00 0.50 FISH N DPRB 601.00 DECOMP RIG UP AND PURGE KILL LINE. CONDUCT INJECTIVITY TEST. 4.0 BBUMIN @ 380 PSI, 4.5 BBUMIN @ 440 PSI, 5.0 BBUMIN @ 515 PSI. 1 BBL RETURNED WHEN BLOWING DOWN RETURN LINE. 05:00 - 06:00 1.00 FISH N DPRB 6,011.00 DECOMP EMPTY 2 GAL. METAL FROM BOOT BASKETS, INSPECT MILL. MAKE UP MILL AND BOOT BASKETS. WAIT ON ORDERS FROM TOWN. 06:00 - 06:30 0.50 FISH N DPRB DECOMP LUBRICATE AND SERVICE RIG 06:30 - 08:00 1.50 FISH N DPRB DECOMP LAY DOWN ALL BAKER FISHING TOOLS FROM RIG FLOOR 08:00 - 08:30 0.50 FISH N DPRB DECOMP PJSM WITH TRUCK DRIVERS, MUD ENGINEER AND RIG CREW ON BULL HEADING WELL FLUID 08:30 - 09:30 1.00 FISH N DPRB DECOMP RIG UP TO PUMP DOWN WELL BORE WITH BLIND SHEAR RAMS CLOSED. -356 BBLS PUMPED DOWN WELL BORE WITH 10 BPM, BEGAN PRESSURE AT 550 PSI, PRESSURE CLIMBED UP TO 2900 PSI. - REDUCED PUMP STOKES DOWN TO 6.5 BPM WITH PRESSURE AT 2900 PSI 09:30 - 12:00 2.50 FISH N DPRB DECOMP SHUT PUMPS DOWN, BLEED PRESSURE OFF THRU TRIP TANK. - MONITOR FLUID RETURNS - 160 POUNDS OF METAL DEBRIS RECOVERD FROM SHAKERS -LOST 19 BBLS WHILE MILLING - PUMPED 360 BBLS DOWN WELL BORE FOR INJECTIVITY TEST - 54 BBLS OF THE 360 BBLS PUMPED RETURNED THRU BLEEDING OFF WELL Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:30 1.50 FISH N DPRB DECOMP MONITORING WELL FOR RETURNS FROM INJECTIVITY TEST. - SIMOPS= CLEAN PITS FOR NEXT INJECTIVITY TEST - 13 BBLS MORE RETURNED FROM WELL. 13:30 - 15:30 2.00 FISH N DPRB DECOMP INJECT 8.5 SEA WATER AT 120 DEGREES, STAGING UP TO 10 BBLS PER MINUTE, REDUCE TO 8 BPM FOR DURATION OF TEST - MAXIMUM PRESSURE WAS 2330 PSI, TAPPERING OFF TO 1450 PSI AT THE END OF TEST. -TOTAL OF 545.4 BBLS PUMPED DURING BULLHEADING 15:30 - 00:00 8.50 FISH N DPRB DECOMP HOLD PRESSURE FOR 5 MINUTES, BLED OFF FROM 1450 PSI TO 590 PSI. - OPEN BLEEDER AND MONITOR WELL FOR RETURNS -113 BBLS MORE RETURNED FROM WELL. FOR A TOATL OF 180 BBLS RETURNED - SPILL DRILL= 2:00 MINS. 10/24/2012 00:00 - 08:00 8.00 CEMT C ABAN_ CONTINUE TO MONITOR WELL WHILE WAITING ON CEMENTERS -12 BBLS BACK FROM MIDNIGHT TO 0600 -CLEAR RIG FLOOR OF X -OVERS NOT NEEDED -CLEAN UP SPACER SPOOLS TO BE SENT TO TUBOSCOPE - GENERAL MAINTENANCE AND CLEANUP ON RIG (PAINTING) -P /U HALLIBURTON TOOLS TO RIG FLOOR FOR CEMENT RETAINER RUN 08:00 - 10:30 2.50 CEMT C. ABAN PICK UP AND MAKE UP CEMENT RETAINER -MAKE UP 6 -1/4" DRILL COLLARS WITH 2 STANDS OF 4" DRILL PIPE -RUN IN HOLE TO 479' 10:30 - 12:00 1.50 CEMT C ABAN SET CEMENT RETAINER AT 477', TURN TO THE RIGHT 35 TURNS. -PICK UP 15K, THEN TURN TO THE RIGHT 25 TURNS - PICK UP TO 15K OVER, LET SIT FOR A MINUTE, THEN PICK UP TO 25K OVER - CEMENT RETAINER SHEARED AT 50K, COME BACK DOWN SET 20K DOWN ON RETAINER. - PUMPED 10 BBLS DOWN THRU RETAINER WITH 6 BPM @ 620 PSI. - PULLED BACK OUT OF RETAINER, PUMPED 30 BBLS OF SAFE SURF -O, LET IT SOAK FOR 10 MINTUES. - PUMPED ANOTHER 30 BBLS OUT CLEANED UP AT SURFACE, SHUT DOWN PUMPS. *""CEMENT RETAINER: HALLIBURTON 9 5/8" EZSVB CEMENT RETAINER S/N 100004372 * ** 12:00 - 13:00 1.00 CEMT C ABAN TEST CEMENT RETAINER 1000 PSI FOR 10 MINUTES. 13:00 - 15:00 2.00 CEMT C ABAN RIG UP TO CEMENT 15:00 - 17:00 2.00 CEMT C ABAN PUMP 5 BBLS WATER AND PRESSURE TESTED LINES TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MINUTES. -PUMP 475 BBL OF 15.8 PPG CLASS "G" PLUG CEMENT. Printed 11/19/2012 11:34:28AM ! r a rf,T, i Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 17:30 0.50 CEMT C ABAN UNSTING FROM RETAINER AND PUMP 14 BBL L OF 15.8 CLASS "G" PLUG CEMENT -TOP OF CEMENT AT 283' "CEMENT IN PLACE AT 17:12 PM 17:30 - 18:00 0.50 CEMT C ABAN RACK BACK 6 JOINTS OF DRILL PIPE 18:00 - 19:00 1.00 CEMT C ABAN REVERSE CIRCULATE SURFACE TO - SURFACE -1.5 BBLS CEMENT BACK -CIRCULATE LONG WAY AROUND UNTIL CLEAN FLUID CAME FROM WELLBORE 19:00 - 21:00 2.00 CEMT C ABAN POOH AND LAY DOWN COLLARS, EZ DRILL MECHANICAL SETTING TOOL AND MOBILIZE OFF DRILL FLOOR 21:00 - 23:00 2.00 CEMT C ABAN RUN IN HOLE WITH 4 -3/4" DRILL COLLARS AND LAY DOWN TO PIPE SHED SINGLES. - RUN IN HOLE WITH 4" DRILL PIPE AND LAY DOWN TO PIPE SHED 3 STANDS AT A TIME.. 23:00 - 00:00 1.00 CEMT C ABAN WAIT ON CEMENT, SIMOPS= CLEAN RIG. 10/25/2012 00:00 - 11:00 11.00 CEMT C ABAN WAIT ON CEMENT TO REACH 200 PSI COMPRESSIVE STRENGTH (EST TIME @ 11:21 AM (10/25/12). -MAINTENANCE ON RIG - CLEANING, PREPWORK FOR RIG MOVE 11:00 - 12:00 1.00 CEMT C ABAN LINE UPON KILL LINE AND PURGE -SHUT BLIND SHEAR RAMS - PRESSURE UP TO 1500 PSI - SHUT IN AND MONITOR PRESSURE FOR 30 MINUTES 12:00 - 12:30 0.50 CEMT C ABAN CONTINUE TEST CEMENT PLUG 1500 PSI FOR 30 MINUTES 12:30 - 15:00 2.50 CEMT C ABAN PULL WEAR RING, RUN IN HOLE WITH DRILL PIPE TO 250' -RIG UP TO CEMENT 15:00 - 15:30 0.50 CEMT C ABAN PUMP 5 BBLS OF WATER, PRESSURE TEST LINES TO 250 PSI LOW/ 4000 PSI HIGH FOR 5 CHARTED MINUTES 15:30 - 16:00 0.50 CEMT C ABAN PUMP 21 BBLS OF ARCTIC SET 1, 15.7 CEMENT. 16:00 - 16:30 0.50 CEMT C ABAN PULL OUT OF CEMENT, CLEANING THE PIPE AND LAYING DOWN SINGLES 16:30 - 18:00 1.50 CEMT C ABAN FUNCTION RAMS AND FLUSH STACK - BLOW DOWN ALL CIRCULATION LINES, CLEAN CEMENT VALVES 18:00 - 19:30 1.50 WHSUR P ABAN RIG UP AND RUN IN HANGER -RUN IN LOCK DOWN SCREWS -SPILL DRILL= 1:45 MINUTES 19:30 - 21:00 1.50 WHSUR P ABAN TEST TWC FROM ABOVE, 250 PSI LOW/ 1000 PSI FOR 5 CHARTED MINUTES EACH - FUNCTIONED BLIND RAMS TWICE TO CLEAN OUT ANY DEBRIS 21:00 - 22:00 1.00 WHSUR P ABAN BLOW DOWN LINES AND SUCK OUT STACK. -LAY DOWN CROSS OVERS FROM RIG FLOOR -LAY DOWN DRILL PIPE IN DERRICK BY BREAKING DOWN IN MOUSEHOLE AND LAY DOWN IN PIPE SHED. 22:00 - 00:00 2.00 WHSUR P ABAN PJSM- NIPPLE DOWN BOP STACK, PULL FLOW LINE AND RISER Printed 11/19/2012 11:34:28AM Common Well Name: MPS-41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/26/2012 00:00 - 01:00 1.00 BOPSUR P ABAN PJSM - NIPPLE DOWN AND PULL BELL NIPPLE AND FLOWLINE 01:00 - 04:30 3.50 BOPSUR P ABAN INSTALL POTATO MASHER WITH 5" HWDP INTO ANNULAR -BREAK TOP OF ANNULAR 04:30 - 06:00 1.50 BOPSUR P ABAN BREAK SPACER SPOOL ON BOP STACK, BRING TO RIG FLOOR. - MAKE ADAPTER FLANGE BACK UP TO BOP STACK AND STAND BACK BOP STACK -PICK UP TREE 06:00 - 09:00 3.00 BOPSUR P ABAN TEST ADAPTOR AND PACKER TO 5000 K PSI FOR 30 MINUTES - TEST TREE TO 1000 PSI FOR 5 MINUTES 09:00 - 12:00 3.00 BOPSUR P ABAN RIG DOWN TEST EQUIPMENT, SECURE WELL -CLEAR CELLAR AREA FOR MOVING -RIG DOWN RIG FLOOR FOR SKIDDING -SKID CONVEYOR #2 IN FOR RIG MOVE 12:00 - 15:00 3.00 MOB P ABAN CONTINUE RIG DOWN FLOOR FOR SKIDDING AND SKID IN CONVEYOR #2 FOR RIG MOVE -MOVE ROCK WASHER, FUEL TANK AND LUNCH SHACK. 15:00 - 16:00 1.00 MOB P ABAN ' " BLOW DOWN RIG FLOOR AND SKID INTO MOVING POSITION 16:00 - 00:00 8.00 MOB P ABAN MOVE RIG OFF WELL AND MOVE DOWN PAD TO WORK ON BOP STACK - MOBILIZE RIG MATS INTO POSITION UNDER CORNERS OF THE RIG AND BELLY - LAY OUT HERCULITE AND POSITION RIG MATS IN CELLAR, SET RIG DOWN 10/27/2012 00:00 - 06:00 6.00 WHSUR N DPRB POST -PJSM ON SKIDDING RIG FLOOR, SKID FLOOR INTO DRILLING POSITION -HOOK UP BRIDGE CRANES TO BOP STACK -PJSM ON TAKING APART BOP STACK -MOBE RIG MATS FOR BOP SECTIONS -L /D BOP SECTIONS AND INSPECT - CHANGE OUT API RINGS 06:00 - 12:00 6.00 WHSUR N DPRB POST PJSM- INSTALL FRONT BOOSTER FRAME - REMOVE ANNULAR CAP, CLEAN OUT AND INSPECT - REPLACE PISTON SEALS -CLEAN AND INSPECT API GROOVES ON BELL NIPPLE AND ANNULAR - MOBILIZE RIG MATS AND HERCULITE FOR NEXT WELL 12:00 - 18:00 6.00 WHSUR N DPRB POST CONTINUE INSTALLING BRACES ON THE FRONT BOOSTER FRAME - REASSEMBLE BOP STACK REPLACING ALL API RINGS, TORQUE ALL BOLTS 18:00 - 00:00 6.00 DEMOB P POST INSTALL FRONT BOOSTER - BLOW DOWN RIG FLOOR, SKID RIG FLOOR TO MOVING POSITION -RIG UP AND PUT BOP STACK BACK ON PEDESTEL 10/28/2012 00:00 - 06:00 6.00 DEMOB P POST REPOSITION RIG AND SET MATS TO REMOVE BOP STACK FROM PEDESTAL. -PLACE BOP STACK IN SHIPPING CRADLE FOR TRANSPORTATION TO E -PAD - CONTINUE TO DEMOBILIZE RIG ITEMS FROM MPU S -PAD TO PBU/ WOA E -PAD -FIRE DRILL= 2:39 MINUTES Printed 11/19/2012 11:34:28AM Common Well Name: MPS -41 AFE No Event Type: WORKOVER (WO) Start Date: 9/25/2012 End Date: 10/29/2012 X9- 003JP -C: (2,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 11/7/2008 12:00:00AM Rig Release: 10/29/2012 Rig Contractor: DOYON DRILLING INC. UWI: 500292340100 Active Datum: MPS -41 @71.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 12:00 6.00 DEMOB P POST CHECK AIR PRESSURE ON RIG TIRES. -CLEAN AND ORGANIZE RIG FOR MOVE, STUFFING CRACKS ETC. -PAINT PRESSURE RELIEF TANK ON TEST PUMP -WORK ON STEAM HEATER IN PIPE SHED AND PREVENTIVE MAINTENANCE WORK ORDERS. 12:00 - 18:00 6.00 DEMOB P POST START MOBILIZING RIG MATS DOWN MPU S -PAD ACCESS ROAD. -PJSM/ REVIEW SOP ON ATTACHING REAR BOOSTER, ATTACH REAR BOOSTER -CONTINUE WORK ON PREVENTIVE MAINTENANCE WORK ORDERS 18:00 - 00:00 6.00 DEMOB P POST CONTINUE MOBILIZING RIG MATS ON MPU S -PAD ACCESS ROAD. - CONTINUE REAR BOOST INSTALL, FUNCTION TEST BOTH FRONT AND REAR. - CONTINUE WORK ON PREVENTIVE MAINTENANCE WORK ORDERS 10/29/2012 00:00 - 04:00 4.00 DEMOB P POST SPREADING RIG MATS ON S -PAD ACCESS ROAD -TROUBLESHOOTING BOOSTERS PENDANT CONTROLLERS ON FRONT OF THE RIG ** *RIG RELEASE AND SWITCH TO E -20 MOBE REPORT AT 04:00 10/29/12 * ** Printed 11/19/2012 11:34:28AM Wellhead: FMC Gen 5 11" x 4 IVI P U � 41 O ri g . KB Elev. = Radigan Wellhead w dry Hole Tree = 72' Tubing head: 11" x 4 -1/2 ", Orig. GL Elev. 38.1' FMC tbg hanger TCII w/ 4" "H" BPV [ 20" 92 lb/ft, H-40 Welded Barrier #2 -15.7 ppg Arctic Insulated 112` oesurF cement from —283' "°- ---- Top of barrier #1 - 283' 15.8 ppg Class G Daily Operation report from 11/12/2008 reported 12 bbls of cement observed at surface during ,. --� Cement Retainer at 477' the 9 -518" casing job. Also, cement The junk has been milled is visible from surface when looking Q and pushed to 601'. past the landing ring. Injectivity has been estab- lished. ' °`' 475 bbls of 15.8 ppg Class Top of fish unknown. Recovered G to fill wellbore - -1786' (43 joints). 3345' of cool- pletion in hole. . 4.5" NDPG multi drop tbg gauge I There are no DPZ's present 9 5/8" 47 #, L-80, BTC it between the Ugnu and surface Csg. drift ID = 8.525 ", Csg. ID = 8.681" ° rt Burst = 6870 psi 7" x 9 -5/8" C -2 ZXP 1 3968` Collapse =4750 psi X Liner Top Pkr. _ ' 4.5" SLB DCIN Chem Inj Mandrel I I 9 -5/8" Casing Shoe 1 4140' .l V 4.5" WFD Pump Seating Nipple I 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg 4.5" WFD Drain Sub/ 3996 psi shear I (Drift ID 3.833" - Capacity = .0152 bpf) • XO 4 -1/2" HYD x 3 -1/2" IBT 3.5" 9.3 ppf, L -80, IBT -Mod Tbg I 11 I (Drift ID 2.867" - Capacity = .0087 bpf) i; u.i � 3.5" NDPG multi drop Annular gauge I ` I 3.5" NDPG multi drop tbg gauge MM 7" 26 #, L -80, BTC -M Casing —)::>. I I Csg. ID = 6.276" Csg drift ID = 6.151" WFD PCP Stator XXXL 327 6000 Burst = 7240 psi Collapse = 5410 psi `•" 3.5" NDPG single drop tbg gauge I I 3.5" WLEG I I Top of MPS -41 7" Casing Stub @ 4275' MD I I 7" 29# slotted liner from MPS -41 P &A'd I I 4800' - 4880' 7" L -80 Casing 5250' - 6250' TD: 5077' 6800' - 7600' 8 -1/2" Hole 7" 26# solid liner 4000' - 4800' i 4880' - 5250' I I 6250` - 6800' I MPS -41 Open Hole Sidetrack � 1 7" Liner Shoe © 7605' MD Well Inclination @ shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS -41 Pilot hole & Horizontal Sidetrack WELL #: MPS -41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50- 029 - 23401 -01 -00 8/10/2012 Doyon 14 Attempt to de- complete - Install Kill String. BP EXPLORATION (AK) • � \�//. / s THE STATE Alaska Oil and Gas S °f ALA� Conservation Commission c GOVERNOR SEAN PARNELL F 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: Main: 907.279.1433 Fax: 907.276.7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Q.os' .. Anchorage, AK 99519 -6612 Re: Milne Point Field, Ugnu Undefined Pool, MPS -41A Sundry Number: 312 -411 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. ncer - . , J. w K. Norm- L o ,- ' sioner DATED this 1' da of October, 2012. Encl. STATE OF ALASKA .. Myk~ • ALASKA OIL AND GAS CONSERVATION COMMISSION CL,' .6 "- ' APPLICATION FOR SUNDRY APPROVAL , . \,' '' , a; `;: ' s 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program E-4 Suspend • ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension Operations Shutdown 0 Re -Enter Suspended Well 0 Stimulate 0 Alter Casing Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. '® Development ❑ Exploratory 208 - 161 ' 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 23401 - 01 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS -41A ' Spacing Exception Required? ❑ Yes is No 9. Property Designation: 10. Field / Pool(s): ADL 380109 & 380110 ' Milne Point / Ugnu Undefined ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7605' ' 3807' , 7605' 3807' None Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' Surface 4140' 9 -5/8" 4140' 3477' 6870 4760 Intermediate Production Liner 3637' 7" 3968' - 7605' 3385' - 3807' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner: 4800' - 7600' 3738' - 3807' 4 - 1/2" x 3 - 1/2 ", 12.6# x 9.2# L - 80 Unknown Packers and SSSV Type: None Packers and SSSV None MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: • ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for - 15. Well Status after proposed work: Commencing Operations: October 23, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ro ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: (a 5.�,.r6� 0 WAG ❑ SPLUG Suspended (c..J� fa s4,' 17. I hereby certify that the foregoing is true &nd correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Name avid Reem Title Engineering Team Leader j Prepared By Name /Number: Signature ( Phone 564 -5743 Date /piZz/12012 Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness `�' i Sundry Number: f VIPlug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: isio 4 1;5, e' r 4c f hdl cc -,,Q , Subsequent Form Required: /v Y - a / , APPROVED BY 10 �6�,. ,/ Approved By: C ISSIONER THE COMMISSION Date v } Form 10 -403 Revised 01/2010 f OCT 707 ubmit In Duplicate 3 0 . 4„.,7.,z_c) R 1 by MPS -41A Rig Workover Well Objective: P&A well MPS -41A Justification: Well MPS -41A was drilled as part of a pilot project to test the viability of the Ugnu. The CHOPs completion consisted of a 4 -1/2" completion with corod inside to turn the PCP. On the exterior of the 4- 1/2" completion was heat trace, capillary tube, and i -wire that was secured to the tube body with cross connection clamps, bands, and flat guards. The 4 -1/2" tubing had developed a hole due to the rotating corod. The corod was removed from the wellbore as part of the pre -rig work. During the decomplete the exterior cables parted leaving a significant amount of junk in the hole. The rig has been stuck multiple times while attempting to clean the wellbore. Most recently, 8 -1/8" wash pipe was stuck across the wellhead and the well plugged below. The junk has been milled out of the wellhead and circulation has been reestablished. A significant amount of junk remains in the wellbore which can't be recovered without a significant risk to sticking pipe. As such, there are no future plans for this wellbore. BP requests approval to P&A MPS -41A. As part of the P&A a cement retainer will be set at -300' and -475 bbls of cement will be down squeezed to fill the entire wellbore. There is a risk that the well will plug off during the large cement job due to the debris left in hole. BP requests permission to proceed with the P&A if the wellbore locks up prior to pumping the planned volume of cement. After the down squeeze, 150' of cement (11 bbls) will be placed on top of the cement retainer then pressure tested to 1500 psi. Finally, a 150' cement plug (11 bbls) will be pumped to surface. MASP: 1,495 psi Well Type: Ugnu - CHOPs test well Pad Engineer: Jim Young 564 -5754 Intervention Engineer: Sean McLaughlin 564 -4387 MPS -41A Permanent Abandonment Reference Documents: • GP 10 -60 - Zonal isolation (Section 7 - Permanent Abandonment) • AOGCC 20 AAC 25.112 - Well Plugging Requirements Verify Start Checklist: ❑ BP Alaska has verbal approval from the commission to proceed with abandonment operations on MPS -41A. ❑ A Sundry request for P&A has been filed with the state. ❑ Primary and secondary well barriers shall be installed in the wellbore prior to abandonment of a well. Issues and Potential Hazards: • Junk in the wellbore below the cement retainer may plug off while pumping cement. ➢ If the well plugs while down squeezing cement there will be no attempt to reestablish circulation. The AOGCC requirements will be met by attempting the down squeeze. • Next BOPE test due 10/27/12 P&A Plan: 1. Preform an injectivity test. Pump 290 bbl of seawater in the well at maximum rate while limiting pressure to 3000 psi. 2. PU a 9 -5/8" HES Cast Iron Mechanical Set Cement Retainer and run in on 4" drill pipe. 3. Set the Retainer at -300' per HES instructions. • ➢ Target set depth is 20' above the junk. ➢ The shear release on the retainer is 30klbs. ➢ Document the following barrier information in Openwells • Manufacture, type, and model number • Tool configuration • Serial number 4. The WSL needs to verify the SLB field test blend has the following parameters before pumping cement: ➢ Fluid Loss: <250mL ➢ Free Fluid: trace or OmL ➢ Thickening Time: 3:30 - 6 hrs at 80 degF ➢ 1,000 -psi compressive strength: 15hrs max 5. RU Schlumberger cementers. PT cement lines to 4,000psi. Pump 475 bbls 15.8ppg Class G cement at -6bpm. Maximum pump pressure will be 3000 psi. Cement volume = Total wellbore volume below the retainer + 11 bbls above the retainer. ➢ The depth of the tubing stub is unknown. 6. Cement as follows: ➢ 5 -bbls seawater to PT ➢ 475 -bbls 15.8 -ppg Class "G" plug cement ➢ Displace with seawater ➢ Utilize the rig pumps for displacement ➢ Pump cement below the retainer, unsting from the retainer and pump 11 bbls of cement above. ➢ Record cement -in -place time in openwells. 7. LD 6 joints and reverse bottoms up through the headpin. This will keep cement from going across the stack. Pull out of hole standing back drill pipe. 8. Wait on cement to reach 200 psi compressive strength. Close blind /shear rams. Test lower barrier to 1,500 psi for 30 charted minutes. Verify pressure test with the WTL before proceeding. Notify the state inspector for witness of bottom plug test. ➢ Use the "BPXA STP Wellbore Testing Criteria Calcu ator ". The latest version is embedded in the Tubular Pressure Testing RP. o WSL and Toolpusher to sign. Attach pressure chart and calculator to OpenWells. 9. Verify no wellbore pressure and open B/S rams. 10. Run 4" DP to -150'. 11. The WSL needs to verify the SLB field test blend has the following parameters before pumping cement: ➢ Fluid Loss: <250mL ➢ Free Fluid: trace or OmL ➢ Thickening Time: 3:30 - 6 hrs at 80 degF ➢ 1,000 -psi compressive strength: 15hrs max 12. RU Schlumberger cementers. PT cement lines to 4,000psi. Pump 11 bbls of Arctic Set cement at -3bpm. Maximum pump pressure will be 3000 psi. Cement volume = 11 bbls above the retainer to surface. 13. Cement as follows: ➢ 5 -bbls seawater to PT ➢ 11 -bbls Arctic Set cement ➢ Record cement -in -place time in openwells. 14. Pull out of hole laying down drill pipe. 15. Set TWC and test from below to 250 psi low / 1000 psi high for 30 -min. 16. ND BOPE and NU adapter flange and dry hole tree. 17. Pressure test tubing head adapter and tree with diesel to 250 psi low / 5,000 psi high for 5 minutes. 18. RDMO Wellhead: FMC Gen 5 11o O r 5M M P U S � 41 A Radigan Wdllhead w dry Hole Tree e Orig. KB Elev. = 72' ^ ' Tubing head: 11 "x4 -1/2 ", Orig. GL Elev. = 38.1' FMC tbg hanger TCII w/ 4" "H" BPV 20" 92 lb/ft, H -40 Welded 1. Set 9 -5/8" cmt retainer —300' Insulated 1 112 2. Pump —475 bbl of 15.8 ppg cmt 3. Unstab and lay in 150' ofArcticSet cmt 4. PT cmt plug 5. Lay in —150' of cmt to surface Daily Operation report from 11/12/2008 reported 12 bbls of cement observed at surface during the 9 -5/8" casing job. Also, cement is visible from surface when looking Q The junk has been milled past the landing ring. and pushed to 288'. Par - tial infectivity has been established. Top of fish unknown. Recovered - -1786' (43 joints). 3345' of com- pletion in hole. 4.5" NDPG multi drop tbg gauge i There are no DPZ's present 9 5/8" 47 #, L -80, BTC between the Ugnu and surface Csg. drift ID = 8.525 ", Csg. ID = 8.681" Burst = 6870 psi \ / 7" x 9 -5/8" C -2 ZXP 3968' Collapse =4750 psi �/ \ X Liner Top Pkr. • / ' 4.5" SLB DCIN Chem Inj Mandrel 9 -5/8" Casing Shoe 4140' 4.5" WFD Pump Seating Nipple I I 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg 4.5" WFD Drain Sub/ 3996 psi shear I I (Drift ID 3.833" - Capacity = .0152 bpf) XO 4 -1/2" HYD x 3 -1/2" IBT 3.5" 9.3 ppf, L -80, IBT -Mod Tbg 1 1 (Drift ID 2.867" - Capacity = .0087 bpf) 1 I 3.5" NDPG multi drop Annular gauge i 1 3.5" NDPG multi drop tbg gauge 1 1 7" 26 #, L -80, BTC -M Casing - -)>- Csg. ID = 6.276" Csg drift ID = 6.151' WFD PCP Stator XXXL 327 -6000 1 Burst = 7240 psi Collapse = 5410 psi 3.5" NDPG single drop tbg gauge I 3.5" WLEG I I Top of MPS -41 7" Casing Stub @ 4275' MD 7" 29# slotted liner from MPS -41 P &A'd 4800' - 4880' 7" L -80 Casing 5250' - 6250' ' TD: 5077' 6800' - 7600' 8 -1/2" Hole 7" 26# solid liner 4000' - 4800' i 4880' - 5250' i i 6250' - 6800' MPS -41 Open Hole Sidetrack i 7" Liner Shoe @ 7605' MD c Well Inclination @ shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole - DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS -41 Pilot hole & Horizontal Sidetrack WELL #: MPS -41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50- 029 - 23401 -01 -00 8/10/2012 Doyon 14 Attempt to de- complete - Install Kill String. BP EXPLORATION (AK) Page 1 of 3 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, October 23, 2012 3:47 PM To: ' Lastufka, Joseph N'; McLaughlin, Sean M • Subject: RE: MPS-41 P&A PTD 208 -161 Joe /Sean, You have verbal approval to proceed with P &A as outlined in your application. The Sundry number is 312 -411. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Lastufka, Joseph N [mailto:Joseph.Lastufka @bp.com] Sent: Tuesday, October 23, 2012 3:37 PM To: Schwartz, Guy L (DOA); McLaughlin, Sean M Subject: RE: MPS-41 P&A Guy, Could we please get a verbal OK to proceed with the sundry work? It should be there now, and it would be great if we could have permission to proceed and get a sundry number ASAP. Please let me know if you have any questions. Thanks! Joe Lastufka From: Schwartz, Guy L (DOA) [maifto:guy.schwariz @alaska. ov 9 ] Sent: Monday, October 22, 2012 4:39 PM To: McLaughlin, Sean M Cc: Lastufka, Joseph N Subject: RE: MPS-41 P&A Sean, If you start the cementing with decent injectivity (hopefully the SW injection test will be good) the Commission will accept the P & A if it happens to lock up prematurely. Assuming you can put 1/3 (approx 150 bbl) or so of the cement away before lockup would be acceptable.... It is hard to say what will happen though. The Commission will not likely require a CO of the cement and retainer. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Monday, October 22, 2012 3:15 PM 10/23/2012 Page 2 of 3 • To Schwartz, Guy L (DOA) Cc: Lastufka, Joseph N Subject: RE: MPS -41 P&A Here is a draft of what we are considering for the P &A. Basically a large plug ( - 475 bbls) below the retainer, then 150' plug above the retainer, PT to 1500 psi, then cap with another 150' plug. We are concerned with the possibility of plugging off while pumping the large cement job. What will the State require if this happens? Will BP need to attempt a risky cleanout or would we be able to proceed with the P &A even if we are not able to pump the planned 475 bbis? sean From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, October 22, 2012 9:57 AM To: McLaughlin, Sean M Subject: RE: MPS-41 P&A That sounds reasonable. Glad you are still making some progress although slowly. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughtin @bp.com] Sent: Monday, October 22, 2012 9:55 AM To: Schwartz, Guy L (DOA) Subject: RE: MPS-41 P&A Guy, We are in a little better situation on MPS -41 than we have been over the last two weeks. Shortly after I sent the note below to you on the 10 we lost injectivity. We have spent the last 11 days clearing the fish from the wellhead and milling down to 288'. At this time we have established partial injectivity. The plan forward is to continue milling and pushing the junk down hole until full injectivity can be restored. At that time we'd like to P &A the wellbore. Our intention is to not try to engage the 4 -1/2" tubing string as we have shown (over the last 3 weeks) that there is a high risk of stuck pipe due to the cables, bands, flat guards, and clamps. We'd like to set a cement retainer as deep as possible and fill the well with cement (400 bbls) then unstab and bring the cement up to surface. Once we get a little more comfortable with the injectivity we will send a Sundry request to the State. Regards, sean From: McLaughlin, Sean M Sent: Wednesday, October 10, 2012 2:05 PM To: Schwartz, Guy L (DOA) (guy.schwartz @alaska.gov) Subject: MPS-41 P&A Guy, 10/23/2012 Page 3 of 3 I'd like to discuss what a P &A could look like on MPS -41. The rig has been either fishing or stuck for the last two weeks and more fishing on a prior rig up. There has been non - shearable equipment across the BOPE since Friday. Just this morning we were able to back off a 8 -1/8" wash pipe connection so we have the ability to close the Blind /Shear rams. After we backed off we could then drift and found the top of the junk at 13.7' below the landing ring. We still have 8 -1/8" wash pipe stuck across the wellhead and are concerned that attempting to clean out this junk (heat trace, control line, capillary tube, flat guards, clamps, and bands) further will result in a similar stuck pipe situation with BHA across the BOPE and wellhead. Fortunately at this time we still have the ability to bullhead fluid. Another concern is that with more milling and grinding we may lose the ability to inject into this well. We would like to discuss filling the well with cement top to bottom. There is not an intermediate string of pipe and there are no distinct permeable zones between the Ugnu and surface. The volume from surface to the top of the slotted liner is 322 bbls. Unfortunately, I do not know where the top of the 4 -1/2" completion is and where the cement will go (in, around, or both). I do have record that 12 bbls of cement were observed at surface during the 9 -5/8" casing job. If we were to pump a continuous cement plug from top to bottom would this meet the State's criteria for permanent abandonment isolation? Regards, sear Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 Cell 10/23/2012 Wellhead: FMC Gen 5 11" x 4 1/16" 5M dry Radl 9 an Wellhead w d Hole Tree MPU S-41A P &A Orig. KB Elev. = 72' Tubing head: 11 "x 4 -1/2 ", Orig. GL Elev. = 38.1' FMC tbg hanger TCII w/ 4" "H" BPV 1. Set 9 -5/8" cmt retainer -300' 20" 92 lb/ft, H -40 Welded 1 112' 2. Pump -475 bbl of 15.8 ppg cmt Insulated 3. Unstab and lay in 150' ofArcticSet cmt 4. PT cmt plug 5. Lay in -150' of cmt to surface Daily Operation report from 11/12/2008 reported 12 bbls of cement observed at surface during the 9 -5/8" casing job. Also, cement is visible from surface when looking Q The junk has been milled past the landing ring. and pushed to 288'. Par - tial injectivity has been established. Top of fish unknown. Recovered -1786' (43 joints). 3345' of com- pletion in hole. III 4.5" NDPG multi drop tbg gauge dia5 t€1,0 There are no DPZ's present • 9 5/8" 47 #, L -80, BTC .6'51° ' between the Ugnu and surface Csg. drift ID = 8.525 ", Csg. ID = 8.681" >- Burst = 6870 psi 7" x 9 -5/8" C -2 ZXP 1 3968` I • Collapse =4750 psi - Liner Top Pkr. AIX • 4.5" SLB DCIN Chem Inj Mandrel 9 -5/8" Casing Shoe 1 4140 4.5" WFD Pump Seating Nipple I 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg 4.5" WFD Drain Sub/ 3996 psi shear I (Drift ID 3.833" - Capacity = .0152 bpf) III XO 4 -1/2" HYD x 3 -1/2" IBT I I 3.5" 9.3 ppf, L -80, IBT -Mod Tbg f ■ i (Drift ID 2.867" - Capacity = .0087 bpf) sm.] I 3.5" NDPG multi drop Annular gauge 1 •1 ■ 3.5" NDPG multi drop tbg gauge 7" 26 #, L -80, BTC -M Casing 1 Csg. ID = 6.276" Csg drift ID = 6.151" -� WFD PCP Stator XXXL 327 -6000 Burst = 7240 psi Collapse = 5410 psi 1 .•_.1. 3.5" NDPG single drop tbg gauge Illi 3.5" WLEG I Top of MPS -41 7" Casing i Stub @ 4275' MD i ;l D MPS-41 P &A'd i 3' 7" 29# slotted liner from 1F 1 064' ' 4800' - 4880' 7" L -80 C asin g I 52 5 0 ' - 6250' TD : 507` 6800' - 7600' 8 -1/2" Hole 7" 26# solid liner 4000' - 4800' i 4880' - 5250' i i 6250' - 6800' MPS -41 Open Hole Sidetrack i 7" Liner Shoe @ 7605' MD J Well Inclination @ shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS-41 Pilot hole & Horizontal Sidetrack WELL #: MPS -41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50- 029 - 23401 -01 -00 8/10/2012 Doyon 14 Attempt to de- complete - Install Kill String. BP EXPLORATION (AK) Page 1 of 1 • Schwartz, Guy L (DOA) From: McLaughlin, Sean M [Sean.McLaughlin @bp.com] Sent: Wednesday, October 10, 2012 2:05 PM To: Schwartz, Guy L (DOA) Subject: MPS-41 P&A Attachments: MPS -41A 10 -10 -12 pre P&A.pdf Guy, I'd like to discuss what a P &A could look like on MPS -41. The rig has been either fishing or stuck for the last two weeks and more fishing on a prior rig up. There has been non- shearable equipment across the BOPE since Friday. Just this morning we were able to back off a 8 -1/8" wash pipe connection so we have the ability to close the Blind /Shear rams. After we backed off we could then drift and found the top of the junk at 13.7' below the landing ring. We still have 8 -1/8" wash pipe stuck across the wellhead and are concerned that attempting to clean out this junk (heat trace, control line, capillary tube, flat guards, clamps, and bands) further will result in a similar stuck pipe situation with BHA across the BOPE and wellhead. Fortunately at this time we still have the ability to bullhead fluid. Another concern is that with more milling and grinding we may lose the ability to inject into this well. We would like to discuss filling the well with cement top to bottom. There is not an intermediate string of pipe and there are no distinct permeable zones between the Ugnu and surface. The volume from surface to the top of the slotted liner is 322 bbls. Unfortunately, I do not know where the top of the 4 -1/2" completion is and where the cement will go (in, around, or both). I do have record that 12 bbls of cement were observed at surface during the 9 -5/8" casing job. If we were to pump a continuous cement plug from top to bottom would this meet the State's criteria for permanent abandonment isolation? Regards, sean Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 Cell 10/10/2012 Wellhead: FMC Gen 5 11" x 4' 5M Radigan Wellhead w dry Hole M P U S-41 A • Orig. KB Elev. = 72' Tubing head: 11" x 4 -1/2 ", Orig. GL Elev. = 38.1' FMC tbg hanger TCII w/ 4" "H" BPV j '.41111611111.111wpi Top of junk tagged at 13.7' below the landing ring. Junk = wad of heat trace, 20" 92 lb/ft, H-40 Welded ( 112' 1 control line, capillary tube, Insulated bands, clamps, and flat guards. Daily Operation report from 11/12/2008 reported 12 bbls of cement observed at surface during Top of fish unknown. Recovered the 9 -5/8" casing job. - -1786' (43 joints). 3345' of com- pletion in hole. 4.5" NDPG multi drop tbg gauge 1 I 9 5/8" 47 #, L -80, BTC Csg. drift ID = 8.525 ", Csg. ID = 8.681" --)7 Burst = 6870 psi There are no DPZ's present Collapse =4750 psi between the Ugnu and surface 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg (Drift ID 3.833" - Capacity = .0152 bpf) 3.5" 9.3 ppf, L -80, IBT -Mod Tbg \ / 7" x 9 -5/8" C -2 ZXP 3968' I (Drift ID 2.867" Capacity = .0087 bpf) X X Liner Top Pkr. \' 4.5" SLB DCIN Chem Inj Mandrel I 9 -5/8" Casing Shoe 1 4140' 1 4.5" WFD Pump Seating Nipple 7" 26#, L -80, BTC -M Casing �—>"" 1 Csg. ID = 6.276" Csg drift ID = 6.151" 4.5" WFD Drain Sub/ 3996 psi shear Burst = 7240 psi Collapse = 5410 psi XO 4 -1/2" HYD x 3 -1/2" IBT I 11 : 3.5" NDPG multi drop Annular gauge 1 1 3.5" NDPG multi drop tbg gauge WFD PCP Stator XXXL 327 -6000 I 3.5" NDPG single drop tbg gauge I 3.5" WLEG Top of MPS -41 r Casing i Stub @ 4275' MD 1 1 7" 29# slotted liner from MPS -41 P&A'd 4800' - 4880' 7" L -80 Casing 5250' - 6250' TD: 5077' 6800' - 7600' 8 -1/2" Hole 7" 26# solid liner 4000' - 4800' 4880' - 5250' i i 6250' - 6800' 1 7" Liner Shoe @ 7605' MD MPS-41 Open Hole Sidetrack Well Inclination © shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS-41 Pilot hole & Horizontal Sidetrack WELL #: MPS -41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50- 029 - 23401 -01 -00 8/10/2012 Doyon 14 Attempt to de- complete - Install Kill String. BP EXPLORATION (AK) ' DOYON 14 0 TODAYS DATE: / , RIG FLOOR WELL #: ./V1 -41t A z.zi ..... j 1 • • • • LINE NIPPLE _ I 15.8' I LI'l 4Z ()I 1 Annular L ( 1 19.7 I rcl 1 ) , A k , :1- 1 1 ■ I I : Ii■Im All VBR's Illrilli I_ 113q " 3-1/2" x 6" I 21.5' illIMI V\ ' 1 III i 1 nhear I I 111 7.11 Rams Blind S I 1- MINI RIC ,.....- I i Mud . I 26.02' I , --, Cross a , I MGR Kill Manual Manual HCR ZS Al Kill Ctinam Choke .^. I - I --- . , 1 :I'D VBR's 1411: 3 — 6 , 2-7/8" x 5* In II .--. ,- 1 ULDS 31.1 7 --,:. A *MI . 1 LLDS I 1 33.33' -_-1 1 011 I I (CO) I A , 4 < - ill. 1 (co 1 .._ 33.65' FIGround Level' —.- - .-.. -r. r. wary mar 13 / __ z/038 i . . ._ ll L _.,/,.., „_.,...„ 1 '' .'.1.1.(,....3r • • • CLAMP RAMS y OMPOSITE P P L U O MP BT IN TREE III 111 4 I S 16-5K SCOT TOP X POLISHED ROD RAMS , ' W/ DUAL RAM DESIGN i 1 jl i i 1 O '1v 9 0.: I� 33.47 r \ :_� � i B50.13 i !I O ti I T - O r i 0 0 1 3 1 /8 -5K i 1 -3 I/8 -56 1 _ 23.75 I1.:ik 1 _ i 1 CLASS *I -A HEAT TRACE CONNECTION \ I I RE -II -SK ROT G 11.88 11 i ii f ---- Till i +_ - 1 1-- f — = m�eeml ® �ememe•= 96.85 19 I_ 2459.97 06 357 BO - \' t, I FM 11 .16 OD ' - Mil 4,04 r A•• , i 1 J 1, i : -� « 10 LOCKDOWN SCREWS = =�_ =°I II �c < i Via= BLANKED SCSSV EXITS ' 7, - , 0 I fRX -54) 2 1/16 -5K- 1 I 1 'B, O MI 20 GV ACTT ' 2 I/16 -5K M120 GV ACT'D I 11 • O � ' i 1 1 I P. O C ' Li 1 III 26.41 t ■ ■ J o J 9 ■ I 1 ''4 €) J _ 6 70.89 T - M- s "�'i ' � � I 1 ' a l / 6 ■ `.J ! 1 i • I '. r ■. I ■ li 13.28 i I I / ® 337,1 I 1 .16 I 1 TEST PORT 4.06 .__ 'i' i i I - . GROUND LEVEL 721 �` = ®, I 1 ` ® = == - 10 TOCKDOWN SCREWS 4 '., 1j i i k_i RH - 11 -5K IR -541 i ; ^ 2 1/16 -5K M120 GV I I - H IIs ' — I ; 0* ioi 232.41 1 0i I - 5,94 1 1 - © 3.26 ■ I 82.93 152.22 1 I ' ' 1111 i 1 o 1 [ITEMII PART NUMBER II DESCRIPTION I 1 I 13- 300 -030 DIVERTER LANDING RING 1 1 2 P138322 -0005 9 5/8 CASING HANGER I.". �y 1 1 4 P164819 CASING HEAD ASSY I I �l I I 5 13- 300 -718 GEN 5 TUBING HEAD ASSY - 6 12- 150 -016 7'PACKOFF ASSY 7 P155735 11 X 7 CSG MANDREL HANGER 1 ii 8 01000063427 TUBING HANGER ASSY. TC -R -EC. II X 4 1/2 II 9 (P1000051099I COMPOSITE PUMPING TREE 1 10 12- 093 -174 9 5/8 C -21 CASING HANGER ii II P118334 -0005 BELL NIPPLE 11 II 13 SP- NRM587201- 101 - % %X CLASS *I-A SURFACE PIGTAIL II 19 • SP- HBM5B7102 ASSY CPLG FMC ELECTRO SUB, CLASS 'IA -CI 11 15 LO2XXX -KIT CLASS 'I-4 SOB SURFACE PIGTAIL I 1 -' IA P172511 ATTACHMENT ASSY I 20' OD CASING ii ii li j i - 9 5 /8' OD CASING Ii 1 i I 1 '.------- OD CASING 1 ii I II I 1 9 1/2' OD TUBING 878 3.232 -- 4,110/ ((�7Cap��IL��C�n�O�L�O I �ORIL PROJECT L,108V LS INQ fl OOUV WCLLaCQD OMI00049826 REV D DU100080634 OM100071604 P RIVATE AND CONFIDENTIAL Nyvisxxis OESCII1PT 10X '•��^k` BP COLD OIL PROJECT ® „«„ -00 -0 GENERATION 5 WELLHEAD -11 Ad�■bnn "`"°'�® 20 X 9 5/8 X 7 X 4 1/2 ® _ I I - 5K COMPLETION n HAMILTON � 11 - 11 - ON r ,,, .�i, ..27-.77.rL.� -- W/ HEAT TRACE COMPLETION rtxu ,,„ 11-11-OV DM10004 982 6 -A • • DOYON 14" TODAYS DATE: WELL # : RIG FLOOR BELL i "FLOW LINE NIPPLE I 18 I • q P Annular , 11111111.111 i ll VBR's 111141111; 3 -1/2" x 6" � , INN ;'1111i 71; I 21.5' .ELI RJR= j -, _ Blind Shear , , Rams 7f. I- I I Mud • I 26.02' Cross L HCR Kill Manual Manual HCR Kill Choke Choke I I -' MI: VBR's ■ = 2 -7/8" x 5" aJIG ( m 71= I I r ULDS 31.1' 4 1 LLDS ii i�...f 1 33.33' iteenr - 1 I I A I 33.65' FIGround Level ........ .,, ii 1 • • Wes kV BAKER Bottom Hole Assembly Y SWIM Baker Oil Tools J Date: 10/6/2012 ��, Trip #: 17 Company: BPXA Well #: MPS -41A Field: Milne Point Lease: MPS Pad Working Depth Out: Working Depth In Formation Type: 95/8 csg Traveling Weight U1 Traveling Weight Down Rotating Weight: Weight on Bit: Rotary Speed: Free Torque: Drilling Torque: Circulation Rate: Stand Pipe Pressure: Tool Orifice Cut Out Time Drilling/MBI Time: Mud Weight: Mud Viscosity: Mud Yield Point: Initials/Signature Required Serial No. Description Top Bottom Fishing OD ID Length Cumulative Conn. Conn Neck Total Installed in String 10122150 81/2 x 6 7/8 FB SHOE TSWP 8 1/8 2.17 8 1/2 6 7/8 2.60 2.6 10141277 81/8 WASH PIPE EXT TSWP TSWP ALL 8118 7 1/4 7.15 9.75 10319293 8 118 WASHPIPE EXT TSWP TSWP ALL 81/8 7 5.54 15.29 10319295 81/8 WASHPIPE EXT TSWP TSWP ALL 8 1/8 7 5.55 20.84 AF01841 81/8 WASHOVER BOOT BASKET 41/2 IF TSWP 6 1/4 V 81/8 3 4.71 25.55 9302040 6 114 OIL JAR 41/2 IF 4112 IF 61/41.64 6 1/4 2 1/4 11.55 37.1 RIG XO 4 1/2 H -90 BOX X 41/2 IF PIN H -90 41/2 I ALL 6 112 1 13/16 1.38 38.48 DOYON 6" PUP JT. 41/2 IF 41/2 IF 1.26X6 3/8 5" 3 3/4 9.96 48.44 9204034 SURFACE JARS 4 1/2 IF 4 1/2 IF 88 7" 7" 1 7/8 8.70 57.14 45 -5110 5" PUP JT. 41/2 IF 41/2 IF _ 1.26X6 3/8 61/2 3 3/4 _ 14.83 71.97 DOYON X -O SUB 4" XT 4 1/2 IF 1.62 51/16 6 3/8 2 1/2 2.33 74.3 1 i _ . L ,_ - T otal BHA I 74.3 1 LA,r(6,C e_ ; as "5 c' NO IttAnty ,r JOSI a&C\ haV L 64..A. t u\ c�owk. 5A- 1-„,...,1 .‘ 1 a S�Vo �,, K> , `1 ZF 7.5.1- 1F3Rev. 0 k, S-4(4 • P ?0 Regg, James B (DOA) From: Burnett, Richard D [burnr8 @BP.com] Sent: Thursday, August 02, 2012 10:11 AM Z��l ri 7 To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Daniel, Ryan; Kilfoyle, Jeffery A; Allen, Kenneth W; Egbejimba, Uchenna J; McMullen, John C; Reem, David C; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); Willingham, James M; Sarber, Greg J; Yeager, Kevin E; Anderson, Brett; McLaughlin, Sean M Subject: BOPE Usage Report for MPS -41A Attachments: BOPE Usage Report for MPS -41A 8- 1- 2012.doc Jim, Attached please find the BOPE usage form for well MPS -41A. Please let me know if I can answer any questions or if you need any further clarification. Thanks, Rich SCANNED MAY 0 7 2013 Rich Burnett Operations Superintendent RWO /CTD +1 (907) 659 -5329 (Office - slope) +1 (907) 748 -5821 (Cell Phone) Harmony 2157 Alternate: Greg Sarber 1 • • s't v Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC is to ensure timely reporting The purpose of this document y p g to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Richard Burnett Wellsite Leader Name: Brett Anderson Contact Number: 907.659.5329 Contact Number: 907.659.4718 Traction Number: 2012 -IR- 4196298 Well Location /Name & Rig Name: Milne Point S -41A / Doyon 14 Permit To Drill (PTD) Number: 208 -161 - Date and Time of Incident: 08/01/2012 @ 11:35 Original Scope of Work: Pull and re -run new CHOPS completion using Polycore lined tubing. Operational Description Leading up to Well Control Event: Fishing Operations — Washing over a tubing stub at 1416' driller; fisherman thought they were over stub. Picked up to do a routine flow check prior to pulling out of the hole and flow was observed at the flow line. BOPE Used and Reason: Annular was used to shut in the well per BP procedure. Is a BOPE Test Required after use ( Yes / No): Yes If no, why? 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: After verifying 0 psi and no flow from the well, continue with operations to suspend well. - Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa .aogcc.prudhoe.bay(c�alaska.gov Email CC List Well Integrity Team Leader: Ryan Daniel HSE Advisor: Jeff Kilfoyle Engineering Team Leader: Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager: Steve Rossberg Wells Intervention Manager: Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC Rev 1 September 1, 2010 • • Fl 7 FE EF 'C.t L r 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 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. - / (� 1 P.O. Box 196612 ao' Anchorage, AK 99519 -6612 Re: Milne Point Field, Ugnu Undefined Oil Pool, MPS -41A Sundry Number: 312 -298 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P 92e4.\ Cathy . Foerster G� Chair ?i DATED this day of August, 2012. Encl. ALA OIL AND GAS CONSERVATION CO SSION EQE APPLICATION FOR SUNDRY APPROVAL lki l 2012 20 AAC 25.280 1. Type of Request: AO CC ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ® Change Approved ProgramnW b 5/1 ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ►�� Development' ❑ Exploratory 208 - 161 • 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 23401 - 01 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS -41A • Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 380109 & 380110 Milne Point Unit / Ugnu Ciica .cr Ci 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7605' • 3807' • 7605' 3807' None 1416' Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' Surface 4140' 9 -5/8" 4140' 3477' 6870 4760 Intermediate Production Liner 3637' 7" 3968' - 7605' 3385' - 3807' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner: 4800' - 7600' 3738' - 3807' 4 - 1/2" x 3 - 1/2 ", 12.6# x 9.2# L - 80 1416' - 5939' Packers and SSSV Type: None Packers and SSSV None MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 1, 2012 ® Oil • ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Name David Reem Title Engineering Team Leader Prepared By Name /Number: Signature C Phone 564 Date g /lj/Z Joe Lastufka, 564-4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness r: 3 i 2 -2 Sundry Numbe ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Subsequent Form Required: /6 r L / APPROVED BY Approved By > COMMISSIONER THE COMMISSION Date — 2. Z / Form 10-403 Revsed 01/010 9 Y • cj h (� I „ In Duplicat i'' V K I DAIS AUG 0 3 2012 �� ja� i • by MPS -41A Rig Workover Current Objective: Operations Shutdown on Well MPS -41 Justification: Doyon 14 rigged up on well MPS -41 to perform a tubing swap on the CHOPs producer. The 3 exterior cables and associated clamps rats nested below the tubing hanger. Eleven joints of tubing were removed from the wellbore. Unable to pull the completion further it was set near bottom. Fishing attempts are ongoing to clean up the clamps, flat guards, heat trace, i -wire, and control line to the tubing stub. Prior to shutdown of operations a workstring string will be ran and latched up to the tubing stub. A TWC will be set at surface. BP requests approval to shutdown operations on MPS -41 while a long term plan for the well is developed. The wellhead equipment will keep the well in a safe condition while the reservoir team figures out what the long term plan is. MASP: 0 psi with reservoir fluids Well Type: Ugnu CHOPs Producer Pad Engineer: Mike Warren 564 -4306 Intervention Engineer: Sean McLaughlin 564 -4387 4). z L- • BP Exploration Alaska Inc. MPS -41A Operations Shutdown Recommend Sean McLaughlin Date: RWO Engineer Recommend Brett Anderson Date: WSL Agree Rich Burnett Date: Superintendent Agree Dave Reem Date: ETL Decide Steve Rossberg for Willingham Date: WTL • • MPS -41A Operations Shutdown Scope of operations: o Run a workstring and overshot tubing stub o Secure the well for shutdown Reference Documents: • ETP 10 -60 - Zonal isolation (Section 6.1 - Principles of Suspension) o The Ugnu is a non - moveable hydrocarbon bearing zone and single barrier at surface will be used to secure the well. • AOGCC 20 AAC 25.072 (Temporary Shutdown) Verify Start - up Checklist: ❑ A Sundry request for sh opera tl for MPS -41 will be filed with the State ASAP. Issues and Potential Hazards: ➢ Next BOP test due 8/04/2012. ➢ KWF = seawater. Current loss rate is -20 bph Suspension Plan: Initial Well Barrier Elements: Wellbore KWF, BOPE 1. Continue to feed the well continuously with seawater at 20 bph. ➢ Monitor IA pressures every hour ➢ Monitor loss rate 2. Run a guide shoe below fishing assembly to drift over the tubing stub (5.22" IBT -M collar looking up). 3. Run overshot sized for 5.22" OD IBT collar followed by two joints of 4 -1/2" IBT tubing. Set in slips and set the lower isolation sleeve over the tubing stub. Crossover over to the isolation sleeve running tool. Set sleeve per FMC. Lay down running tool and crossover. ➢ Test isolation sleeve per FMC. ➢ Overshot will be turn to release. ➢ The workstring will have minimal ID restrictions to facilitate future intervention work. 4. Run 4 -1/2" IBT -M L -80 workstring to 10' above the tubing stub. Record circulating rate and pressures, as well as PU /SO weights. Latch overshot on IBT -M collar. 5. Pick up to the nearest connection and record circulating rate and pressures, as well as PU /SO weights before landing hanger. Land Hanger. ➢ Ensure a dummy penetrator is installed in the hanger. 6. Run in lock down screws and test pack off to 5000 psi. Well: MPE -30 Version: 1 2 Suspend Well • • 7. Set BPV and preform 500 psi rolling test from below for 10 minutes. Changes to Well Barrier Elements: Welibore KWF, BOPE, BPV 8. ND BOPE and NU adapter flange, radigan, and 4- 1/16" dry hole tree. Changes to Well Barrier Elements: Welibore KWF, BPV 9. Pressure test tubing head adapter and tree with diesel to 250 psi low / 5,000 psi high for 5 ✓` minutes. 10. Confirm MPU Wells Group assumes freeze protect responsibilities after the rig moves off. , 7" ➢ Wells group will set and test TWC after freeze protecting the well. 11. RDMO Well: MPE -30 Version: 1 3 Suspend Well • • Wellhea e Gen 5 11" x ad w dry Hole 4•' 5M Radigan W M P U S-41 A • Orig. KB Elev. = 72' ellhe Tubing head: 11"x4-1/2", Orig. GL Elev. = 38.1 FMC tbg hanger TCII w/ 4" "H" BPV 20" 92 lb/ft, H -40 Welded 1 112` I Insulated - - ` Heat Trace ran to 3450' •' 4.5" NDPG multi drop tbg gauge 1 1998' I NOTE: Isolation sleeve installed in - j wellhead must be removed before - 10/5/10 - Corod assembly drilling or running another casing PU weight above stator - 16,600#'s string!!! - PU weight engaged in stator 20,700 #'s I - 3/8" SS capillary tube 9 5/8" 47 #, L -80, BTC - 0.433" TEC Wire Csg. drift ID = 8.525 ", - Csg. ID = 8.681" Burst= 6870 psi Collapse =4750 psi 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg 4.5" SLB DCIN Chem Inj Mandrel 1 3486' (Drift ID 3.833" - Capacity = .0152 bpf) 3.5" 9.3 ppf, L -80, IBT -Mod Tbg (Drift ID 2.867" - Capacity = .0087 bpf) X X 7" x 9 -5/8" C -2 ZXP 1 3968' I / Liner Top Pkr. 9 -5/8" Casing Shoe 1 4140' I , own= 4.5" WFD Pump Seating Nipple 1 4104' I 7" 26#, L -80, BTC -M Casing Csg. ID = 6.276" Csg drift ID = 6.151" 4.5" WFD Drain Sub/ 3996 psi shear 1 4135' I Burst = 7240 psi Collapse = 5410 psi ■ XO 4 -1/2" HYD x 3 -1/2" IBT 1 4637` •_i 3.5" NDPG multi drop Annular gauge 4668' �•r 3.5" NDPG multi drop tbg gauge 4704' WFD PCP Stator XXXL 327 -6000 1 4761' �•� 3.5" NDPG single drop tbg gauge 5090' 3.5" WLEG 1 5131' Top of MPS -41 7" Casing Stub @ 4275` MD MPS 41 P &A'd 7" 29# slotted liner from 1 4800' - 4880' 7" L -80 Casing 5250' - 6250' TD: 5077' 6800' - 7600' 8 -1/2" Hole 7" 26# solid liner 4000` - 4800' 4880' - 5250' 6250' - 6800' 7" Liner Shoe @ 7605' MD MPS -41 Open Hole Sidetrack i J Well Inclination @ shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS -41 Pilot hole & Horizontal Sidetrack WELL #: MPS -41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50- 029 - 23401 -01 -00 8/28/11 Hulme Pull Corod BP EXPLORATION (AK) ' Wellhead: FMC Gen 5 11" x 40 5M MPU S-41A • dry Hole Tree Orig. KB Elev. = 72' Tubing head: 11 "x4 -1/2 ", Orig. GL Elev. = 38.1' FMC tbg hanger TCII w/ 4" "H" BPV i [ Operations Shutdown 20" 92 lb/ft, H -40 Welded 112' Insulated 4 -1/2" IBT -M workstring w/ overshot latched on to tubing stub ::ti:::ti `- Top of tubing stub at 1,416' NOTE: 7.25" Isolation sleeve ;:;•:•:•9 installed in wellhead must be "" ' removed before pulling the over \ Junk - Clamps, flat guards, i -wire, - heat trace, control line .i Heat Trace > d 3/8" SS capillary tube 9 5/8" 47 #, L -80, BTC - -rin `� 0.433" TEC Wire Csg. drift ID = 8.525 ", Csg. ID = 8.681" - Burst= 6870 psi Collapse =4750 psi - 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg - (Drift ID 3.833" - Capacity = .0152 bpf) - 3.5" 9.3 ppf, L -80, IBT -Mod Tbg (Drift ID 2.867" - Capacity = .0087 bpf) N X I X 7" x 9 -5/8" C -2 ZXP 3968' Liner Top Pkr. 9 -5/8" Casing Shoe 4140' , 1 7" 26 #, L -80, BTC -M Casing Csg. ID = 6.276" Csg drift ID = 6.151" Burst = 7240 psi Collapse = 5410 psi 1 MIN ANISI Top of MPS -41 7" Casing WLEG at 5,939' Stub @ 4275' MD MPS-4 1 P &A'd 7" 29# slotted liner from 7" Casing i 4800` - 4880' TD: 5077' i 8-1/2" Hole 5250' - 6250' 6800' - 7600' 7" 26# solid liner 4000' - 4800' 4880' - 5250' 6250' - 6800' MPS -41 Open Hole Sidetrack i 1 7" Liner Shoe @ 7605' MD J Well Inclination @ shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole I . DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS -41 Pilot hole & Horizontal Sidetrack WELL #: MPS -41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50- 029 - 23401 -01 -00 BP EXPLORATION (AK) t 4 pet ,ii, 4,.. .. ,.. e vv s Po9e Access v. safety issue in tussle 7 between AOGCC and Alyeska Vol. 16, No. 36 • www.PetroleumNews.com A weekly oil & gas newspaper based in Anchorage, Alaska Week of September 4, 2011 • S2 • EXPLORATION 8 PRODUCTION - Escoeta almost there is l et di: " ' ' w; s: s ' r.;; s Company chief addresses doubts, anticipates drilling in Alaska's Cook Inlet s un w "` w : s ! By MIT LOY NEWS FLASH . . 61 Z ° !A I ! d t. For Petroleum News y ^ :� ra 4 r 1,;4 + 1I 3 The Alaska Oil and Gas Conservation ,i = ■ ; As Petroleum News went to Commission completed its rig inspection am, i n Oki il' A 1 press, Escopeta Oil Co. was , late on Aug. 31, giving Escopeta the dt _ ; , - primed to spud its first exploratory f 1 final regulatory approval needed to S le I i .i to z ±well from a jack -up rig in Alaska's *'y spud its Cook Inlet well, but as a cour- 1t 1 sre rh: I•// Cook Inlet. levy to Bill Barron, Alaska's oil and gas V t A , : _ director, Escopeta officials are going to w-+ - , t th _ j + Ed Oliver, the company's new meet with him beforehand, company w•—• t t r� ! ; president, said in an Aug. 31 inter- ED pomp spokesman Steve Sutherlin told view that inspections were nearly Petroleum News Sept. 1. AOGCC inspec- .? complete, permits were in hand and drilling could begin tor Lou Grimaldi said in an email to E'''. within a day or two. Escopeta that in his report to his super- , , ' - : - .�, `�„ He added that the company, which came under new visor he "used the terms outstanding ownership in late June, was working hard to allay any and flawless as these best describe the CL. + efforts that your men expended in corn- concerns about Escopeta's commitment to drill safely and - in accordance with regulations. ing into compliance." 1.13 — Kay Cashman see ESCOPETA DRUM page 17 The Spartan 151 jack -up rig in Cook Inlet in August; the legs are now KOV buys Adriatic XI down on the rig and it is ready to spud its first well for Escopeta. See story this p Buccaneer JV set to close on jack -up rig in October, start drilling next year aS Some lessons learned: USCG h IRK li 11 The funding for the $86.5 million project report puts DWH record straight ` For Petroleum New will come from three sources. Much has been said and written about the causes and con- Q subsidiary of Buccaneer Energy Ltd. has sequences of the 2010 Deepwater Horizon disaster in the rl signed an agreement to buy a jack -up rig tions of Cook Inlet. Gulf of Mexico, and about the scramble to respond to an oil from Transocean Offshore Resources Ltd., the The entire effort to buy, modify and mobilize spill that no one appeared adequately prepared to deal with. Australian independent announced Sept. 1. the jack -up rig, known as Project Endeavor, is However, the U.S. Coast Guard's incident report, known as Kenai Offshore Ventures LLC will buy the GSF expected to cost $86.5 million, according to the Incident Specific Preparedness Review, or ISPR, provides Adriatic XI rig for $68.5 million. Buccaneer. The company said that the budgets for some fascinating insights into lessons learned from how the The sale is expected to close between Sept. 30 the mobilization and modification activities are response was conducted, and how those lessons might be and Oct. 25. still being finalized. applied to planning for some future oil spill contingency. The rig has been cold stacked in Malaysia since The funding for the $86.5 million project will And the annual meeting of the Pacific States /British 2009, Buccaneer said. Once the deal is fmalized, come from three sources, Buccaneer said. Columbia Oil Spill Task Force, held in Anchorage, Alaska, on Buccaneer said the rig would be moved to an Kenai Offshore Ventures, a 50-50 joint venture Aug. 24, particularly focused on the ISPR findings. Asian-based shipyard to undergo modifications to winterize the rig for use in the sub - Arctic cortdi- Xiitl6 page see USCG REPORT page 19 c Keystone XL clears one hurdle: Positive EA from State Dept. It's going gangbusters l P5` y ( A The U.S. Department of State has issued a positive envi I ronmental assessment of TransCanada's plans to ship Alberta , BP meets with initial success in tests of heavy oil production at Milne Point oil sands crude to Texas refineries, but the next three months rn promise to be an epic showdown between forces on both RY ALAN tN sides of the issue and a pivotal test of President Barack BP has in fact drilled Jour wells for its Petroleum News Obama's promise to fight climate change by reducing heavy oil testing, each in a different dependence on fossil fuels. reservoir zone. The State Department gave the strongest endorsement yet BP's heavy oil test facility at Milne oi S Pad of the Keystone XL project to ship 500,000 barrels per day of on Alaska's North Slope has been going gang- 6 1 diluted bitumen on a 1,700 -mile, $7 billion pipeline from busters since the facility started up in early May. On Aug. 31 Eric West, manager of BP's Alaska a I Canada to the Gulf Coast. Petroleum engineering consultant Dudley Platt has renewal team, told Petroleum News that it is too pointed out to Petroleum News that in July the soon to make production comparisons with con - In one of its strongest findings, the report concluded that facility's single operating heavy oil test well, ventional North Slope oil wells but that the heavy the need for heavy crude in the Gulf Coast would continue to drawing thick, syrupy oil from sands in the shal- oil test well had achieved a maximum production grow over the next decade, even in a low - demand scenario. low Ugnu formation, appeared to have achieved rate of 550 net barrels of oil per day. The well had If XL was not built, refineries would look for heavy crude average daily production rates in excess of the g IY per produced 7 clay a total nf4 us barrels e at of heavy oil over from other sources and transport it by other U.S. pipelines, wen average production fives conventional wells 117 days of continuous operation since testing railroads, trucks or barges. in the main oil 1 at Prudhoe Bay, according to Poo Y g started in April. see REYSTOME WROTE page 18 data from the Alaska Oil and Gas Conservation Commission. see WAVY OIL TESTS page 14 ZWi t:2 o■_S 6 1 L. \,, \IE' • 14 • PETROONEWS • WEEK OF SEPTEMBER 4, 2011 t continued from page 10 aokls to the mowing body of research The two -year study, the resuhs of of major environmental changes. The SPILL MODELING regarding effects of climate change on the which BOEMRE has now published, par- report also recommends that the agency Arctic marine environment." titularly focused on the Beaufort and should run multiple models, to assess the Oil spill trajectories in the Arctic. off- Chukchi Seas, taking into account the how these models predict the changes in we need the best scientific data available shore would be impacted by ocean cur- most up-to -date oceanographic knowl- movement of a hypothetical oil spill to understand the impact of the changing rents, which in turn are influenced by fan edge and including feedback from under the impacts of climate variability, climate," said BOEMRE Director tors such as wind, precipitation, evapora- oceanographic and atmospheric scien- using data covering a five -year period. Michael Bromwich on Aug. 29 in lion, river runoff and sea ice coverage, tists. The report recommends that BOEM- — ALAN BAILEY announcing the publication of the study with rapid changes in any of the climate RE should organize a data archive of U.S. results. "This study will help improve our related parameters potentially altering the Arctic atmospheric, sea ice and ocean computer modeling and analyses and it currents, BOEMRE says. conditions, to enable the documentation Contact Alan Bailey ti Y at alailey@petroleamnews.com continued from page 1 urations other than the single well that has drives the foam into the well bore, from objectives. HEAVYH OIL been ope ration. Unknowns include the where the foam can be pumped up the well Actually we got a little more life out of TESTS i i production performance of different zones bore to the surface. it than we thought," West said. within the Ugnu reservoir — the reservoir "We know that's working because the And closing the well fora while will pro- "We are pleased with the well.... It's consists of a series of discrete, differing samples we acquire at the wellhead show vide an opportunity to determine how effec- awesome," West said. sand bodies, rather than a single, homage- evidence of that (foam)," West said tively production will restart after a shut- Major resource neous unit. When BP first put the test well into pro- down, helping determine the sustainability The idea is to avoid the results from a duction the company started with a relative- of heavy oil production through the There are an estimated 12 billion to 18 single well turning out to be a false positive ly modest poop rotation speed of 100 rpm, inevitable well workovers that would take billion barrels of heavy oil in the Ugnu, a before going to the bank on a development subsequently turning up the throttle to place in a commercial production envirmn- potential major resource even if only a rela- project — it is necessary to see repeated observe how the well reacts to increasing ment. tively low percentage of that oil can ulti- production from multiple wells, West pump speeds — the higher the pump speed, mately be recovered explained. the greater the oil pnduction rate, with die Gas Gush siskss But don't expect the spigots to open for proviso that a too -high speed would cause One unanticipated problem in the heavy connnercial heavy oil production from the Four wed gas to separate from oil in the reservoir, thus oil testing has been a failure of the system Ugnu any time soon. BP has yet to deter- BP has in fact drilled four wells for its compromising oil production. designed to scrub gas out of the produced mine whether production can be sustained heavy oil testing, each in a different reser- oil. Instead of using this system, BP has at corrmiercial levels in the long tent. and voir zone. Two of the wells, including the Vhm tabMG obtained permission to flare the gas, while has yet to test production from well "' one that the company has tested to date, are A solid rod passing down the well bore producing oiI from just the one well until horizontal wells, configured to access a rel- from the surface turns the pump rotor. Over the gas scrubbing system is fixed, West said. Oilfield Improvements"' atively large volume of Ugnu sand. The time this spinning rod puts wear on the steel The company is hesitant to bring any other ULTRA - FLOW"' other two wells are vertical, designed to use tubing that lines the well, thus requiring wells on line until that fix has been corn - FIELD- INSTALLED a technique called cold heavy oil production some of the tubing to be replaced. 131' has pleted, he said CENTRALIZERS/ with sand, or CHOPS, involving the use of recently had to stop production from the test On the plus side of the testing equation, PARAFFIN SCRAPERS an augur-like downhole pump to draw a well because the rod had wont a hole in the BP has been delighted with the way sand Full Wiping mixture of sand and oil into the well. tubing. The company has since been paofil- flowing into the well has flushed from the of Tubing 1.11 The horizontal wells use the same type ing the thickness of the tubing down the web bore without a need shut the well in of pump as the CHOPS wells, with the well, to determine which sections of the tub- for cleaning, West said. More Gripping pump drawing down the reservoir pressure ing to replace with specially hardened pipe — ALAN BAILEY Force on Sucker Rods around the well bore, thus causing gas in the for continued web operation. Wear on the p More Fluid Flow -by reservoir to effervesce, forming a foamy tubing had been anticipated, with drtem»n- Contact Alan Bailey Volume material with the oil. The effervescing gas ing the rate of wear being one of the test at abailey@peaaleumnews.com >i T� ^. Longer Useful Life tr,,. fromLongerVanes .:!. 00 a Bearing Sues s° +r. 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Prudhoe Bay, AK ro PH0918- 250 -5584 • FAX 918- 250 -4666 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg /am' r 1//, v DATE: 8/21/11 P. I. Supervisor 1 \ 1 FROM: Bob Noble SUBJECT: No -Flow Test Petroleum Inspector BPXA Milne Point Unit MPU S -41A, PTD 2081610 SONNEOFEB 1 6 ZU12 8 -21 -11 met with BPXA representatives Jon Arend and John Perl. We discussed the planned No -Flow test. MPU S -41A (PTD 2081610) is part of the cold heavy oil (HO) pilot project, and the no flow test would serve 2 purposes: - Support the completion design for the HO wells which are designed to be packerless; and - Establish that 8.07 ppg Ugnu crude could be used as kill weight fluid to pull the co -rod out of the well instead of oil base mud. The BPXA representatives said that oil base mud has negative effects on their production facility. MPU S -41A developed a hole in the tubing and was subsequently shut in for repairs. On 8- 16 -11, BPXA injected 474 barrels of 8.07ppg Ugnu crude down the IA and back up the tubing of MPU S -41. This was done to load the well and circulate sand out of the well bore followed by 69 barrels of 7.69 ppg MPU crude injected down the tubing. I was told that the tubing fluid level shot before I arrived at the location was 366 feet from surface. The IA fluid level was reported as 550 feet from surface. A pressure gauge /recorder was hooked to the tubing. It was monitored for 3 hours. Pressure held steady at negative 12 psi for the 3 hours. The same pressure gauge /recorder was hooked to the IA and it was also found to have negativel2 psi. I put my finger over the half inch port and I would call both the IA and the tubing as having a good strong vac. Attachments: none MPU S -41A No Flow Test 8 -21 -11 bn • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 8/21/11 P. I. Supervisor FROM: Bob Noble SUBJECT: No -Flow Test Petroleum Inspector BP Alaska Inc MPU 5-41A 8 -21 -11 rD = 208- I1 I I met with BP Reps. Jon Arend and John Peri. We discussed the No -Flow test. They were trying to establish that 8.07 ppg Ugnu crude could be used as kill weight fluid to pull the Co -Rod out of the well instead of oil base mud. They said that oil base mud has negative effects on their production facility. 8- 15 -11, MPU S-41 developed a hole in the tubing and was shut in. 8- 16 -11, They injected 474- barrels _of 8.07ppg Ugnu crude down the IA and back up the tubing of MPU S-41. This was done to load the well and circulate sand out of the well bore. Then 69 barrels of 7.69 ppg MPU crude were injected down the tubing. 8 -21 -11 Fluid levels were shot before I arrived and I was told that the tubing fluid level was 366' down. The IA fluid level was 550' down. A pressure gauge /recorder was hooked to the tubing. It was monitored for 3 hours. It held a steady -12 psi for the 3 hours. The same pressure gauge /recorder was hooked to the IA and it was also found to have -12 psi on it. I put my finger over the half inch port and I would call both the IA and the tubing as having a good strong vac. Attachments: 57e, AUG 2 4 201i Non -Conf No -Flow BP MPU S-41 bn (2).doc 1 of Sheet/Calculations 01/29/10 LG Page 1 of 2 • Schwartz, Guy L (DOA) From: Worthington, Aras J [Aras.Worthington @bp.com] Sent: Monday, August 22, 2011 2:54 PM To: Worthington, Aras J; Schwartz, Guy L (DOA) Subject: RE: MPS-41 No Flow Test Guy, Here is the procedure for the no -flow test submitted for AOGCC approval with the detail of what was pumped down the well included_ Aras Worthington Wells Intervention Engineer Bp Alaska, Inc. (907) 564 -4102 No Flow Test: Prior to this No -Flow Test the welibore was flushed with Ugnu and Milne crude while keeping the downhole PCP rotating with the drivehead to clear the welibore of sand. Fluids pumped were as follows: - 489 bbls of Ugnu Crude down the IA (70 bbls of production up tubing while this was pumped down IA) 8/15/2011 - 69 bbls of Milne Crude down the tubing 8/16/2011 1. Provide the AOGCC inspector 24 hours notice to witness a tubing no -flow. Document the notification of the AOGCC in AWGRS report and whether or not the witness was accepted or waived, by whom, and the time /date. 2. DHD shall perform a 3 -hour no -flow test using a calibrated low pressure gauge (1 psi increments) and a calibrated gas meter rigged up to the radigan outlet opposite the flowline. (See schematic below for AOGCC equipment requirements per Guidance Bulletinl0 -004). The requirements for "no flow" per AOGCC 20 AAC 25.265 are as follows: A. The measured liquid production is not greater than 6.3 gallons per hour, and the measure gas production is not greater than 900 standard cubic feet per hour; or B. Well pressure is discharged not later than five minutes after a three -hour charted pressure build -up period 8/23/2011 Page 2 of 2 • Cizirtzwe Butler. Ar.r4 6arety Vuhc Syst4Trq AftpuncliT A - NO Pm Test Equiplarat Lew SITe gs 1-psi vi ...... 4izm III / ) flycning - I LI $' Row mcne tuac or 114-al !_ v: Ictiino • huuket Tte 7 C.f4; L lui with watcr) • 5 8/23/2011 II 0 I∎ C'o'oeI &'/ _' J COROD Safety 22" , 3 -1/2 Otis 5000 6166' I 1 - 0204- 16 / 4 ft Lubricator . - ------ 3 ft 3 -1/2 Otis 5000 i 2 f ,.„.__„„) C_ -._J I 3 -1/2 Otis 5000 MANNED AUG 1 9 2011 GKS Upper Annular Assy #7473A 2 -9/16 5000 R27 Bore 2.56" Model GKS 4130 serial# 48518 -3 -ACD -2 GKS Lower Annular Assy # 7473B 6'9" 2 -9/16 5000 R27 Bore 2.56" Model GKS 4130 I I serial# 49618 -3 -ACD -1 .... ,_. Rod Ram Assy 111111.11 3 -1/8" 10K Model — serial# ■ X -Over 3 1/8" 10K X 4 1/16" 5k ' (X�z�_"_(?�^z)_'I, Flanged Pump -In Sub /Choke /Kill Line Inlet; 24" OAL - �— of 4 1/16" 5K X 4 1/16" 5k _ ■ Gate Valves (2) To Choke ' 41/16" 5K X 4 1/16" 5k / Check Valve `._ ..... MI..... I 1NINNII I-1Ol ---0' Kill Line (to pump) a -1 n Snnntt ' GO' K, I Mill ~— Blow Down Tee „ 5000 Radigan Spool /1502 Integral 11" soon# .,....s. .1. ..,. .,. - r. ,-- ,. , Tbg spool Cl IA Valve /1502 Integral .....T.T.T.T.. - - n" 5000# is « • slialf[E 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 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. ` I P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Ugnu Pool, MPS -41A Sundry Number: 311 -255 a Aug 7.011 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ) . day of August, 2011. Encl. II • STATE OF ALASKA �� RECEJV ALASKA PAND GAS CONSERVATION COMMISSI �~ AUG 1 6 2011 APPLICATION FOR SUNDRY APPROVAL f/,- // 20 AAC 25.280 Asks Off & aril cap Gcminisski 1. Type of Request: Anchorage ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool - Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate _El Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Pull & Run Corod assembly 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -® Development ❑ Exploratory • 208 -161- 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 r 50- 029 - 23401 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS -41A - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 6 10. Field / Pool(s): V ADL 380109 & 380110 y Milne Point Unit / Ugnu' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7605' - 3807' - 7605' - 3807' - None None Casing Length Size MD • ND Burst Collapse Structural Conductor 120' 20" 120' 120' Surface 4140' 9 - 5/8" 4140' 3477' 6870 4760 Intermediate Production Liner 3637' 7" 3968' - 7605' 3385' - 3807' , 7240 5410 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner: 4800' - 7600' 3738' - 3807' 4 x 3 - 1/2 ", 12.6# x 9.2# L - 80 5131' Packers and SSSV Type: None Packers and SSSV None MD (ft) and ND (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ., Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 18, 2011 Y =0 Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Na David Reem Title Engineering Team Leader Prepared By Name/Number. Signature Phone 564 -5743 Date g.16_200 Elizabeth Barker, 564 -5674 Commission Use Only Conditions of approval: Nry No ' Commission so that a representative may witness 2 1 , �� Sundry Number: u 1 ❑ Plug Integrity MiOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 44.- 2600 /os'a /3 P 7C.5 t Other: r / � 11 f C � 1 Subsequent Form Required: /0 — cloy ( /// / 7''' Approved By: APPROVED BY % COMMISSIONER THE COMMISSION Date i f Form 10-403 Revis - Pl �. OR � � � � Submit In uplicat AUG 18 211 A L 74- P 17. // /7// • • b P ( 4 ) • Po H eavy Oil Team Today Future Forward MPS -41 Completion Scope of Work: Repair hole in 4 -1/2" tubing MASP: 990 psi (1363 psi @ 3750' TVD, less 0.1 psi gas gradient) Well Type: Ugnu Heavy Oil Producer Estimated Start Date: August 18th, 2011 Production Engineer: Jim Young Intervention Engineer: Aras Worthington Workover Engineer: Sean Mclaughlin Pre -iob prep work 1. Circulate the well to KWF (7.0 ppg mineral expected) Scope of Work Pull Corod 1. MIRU Weatherford Mast Unit and Mobile Gripper Unit (Corod rig). 2. Remove drive head. 6, c..;2 3. NU Corod BOPE including 1 1/8" Rod rams and annular preventer and test to 2000 psi. 4. Recover corod. 5. Caliper tubing 6. Set BPV Tubing Swap 7. MIRU Doyon 16. NU BOPE including 2 -7/8" x 5" VBR rams, blinds, and Annular preventer. Test BOPE to 2000 psi. 8. Pull 4 IA" x 3'A" PCP completiorf. 9. Run 4'A" x 3' /s" PCP completion w/ 2000' of boronized tubing (to prevent tubing wear).. 10. RDMO Doyon 16. Run Corod 11. MIRU Weatherford Mast Unit and Mobile Gripper Unit (Corod rig). p 12. NU Corod BOPE including 1 1/8" Rod rams and annular preventer. ,p5 13. Test BOPE to 2000 psi. R ',a 14. Run PCP Rotor with 1 1/8" Corod, Drive Rods for space -out to surface, and 1 %2" Polish -Rod. 15. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. 16. ND BOP stack and gate valve. 17. Install electric rotating drive head. Pressure test Drive Head seals to 1500 psi. 18. RD Weatherford Corod Rig. Wellhead: FMC Gen 5 11" x 4 1/16" 514IP M P U S -41 A Radigan Wellhead w dry Hole Tree KB Elev. = 72` Tubing head: 11" x 4 -1/2 ", Orig. GL Elev. = 38.1 FMC tbg hanger TCII w/ 4" "H" BPV I 40' of 1 -1/2" x 1 -1/8" x 1" Polished Rod . • 20" 92 lb/ft, H -40 Welded 1112' I : I 124' of TC66 SKR 1-1/4" x 1 -1/8" SH HS Insulated • ( 4000' Corod Ser # 8.5 /Reel # 942 Heat Trace ran to 3450` �i �•' 4.5" NDPG multi drop tbg gauge 1 1998' NOTE: Isolation sleeve installed in - wellhead must be removed before 10/5/10 - Corod assembly - drilling or running another casing PU weight above stator - 16,600 #'s string!!! - PU weight engaged in stator - 20,700 #'s 3/8" SS capillary tube 9 5/8" 47 #, L -80, BTC - v 0.433" TEC Wire Csg. drift ID = 8.525 ", - Csg. ID = 8.681" >0.-' Burst= 6870 psi Collapse =4750 psi 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg 4.5" SLB DCIN Chem Inj Mandrel 3486' (Drift ID 3.833" - Capacity = .0152 bpf) 3.5" 9.3 ppf, L -80, IBT -Mod Tbg (Drift ID 2.867" - Capacity = .0087 bpf) Z F 7" x 9 -5/8" C -2 ZXP 3968' Liner Top Pkr. 9 -5/8" Casing Shoe 4140' I ' w 4.5" WFD Pump Seating Nipple 1 4104' 7" 26 #, L -80, BTC -M Casing _____>. 111 Csg. ID = 6.276" Csg drift ID = 6.151" 4.5" WFD Drain Sub/ 3996 psi shear 4135 Burst = 7240 psi Collapse = 5410 psi • XO 4 -1/2" HYD x 3 -1/2" IBT 4637' 1 -1/8" Jaw Style FS 30K Shear Coupling r =Ira 3.5" NDPG multi drop Annular gauge 4668' 587' Corod Ser # 8.5 Giraffe String ..1 3.5" NDPG multi drop tbg gauge 4704' 52 -1200 XL Ser # 108457 i : WFD PCP Stator XXXL 327 -6000 4761' i i 1 i 1 3.5" NDPG single drop tbg gauge 1 5090' IIII 3.5" WLEG 5131' Top of MPS -41 7" Casing Stub @ 4275' MD MPS 41 P&A'd 1 7" 29# slotted liner from i 4800' - 4880' 7" L -80 Casing 5250` - 6250' TD: 5077' 6800' - 7600' 8 -1/2" Hole 7" 26# solid liner 4000' - 4800' 4880' - 5250' 6250' - 6800' i . 7" Liner Shoe @ 7605' MD MPS 41 Open Hole Sidetrack i Well Inclination @ shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole I . DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS -41 Pilot hole & Horizontal Sidetrack WELL #: MPS 41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50 -029- 23401 -01 -00 BP EXPLORATION (AK) . Wellhead: FMC Gen 5 11" x 4 1/16" 50 M P U S-41�► Radigan Wellhead w dry Hole Tree KB Elev. = 72' Tubing head: 11 "x4 -1/2 ", Proposed RWO Orig. GL Elev. = 38.1' FMC tbg hanger TCII w/ 4" "H" BPV ] - — 4( 40' of 1 -1/2" x 1 -1/8" x 1" Polished Rod 20" 92 lb/ft, H -40 Welded 1112' 124' of TC66 SKR 1 -1/4" x 1 -1/8" SH HS Insulated - - - O !!1( 4000' Corod Ser # 8.5 /Reel # 942 Heat Trace ran to 3450' )i' ® 4.5" NDPG multi drop tbg gauge 1 1000` C 4.5" 12.6 ppf, Boronized, 1 tedtoK55,SLHT 10/5/10 - Corod assembly PU weight above stator - 16,600 #'s - NOTE: Isolation sleeve installed in PU weight engaged in stator - 20,700 #'s wellhead must be removed before - drilling or running another casing - string!!! _ < 3/8" SS capillary tube 9 5/8" 47 #, L -80, BTC - v 0.433" TEC Wire Csg. drift ID = 8.525 ", - Csg. ID = 8.681" ) . Burst= 6870 psi Collapse =4750 psi 4.5" 12.6 ppf, L -80, Hydril 563 SC tbg 1 F 4.5" SLB DCIN Chem In) Mandrel 3486' (Drift ID 3.833" - Capacity = .0152 bpf) 3.5" 9.3 ppf, L -80, IBT -Mod Tbg (Drift ID 2.867" - Capacity = .0087 bpf) r X 7" x 9 -5/8" C -2 ZXP 3968' 7 x -5 8 0- 9 5/8" Casing Shoe 4140' I ' w 4.5" WFD Pump Seating Nipple 1 4104' 7" 26 #, L -80, BTC -M Casing D 111 Csg. ID = 6.276" Csg drift ID = 6.151" MEM 4.5" WFD Drain Sub/ 3996 psi shear 1 4135` Burst = 7240 psi Collapse = 5410 psi iii XO 4 -1/2" HYD x 3 -1/2" IBT 1 4637` 1 -1/8" Jaw Style FS 30K Shear Coupling j+ �.i 3.5" NDPG multi drop Annular gauge 4668' 587' Corod Ser # 8.5 Giraffe String sm�1 3.5" NDPG multi drop tbg gauge 4704' 52 -1200 XL Ser # 108457 i i ; WFD PCP Stator XXXL 327 -6000 4761' 1 3.5" NDPG single drop tbg gauge 5090' I. 3.5" WLEG 1 5131' Top of MPS -41 7" Casing Stub @ 4275' MD MPS -41 P&A'd i 7" 29# slotted liner from 4800' - 4880' 7" L -80 Casing 1 TD: 5077' 5250' 6250' 6800' - 7600' 8 -1/2" Hole 7" 26# solid liner 4000' - 4800' 4880' - 5250' 1 6250' - 6800' 1 7" Liner Shoe @ 7605' MD MPS 41 Open Hole Sidetrack I Well Inclination © shoe = 90 degrees Ugnu Horizontal 8 -1/2" Hole DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS -41 Pilot hole & Horizontal Sidetrack WELL #: MPS 41A 8/24/10 REH FCO - run CHOPS completion - 4ES API NO: 50 -029- 23401 -01 -00 BP EXPLORATION (AK) • TeD 2 O 8 - 3.06 Hydril Annular Bag co ebdo4 ... 8c 1 3.06 Hydril Annular 4 Bag I { 90=1111111r . , 3 10,000PSI BOP (TOT) with 1.156 ram inserts 'tea ik Below this flange will be the 41' Radigan ' .. ek • • Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Tuesday, May 31, 2011 4 :14 PM To: Saltmarsh, Arthur C (DOA) Subject: MPS -41A / Permit # 208 -161 Hi Art, Please reference the following well: Well Name: MPS -41A Permit #: 208 -161 API #: 50- 029 - 23401 -01 -00 Top Perf MD: (Slotted Section Top) 5590' Bottom Perf MD: (Slotted Section Top) 7562' This well began Production on April 22, 2011 Method of Operations is: Flowing Date of Test: 04/21/11 (Through a Portable Test Separator) Hours Tested: 5 24 -Hour Rate / Oil -Bbl: 320 24 -Hour Rate / Gas -Mcf: 100 24 -Hour Rate / Water -Bbl: 25 �U 1 Test Rate / Oil -Bbl: 67 Test Rate / Gas -Mcf: 21 Test Rate / Water -Bbl: 5 Choke Size: N/A Gas -Oil Ration: 313 Flow Tubing Pressure: 137 Casing Pressure: 5 Oil Gravity -API: Not Available 1 DATA SUBMITTAL COMPLIANCE REPORT 6/29/2010 Permit to Drill 2081610 Well Name/No. MILNE PT UNIT UGNU S-41A Operator BP EXPLORATION (ALASKA INC API No. 50-029-23401-01-00 MD 7605 TVD 3807 Completion Date 12/17!2008 Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION ~-' Mud Log No Samples No Directional Surv~j ~ Y DATA INFORMATIDN Types Electric or Other Logs Run: DIR / GR / RES, DEN / NEU w/ACAL, IFR / CASANDRA Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / type mearrrmt pt ~~umue~ name LIS Verification ~~a~~ ~no~a~a rva awn 3905 ~wp 7606 ~.n Open r~e~eiveu 2/25/2009 w~n~nc~~w LIS Veri, GR< FET, RPS, PEF, RPX, DRHO, NPHI, FCNT, RPD, NCNT, ~ /' ~ ED C Lis ~~ 17626•'Induction/Resistivity 3905 7606 Open 2/25/2009 RHOB, CALA, ROP LIS Veri, GR, FET, RPS, PEF, RPX, DRHO, NPHI, FCNT, RPD, NCNT, RHOB, CALA, ROP Rpt LIS Verification 3905 6065 Open 2/25/2009 P61 LIS Veri, GR, FET, I RPS, PEF, RPX, DRHO, NPHI, FCNT, RPD, NCNT, RHOB, CALA, ROP ED C Lis 17627/Induction/Resistivity 3905 6065 Open 2/25/2009 PB1 LIS Veri, GR, FET, RPS, PEF, RPX, DRHO, NPHI, FCNT, RPD, NCNT, RHOB, CALA, ROP pt LIS Verification 3905 6148 Open 2/25/2009 P62 LIS Veri, GR, FET, RPS, PEF, RPX, DRHO, NPHI, FCNT, RPD, NCNT, RHOB, CALA, ROP ED C Lis 17628 flnduction/Resistivity 3905 6148 Open 2/25/2009 P62 LIS Veri, GR, FET, RPS, PEF, RPX, DRHO, NPHI, FCNT, RPD, NCNT, RHOB, CALA, ROP DATA SUBMITTAL COMPLIANCE REPORT 6129/2010 Permit to Drill 2081610 Well Name/No. MILNE PT UNIT UGNU S-41A Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23401-01-00 MD 7605 TVD 3807 Completion Date 12/17/2008 Completion Status SUSP Current Status SUSP UIC N og Induction/Resistivity 25 Col 4140 7605 Open 2/25/2009 MD ROP, EWR, DGR, ALD, CTN, ACAL 13-Dec- 2009 og Induction/Resistivity 25 Col 3477 3807 Open 2/25/2009 TVD EWR, DGR, ALD, CTN, ACAL 13-Dec-2009 ~I~~~ •I'LOg Induction/Resistivity 25 Col 4140 6055 Open 2/25/2009 PB1 MD ROP, EWR, DGR, ALD, CTN, ACAL 13- Dec-2009 Log Induction/Resistivity 25 Col 3477 3791 Open 2/25/2009 P61 TVD EWR, DGR, ALD, CTN, ACAL 13-Dec- i 2009 ~og Induction/Resistivity 25 Col 4140 6147 Open 2/25/2009 PB2 MD ROP, EWR, DGR, ALD, CTN, ACAL 13- Dec-2009 og Induction/Resistivity 25 Col 3477 3775 Open 2/25/2009 PB2 TVD ROP, EWR, DGR, ALD, CTN, ACAL 13- ~ Dec-2009 ED C 17629 rlnduction/Resistivity 0 0 Open 2/25/2009 Final Hole, P61, and PB2 logs in PDS, EMF and CGM graphics "ED C Asc f Directional Survey 5352 7605 Open 2/12/2009 /pt ~ Directional Survey 5352 7605 Open 2/12/2009 ~'ED~~ C Asc Directional Survey 4140 6055 Open 2/12/2009 PB 1 .F(pt Directional Survey 4140 6055 Open 2/12/2009 PB 1 D C Asc ~ Directional Survey 5446 6147 Open 2/12/2009 PB 2 ~tpt Directional Survey 5446 6147 Open 2/12/2009 PB 2 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~ • DATA SUBMITTAL COMPLIANCE REPORT 6/29/2010 Permit to Drill 2081610 Well Name/No. MILNE PT UNIT UGNU S-41A Operator BP EXPLORATION (ALASI(a INC API No. 50-029-23401-01-00 MD 7605 TVD 3807 Completion Date 12/17/2008 Completion Status SUSP Current Status SUSP UIC N ADDITIONAL INFORMATION `('~, Well Cored? Y ~ Daily History Received? ~ N Chips Received? l~'7lT" Formation Tops ~ N Analysis ~f~d''~ Received? -- -- ---- --- _ Comments: _ -- -- - ---- -- - - --- _ -- O~ ~ ~ Compliance Reviewed By: _.-__ _ Date: _ ' ~ ~ ALA58A OIL AI•iD GA.S CO1~T5EItVATIOrT COAII-II55IO1~T Dan Kara Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Ugnu Pool, MPS-41A Sundry Number: 310-161 Dear Mr. Kara: SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~p$-!~I Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person .affected by it may file with the Commission an application for 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, Dani T. Seamount, Jr. G ~ Chair DATED this- / day of June, 2010. Encl. .~ ~.- ,n h' CC' U"~,~ o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSTdN APPLICATION FOR SUNDRY APPROVAL RECEIVED MAY2~2010 20 AAC 2.5 280 .~__~. Ina w 6e3 Cens. Commission 1. Type of Request: An~hl~i~i~! ^ Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ®Pull Tubing, ^ Time Extension ^ Operations Shutdown ®Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 208-161 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23401-01-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS-41A ' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 380109 & 380110 Milne Point Unit / Ugnu 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7605' ~ 3807' 7605' 3807' 3950' None Casin Len h Size MD TVD Burst Colla Structural Conductor 12 ' 20" 12 ' 4 47 Surtace 414 ' 9-5/8" 4 40' 24' 7 47 Intermediate Production 7' 7" ' - 7 72 4 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner: 5590' - 7562' 3770' - 3808' 4-1/2", 12.6# L-80 2153' Packers and SSSV Type: None Packers and SSSV None MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ~ ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 10, 2010 ®Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG ^ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthin ton, 564-4102 Printed Name Dan Kara Title Engineering Team Leader Prepared By Name/Number: g Phone 564-5667 Date ~~'LO I ?.OI O Terrie Hubble, 564-4628 Si nature ~ ~ Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ~~ ~ ~ ((n I Sundry Number: 11 ~~Yy ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance .~o?DOo ~ps~ ,~oP ~s ~ Other: p ~ Zaoa ~ s ~ l~hK ~«-~ ~s f Subsequent Form Required: ~ ~ - y0 APPROVED BY ~ YYY Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revisetl 0112010 ~ (1 {) I ~ ~ ~\ (~ ~ _ J G • (-/~ Submit In Duplicate • MPS-41 Completion Scope of Work: Capital completion -Pull 4 1/2" kill string. Clean out 7" liner, deploy 1 1/8" Continuous Sucker Rod string. MASP: 1325 psi ,/ Well Type: Ugnu Heavy Oil Producer Estimated Start Date: July 10th, 2010 Production Engineer: Jim Young Intervention Engineer: Aras Worthington Pre-iob prep work 1. Set BPV. Scope of Work 1. MIRU Nabors 4ES. NU BOPE including 4'h" Pipe rams, blinds, and Annular preventer. Test BOPE to 2000 psi. 2. Pull and LD 4'/" Kill String. 3. PU DP and retrieve 9 5/8" RBP @ 3950' MD. 4. RIH w/ Cleanout BHA and displace OBM from 7" liner to PBTD. 5. Run 4'/" x 3'h° PCP completion. 6. RDMO 4ES. 7. MIRU Weatherford Mast Unit and Mobile Gripper Unit (Corod rig). 8. NU Corod BOPE including 1 1/8" Rod rams and annular preventer. - ~ §'~~~ r °'"`" 9. Test BOPE to 2000 psi. 10. Run PCP Rotor with 1 1/8" Corod, Drive Rods for space-out to surface, and 1 '/2" Polish-Rod. 11. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. 12. ND BOP stack and gate valve. 13. Install electric rotating drive head. Pressure test Drive Head seals to 1500 psi. 14. RD Weatherford Corod Rig. by • ; ,~- .. Tree: Cameron 4-1/16" 5M Wellhead:FMC Gen 6 11"- 5M Tubing head: 11" x 4-1/2", FMC tbg hanger 20" 92 Ib/ft, H-40 Welded 112' Insulated 9 5/8" 47#, L-80, BTC Csg. drift ID = 8.525", Csg. ID = 8.681" Burst= 6870 psi Collapse=4750 psi ~. KB Elev. = 72` Orig. GL Elev. = 38.1' 4-1/2" Kill Strin 4-1/2", 12.6# L-80, IBT-M Coupling Drift ID: 3.833" Burst: 8,430 psi/ 80%= 6,000psi Capacity= .0152 bbl/ft 4-1/2" X Nipple 2110' 4-1/2" WLEG 2151' 9-5/8" Casing Shoe 4140' 7" 26#, L-80, BTC- M Casing Csg drift ID = 6.151" Csg. ID = 6.276" Burst = 7240 psi Collapse = 5410 psi Top of MPS-41 7" Casing Stub @ 4275' MD MPS-41 P&A'd 7" L-80 Casing TD: 5077' \ 8-1/2" Hole DATE 12/15/2008 Ugnu Horizontal 8-1/2" Hole REV. BY COMMENTS REH MPS-41 Pilot hole & Horizontal Sidetrack BP EXPLORATION (AK) MPU S-41A HES 9 5/8" RBP with 27' 3950` of sand dumped ontop 7" x 9-5/8" C-2 ZXP 3968' Liner Top Pkr. Casing Seal Receptacle and Locator seal Assembly MPS-41 Open Hole Sidetrack 7" 29# slotted liner from 5590' - 6226' 6800' - 7603 Z 26# solid liner 3995' - 5590' 6226' - 6800' 7" Liner Shoe @ 7605' MD Well Inclination @ shoe = 90 degrees MILNE POINT UNIT WELL #: MPS-41A API NO: 50-029-23401-01-00 ,y~- MPS-4 Drive Head: Grenco D2100, 60 h'~J' 8" Motor sheave, 14" Drive Sheave Production Flow Tee: FMC 11" 5M x 4-1116" 5M top and outlet flanges wellhead: 11" x 4 1/2" FMC Gen 6 Tubing Hanger with 3 ports. 20" welded/insulated, 1 ~~ 91.1 ppf, H-40 Heat Trace Cable to 3500' clamped in channel with cap- tu be 4.5" 12.6# L80 Hydril SC 563 Boronized joint at 4100' XO to 3-1 /2" 9.3# Hyd 563 at 4740' 3-1/" Boronized ~u~joint above PCP 7" ZXP Liner top packer 3967' 9-5/8" 47#/ft., L-80 BTC 4165` Rod Shear, 30K # 4100' 1-1/8" SER Co-rod, 2000ft-Ib torque rating Proposed Orig. Elev. = 71.88` (D-14) Orig. lev. = 38.10' (D-14) DF to ~g Spool = 32.61` (D-14) Pdlshed rod 1.5" OD x 40' long - 0.433' TEC Wlre 4-1/2" NDPG career 2000` (tubing P/T) 3/8" SS cap-tub to KBMG-LTS 3800` CM-40R-BK Insert PS nipple,3.81" ID 4120` Tubing drain shear at Pt=4000psi 4200` 4740` 4750` NDPG (annular P/T) NDPG (tubing P/T) 220-5100 PCP, 1.74" ID, 21' XXXL rotor 4782` ~ blank tag sub,1.995" ID 7" Solid Liner Slotted (1/8") liner 4000'-4800' 4800-4880 4880-5250 5250'250 6250'-6800' 6800'-7600' ***No McOH or Diesel in well due to risk of swelling elastomer in pump stator**'' 7" Slotted (1/8") liner (PBTD) 7605` 4805` 3.5" 9.3# STC tail-pipe NDPG carrier (tubing ~ T 5100` self-aligning muleshc:-~ Tbg capacity: 65 BBL IA capacity: 85 BBL (to pump) DATE REV. BY COMMENTS MILNE POINT UNIT 2/1/10 J.Young Proposed, post peer review WELL MPS-41 API NO. 50-029-234010-00 ,..,,1 ,- - 4 ' -'~, q nw.. STATE OF ALASKA ALASKA~AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS a~)~`i 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated er 0 'inspect we I ~ • Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ . Exploratory r 206-1610 3. Address: P.O. Box 196612 Stratigraphic r Service (~ 6. API Number: Anchorage, AK 99519-6612 50-029-23401-01-00 7. KB Elevation (ft): 9. Well Name and Number: 71.53 KB MPS-41A 8. Property Designation: 10. Field/Pool(s): ADLO-380110 Milne Point Field/ Ugnu Pool 11. Present Well Condition Summary: Total Depth measured 7605 feet Plugs (measured) 3950' true vertical 3807.48 feet Junk (measured) None Effective Depth measured 7605 feet true vertical 3807.48 feet Casing Length Size MD TVD Burst Collapse Conductor 120' 20" 92# H-40 Surface - 120' Surface - 120' Surface 4104' 9-5/8" 47# L-80 36' - 4140' 36' - 3424' 6870 4760 SL Liner 3637' 7" 26# L-80 3968' - 7605' 3385' - 3807' 7240 5410 Perforation depth: Measured depth: SL 5590-6227 SL 6801-7562 _ _ True Vertical depth: 3768 - 3766 3779 - 3808 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 KILL STRING SURFACE - 2153' 0 0 - Packers and SSSV (type and measured depth) 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: n/a Subsequent to operation: n/a 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory (~ Development r • Service Ir Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ ' Gas r WAG r GINJ r WINJ ~ WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 8/27/2009 Form 10-404 Revised 04/2006 ~ ~ Submit Original Only Milne Point Well S-41A, PTD 2081610 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Milne Point well MPS-41A on 7/28/09. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition, signed by the witnessing AOGCC inspector • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one-quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • MPS-41A was suspended on 12/17/08. • MPS-41A is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with a RBP at 3950 ft MD with 27 ft of sand placed on top. • The well is mechanically sound as proven by pressure tests after the RPB was set. Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: MPS-41A FieldlPool: Milne Point / Kuparuk River Oil Permit#(PTD): zoo/~io API Number: 50-029-23401-01-00 Operator: BP Exploration (Alaska) Inc Date Suspended: __ Surface Location: Section: Twsp: Range: Nearest active pad or road: Milne Point Unit S-Pad _._______ Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Active pad, well maintained Pad or location surface: Clean gravel Location cleanup needed: No Pits condition: Good Surrounding area condition: Good Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: None Samples taken: N/A Access road condition: Good, well maintained Photographs taken (# and description): 7 pictures of wellhead and location Condition of Wellhead AOGCC requires: 1 } a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC wellhead with a 4-1/16" CIW dry hole tree installed Cellar description, condition, fluids: Rainwater Rat Hole: None Wellhouse or protective barriers: Portable temporary drilling scaffolding Well identification sign: Yes Tubing Pressure (or casing if no tubing): Slight vacuum Annulus pressures: lA =Positive pressure OA =Positive pressure Wellhead Photos taken (# and description): 7 pictures of wellhead and location Work Required: None Operator Rep (name and signa ur ~ ~ - ~ - e AOGCC Inspector: U . Other Observers: Inspection Date: 7/28/200 AOGCC Notice Date: Time of arrival: Time of Departure: Site access method: Tree: Cameron 4-1/16" 5M Wellhead:FMC Gen 6 11"- SM Tubing head: 11" x 4-1/2", FMC tbg hanger 20" 92 Ib/ft, H-40 Welded 112' Insulated Csg. drift ID = 8.525", Csg. ID = 8.681" Burst= 6870 psi Collapse=4750 psi MPU S-41 A ~g• KB Elev. = 72' rig. GL Elev. = 38.1' 4-1/2", 12.6# L-80, IBT-M Coupling Drift ID: 3.833" Burst: 8,430 psi/ 80%= 6,000psi Capacity= .0152 bbl/ft 4-1/2" X Nipple 2110' 4-1/2" WLEG 2151 HES 9 5/8" RBP with 2T 3950' of sand dumped ontop 7" x 9-5/8" C-2 ZXP 3968` Liner Top Pkr. 9-5/8" Casing Shoe 4140' Casing Seal Receptacle and Locator seal Assembly 7" 26#, L-80, BTC- M Casing Csg drift ID = 6.151" Csg. ID = 6.276" Burst = 7240 psi Collapse = 5410 psi Top of MPS-41 7" Casings/~\~ Stub @ 4275' MD MPS-41 P&A'd, 7" L-80 Casing TD: 5077' \ 8-1/2" Hole MPS-41 Open Hole Sidetrack 7" 29# slotted liner from 5590' - 6226' 6800' - 7603 7" 26# solid liner 3995' - 5590' 6226' - 6800' 7" Liner Shoe @ 7605' MD Well Inclination @ shoe = 90 degrees Ugnu Horizontal 8-1/2" Hole DATE REV. BY COMMENTS MILNE POINT UNIT 12/15/2008 REH MPS-41 Pilot hole i~ Horizontal Sidetrack WELL #: MPS~41A API NO: 50-029-23401-01-00 BP EXPLORATION (AK) 22 23 P!~24 19 ~ ~ I PLANT Z ~ 15'00'00" GRID -~ MPS-43 MPS-41 ~ ~'~~~ ~i MPS-39 I ^ 37 ^ 35 ^ 34 ~Si ~ AS-BUILT CONDUCTOR ^ 311 ^ EXISTING CONDUCTOR ^ 30 ^ 29i ^ 28 ^ 27 ^ 26 ^ 25 ^ 24i ^ 23 ^ 22 ^ 211 ^ zo ^ 1si ~ SURVEYOR'S CERTIFICATE ~ ~16 I HEREBY CERTIFY THAT I AM ^ 1s ( PROPERLY REGISTERED AND LICENSED ^14 ^ 131 TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT ~i2 THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT ~ s~ SUPERVISION AND THAT ALL ^ a DIMENSIONS AND OTHER DETAILS ARE ~ ^ 71 CORRECT AS OF JULY 1, 2008. ^s ^~~ ^ 3 l V SECT'Z T Sf\ 1 Tlzry' R~ ^ I IE~ _, ^ SB-04 ^ I j I - _.-i 27 c-pA0 26 ~ 2s\ 1 I 30 °'r 29 35 I 36/ I \\ I 32 z 1 s ~p~~~~T 11 12 8 9 VICINITY MAP N.T.S. ~E °° A~q~ ~P° 0 F °°°°°°°°°°°°°°°°°°°°°°°°°°°°°° °°°°°°°°°°°°°°°°°°°°°°°°°°°°°° 'F~°°° Leonard J. O'Hanley ~~' ~s ° •d~11386 °°' ~~ c~ltJ~"' ~~ 1a ~ ~ - ~ ~ ~~ Qa -- -- -- -' 1 DATE OF SURVEY• JULY 1 2008. a~ It / - - - ~ MPU S-PAD 2. REFERENCE FIELD BOOK: MP08-03, PAGES 17-19. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 _ NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON BPX MPU S-PAD OPERATOR MONUMENTS S-EAST S-MID AND S-WEST. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. I !)('ATFII WITHIN PR(1TRAC'TFII SFC 1 ~ T 1 ~ N _ R_ 10 F.. UMIAT MERIDIAN. ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC ELLAR BO SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS Y=5,999,896.46 N= 2,237.09 70'24'36.598" 70.4101661' 37 78' 3,232' FSL MPS-39 X= 565,522.28 E= 6 384.91 149'27'59.307" 149.4664742' 489' FEL Y=5,999,888.58 N= 2,236.98 70'24'36.523" 70.4101453' 37 79 3,224' FSL MPS-41 X= 565,493.29 E= 6,354.86 149'28'00.159" 149.4667108' ' 518' FEL Y=5,999,880.83 N= 2,236.94 70'24'36.449" 70.4101247' 37 12' 3,217' FSL MPS-43 X= 565,464.52 E= 6,325.06 149'28'01.005" 149.4669458' 547' FEL ~: CHECKED: JZW Yr' b~ O ~ I, DATE: l UU I oRA~HN~: MILNE POINT UNIT S-PAD FR808 MPS 07-00 SHEET: ~~~OC~a ~aa No AS-BUILT CONDUCTORS SCALE 1 OF 1 0 7 2 O9 ISSUED FOR INFORMATION TFB JZW WELL 5-39, 5-41 & 5-43 N0. DATE RENSION BY CHK 1"= 16O' ~; .; a ,~,_ ._ ~: ~' Y~ ~_,. ~'F ~ ~~:a 4 ..''F ..: ~b~ .h ,P ^ '~ _ ~' ~ ~,~ k '~ 5i .~ 3 ~~+! Y 9 ~_ ~. ~~'~ i" ~G#'~` b " t ,_ ~'~ P a~~ ~S° '.F_ „' % ~ ^ ~~ -. ,.~.. '`~ +~~, ~ '' ~~M ~ ~ i~i,~~ ^ Cdr ~ b .44- iM ~'p P ,~' y~ f ~, . f ~,~; t ~x _ ~ y;,~ ~ ~ ~~ fad;. ~ ~~ __, ~ ~r ~ ~''~ ~ ~~ ~ ~~ ~ r r ~.w :,.~~~ g,# ,.y. .. f ,~ • _`` .,. ~~. '~~ '+ra4,.T~ ._ _ ____.a_ LEI''. { r ~" _:,AS~f s ti ,, Po" y x 5u `+..i~.: ,,, -. ' ~~~"3 6 ~~ ,err ~-de~.,t °'°~° M~n~ Ln-,~ i ~aa4 N, ~ ~M_ df-I~`~a.. z y~ ns ..,~ ..y¢ ~ ~ ;z'-' ~'.~ %;rt r tr~"' ~. -afi •9ti. ~~x' r.. - ,. ~ M1 m ~ „•~d Tir ~~lS'w ~ ,S.~+ih+r , ~., ~. ;+C.~ ~ ,~ ,,, 'r ~ x ~ ,.. , `. . ,r Y _.y 6~_ i _ ---,~ - ~ -~"'" ,< n,~. r~~%+*ti ~__-__ I `. _,~..;; :3~' "f+ I ~' • ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: August 1, 2009 P. I. Supervisor ~~~~ lUl ~3~~ 1 FROM: John Crisp, SUBJECT: Suspended Well Inspections Petroleum Inspector BPXA Milne Point Unit S-41A " PTD 2081610 August 1, 2009: I traveled to Milne Point Unit (MPU) with BPXA representative Mike Shoemake to inspect wellsite MPU S-41 A. This well is located on an active Drillsite. The area around MPU S-41A is the ., same as producing & injecting wells on the Drillsite. Guard rail has been placed around the well. All valves are opened to monitor casing and tubing pressures. MPU S-41A seems to meet regulation 20 AAC 25.110 for Suspended wells. Summary: Suspended well site Inspection performed on MPU S-41A. Attachments: Photo's & Operator Wellsite Inspection Form. • • MPU S-41A (BPXA) Suspended Well Inspection PTD 2081610 Photos by AOGCC Inspector J. Crisp August 1, 2009 MPU 5-41 A Suspended Well Inspection 8-1-09 • MPU S-41A Suspended Well Inspection 8-1-09 Suspended ell Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: MPS-41A Field/Pool: Milne Point / Kuparuk River Oil Permit # (PTD): 2U~~16 j © API Number: 50-029-23401-01-00 Operator: BP_Exploration LAlaska~Inc.. Date Suspended: _ -__ . Surface Location: Section: Twsp: Range: Nearest active pad or road: Milne Point Unit S-Pad _______ _ Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Active pad, well maintained ` Pad or location surface: Clean gravel Location cleanup needed: No Pits condition: Good _ . Surrounding area condition: Good Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: None - Samples taken: N/A _ _- _ _ _ _ Access road condition: Good, well,maintained Photographs taken (# and description): 7 pictures of wellhead and location Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC wellhead with a 4-1/16" CIW dry hole tree installed ' Cellar description, condition, fluids: Rainwater ___ __ ___ Rat Hole: None Wellhouse or protective barriers: Portable temporary drilling scaffolding Well identification sign: Yes __ _ _ . . Tubing Pressure (or casing if no tubing): Slight vacuum Annulus pressures: IA =Positive pressure OA =Positive pressure Wellhead Photos taken (# and description): 7 pictures of wellhead and location Work Required: None Operator Rep (name and sig AOGCC Inspector: Inspection Date: 7/28/201 Time of arrival: Site access method: ~C/~Rd/ C~I~CsttR~t° u , ' Other Observers: AOGCC Notice Date: _ _ ___ Time of Departure: llUC; liodyrage ~ rage i of ~ j 20_AAC 25,110._Sus ende_d_wells S~cj~ ~ a- j+~ `O (a) If allowed under 20 AAC 25.105 an operator may apply to the commission under this section to approve the suspension of a well or to renew the approval of the suspension of a well. The operator must state the reasons the well should be suspended, and not completed or abandoned, and must demonstrate to the commission's satisfaction that (1) the well (A) is mechanically sound; (B) will not allow the migration of fluids; (C) will not damage freshwater or producing or potentially producing formations; (D) will not impair the recovery of oil or gas; (E) is secure, safe, and not a threat to public health; and (F) is in compliance with all provisions of AS_ 31.05, this chapter, and any order, stipulation, or permit issued by the commission; (2) the well (A) has future utility as an exploratory, development, or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. (b) An Application for Sundry Approvals (Form 10-403) must be approved by the commission before operations to suspend a well commence, except that oral approval may be requested under 20 AAC 25.507 . In addition to meeting the requirements of (a) of this section, the application must include the following: (1) wellbore diagrams illustrating the current and proposed mechanical configurations of the well; (2) information on abnormally geo-pressured or depleted strata; (3) a description of the proposed work plan, including how the integrity of existing and proposed plugs will be demonstrated. (c) Unless the commission otherwise requires or approves a variance under 20 AAC 25.1120 ,any well suspended under this section must be plugged in accordance with 20 AAC 25_._112 except that the requirements of 20 AAC 25.1__12~d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and httn•//www leuicstate.ak.ns/hasis/f~li~nr~xv.asn?url=httn://www.le~is.state.ak.us/cai-bin/f... 8/31/2009 DOC BodyPage ~ Page 2 of $('~ (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface. (d) The operator of a suspended well shall maintain the integrity and safety of the well and surrounding location and clear the location in accordance with 20 AAC 25.170(a~ (2) or (b) or with 20 AAC 25_.172 (~ (2) or (d), as applicable. (e) For a well suspended before January 1, 2009, the o erator shall ins ect the well site before Septem er 010. For a well initially suspended on or after January 1, 2009, the operator shall inspect the well site within 12 months after the date of suspension. For a well suspended under this section, subsequent inspections shall be conducted within 24 months before September 30 of every calendar year ending in 0 or 5, except that a suspended well is not required to undergo a subsequent inspection under this subsection if the initial inspection under this subsection occurred within the prior 24-month period. For all inspections under this section, the operator shall provide the commission notice at least 10 days before the inspection and the opportunity for commission inspectors to accompany the operator on the inspection tour. If convenient for the commission, shorter notice periods may be accepted. (~ Within 30 days after any well-site inspection required under this section, including (e), (h), and (i) of this section, the operator shall file a Report of Sundry Well Operations (Form 10-404). The report must include (1) a description of the condition of the wellhead and surface location, including any discoloration, fluid or sheen visible on the ground or in any nearby water; ~/` (2) a plat showing the location of the suspended well and any wells within aone-quarter-mile radius of the wellbore; (3) well pressure readings, if practicable; f (4) photographs clearly showing the condition of the wellhead and surrounding location; and (5) an update of all information and documentation required in (b) of this section. (g) A suspension or renewal of a suspension approved on or after January 1, 2009 is valid for 10 years from the date of approval. (h) Renewal of an existing suspension may be requested by the submission of an Application for Sundry Approvals (Form 10-403) meeting all requirements of (b) of this section. A renewal is not effective until approved by the commission. If a complete renewal application is submitted at least 60 days before the expiration of an existing suspension, the existing suspension will continue until the commission acts on the application. Within 24 months before the submission of a request for suspension renewal, awell-site inspection must be completed. (i) For wells suspended before January 1, 2009, an Application for Sundry Approvals (Form 10-403) requestmg_a suspension renewal under (h) of this section must be submitted (1) no later than December 31, 2010 for all wells suspended before January 1, 2006; and (2) no later than December 31, 2015 for all wells suspended on or after January 1, 2006. Qi~~ i~nn4 DOC BodyPage . Yage j of 8 ~, (j) The operator shall immediately notify the commission and propose appropriate action if the operator learns that there is a reasonable risk that a suspended well is (1) mechanically unsound; (2) allowing the migration of fluids; (3) causing damage to freshwater or producing or potentially producing formations; (4) impairing the recovery of oil or gas; (5) a threat to public health or not secure or safe; or (6) not in compliance with all provisions of AS 3.1_.0.5,. this chapter, and any order, stipulation, or permit issued by the commission. (k) within five working days after notifying the commission under (j) of this section, the operator shall file a report and all relevant information and documentation regarding the well, including all information and documentation that may be required by the commission. (~ If the operator learns that any information required under this section is no longer complete or accurate, the operator shall, within 30 days, notify the commission in writing, provide updated information, and propose appropriate action. (m) At any time, the commission may request that an operator provide, within 10 days after the date of request, any information concerning whether suspension remains appropriate for a well. If the operator does not comply with the information request or if the commission determines that information is insufficient to support allowing the well to remain suspended, the commission may take action under 20 AAC 25,.540 including (1) revoking the well's suspended status, effective as of the date determined by the commission, and (2) prescribing actions the operator must take, which may include plugging and abandonment of the well; if action is ordered, including plugging and abandonment under this chapter, a separate notice and hearing is not required notwithstanding any other provision of this chapter, including 20 AAC 25.105,. (n) Upon written request of the operator, the commission may modify a deadline in this section upon a showing of good cause. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am 11/19/2008, Register 188 Authority: AS 31.05.030 AS 31.05,.040 AS 31.05.095 20 AAC 25_.112._ We11_~u~gi~ requirements httr~•/lansnz~ 1PlT10 ctatc~ olr nc/hacie/fnlinrrnvv acn~nrl=~lttY1•//VV~x7R7 lPaic etatP ak nc/cai-hin/f R/~1 /~nnA ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPS-41A+PB1+PB2 February 19, 2009 AK-MW-6150038 MPS-41A+PB1+PB2: 2" x 5" MD Triple Combo Logs: 1 Color Logs 5 0-029-23 401-01, 70, 71 2" x 5" TVD Triple Combo Logs: 1 Color Logs 50-029-23401-01,70,71 Digital Log Images: 1 CD Rom 50-029-23401-01,70,71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED CQPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 t~i~ , on.com Date:' ~ z~ f=' ~~" ' Signed: ~ ~`~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data MPS-41A 1 LIS formatted CD with verification listing. API#: 50-029-23401-0 l February 19, 2009 AK-MW-6150038 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Off ce: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda a~alliburton.com ,~ Date:_ -, BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Signed: ~~ ~p~-!~ 1 t~~~ WELL LOG TRA1~iSMITTAL • To: State of Alaska February 19, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data MPS-41A PB1 AK-MW-6150038 1 LIS formatted CD with verification listing. API#: 50-029-23401-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com ,~ . , Date: ,-~ ,, -~ ..a _} H ~. .. .. J ~j~ -~~ Signed: f ~ ~ -~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska February 19, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data MPS-41A PB2 AK-MW-6150038 1 LIS formatted CD with verification listing. API#: 50-029-23401-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 ~_ ;~ ~x~` ;~; ~,~ ~ ~M~ Date ~~'~~' ~,]~,q> ~° ~ > ~ °~ Signed: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com ~. ~~~-~~o ~ 1~ C°~~ • HALLIBURTON Drilling and Formation Evaluation State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-41A Dear Christine Mahnken 10-Feb-09 Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 5,352.28' MD Window /Kickoff Survey 5,390.00' MD (if applicable) Projected Survey: 7,605.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center 900 E. Benson Blvd. Anchorage, AK 99508 Date ~ ~- ~~ ~~ LR2-1 Signed (An a-mail confirmation, citing the well, to James.Durand@Halliburton.com would be an additional courtesy.) Please call me at 273-3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) • • HALL.IBURTON Drilling and Formation Evaluation State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-41APB1 Dear Christine Mahnken 10-Feb-09 Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 4,140.00' MD Window /Kickoff Survey 4,145.00' MD (if applicable) Projected Survey: 6,055.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 _ Date o~ 't.`~~ ~~®f Signed (An a-mail confirmation, citing the well, to James.Durand@Halliburton.com would be an additional courtesy.) Please call me at 273-3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) • • HALLIBURTON Drilling and Formation Evaluation State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-41APB2 Dear Christine Mahnken 10-Feb-09 Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey Projected Survey 5,446.22' MD 5,515.00' MD (if applicable) 6,147.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center 900 E. Benson Blvd. Anchorage, AK 99508 LR2-1 t ~~~ Date l ~ ~..~., ~~1 Signed _ (An a-mail confirmation, citing the well, to James.Durand@Halliburton.com would be an additional courtesy.) Please call me at 273-3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) MPS-43 PTD correction (PTD.#?08-176) ~ Page 1 of 3 Maunder, Thomas E (DOA) From: Hanson, Paul [Paul.Hanson1@bp.com] Sent: Monday, February 09, 2009 2:05 PM To: Maunder, Thomas E (DOA) Cc: Crane, Lowell R; Kara, Danny T; Engel, Harry R Subject: MPS-41 (208-159) and MPS-41A (208-161) "1:'ozn< As I indicated on Friday, here is my response to your ingixiry of last: Thursday. 1. Was the surface casing reciprocated while cementing? PU and SO weight is given for circulating the last joint down, but I don't find any mention of moving pipe thereafter. "I`l~e casing was landed can a tnanclrel hsulgcr. I~hus it vti-•as not moved during the cement job. 2. Was it intended to cut the 9-5/8" cement volume so "close"? l~?o, it vas not planned to be so close. 1 planned I St?`% excess t(~rough the permafrost and 4()% excess for the remainder. r~ lesson. leanled from ~~IPS-l surface hole ~~;-as the lolloti~~ing: Because of the DLS<4 degreesf100' constraint for running a co-rod pump, we spent more time than anticipated - both wiping out doglegs and trying to drill the line. ttVe achieved our objective; however, the net result was a more washed out hole than was anticipated. So on MPS-43 and 39 we increased the excess to 200% across the permafrost. ~l.hus, u-e pumped. enough cerne:nt......but just enough. 3. For running the 7" liner, were the 7" rams tested? Also, were the 2-7/8" x 5" tested on 2-7/8" for the inner string? It is stated on the report of the BOP test on12/6 that both rams were tested with 5" and 4- 1/2" test joints. It appears that you all planned accordingly to have the BOP equipped with rams to cover all the tubular combinations. I look forward to your reply. Call or message with any questions. ~L'e did plan accordingly, and did have rams f~-1i2" x 7" and 2-7/8`° x 5" ~BRs) that c~~uld test against 7" artd 2-7i'8" pipe. l lotivever, eve did not actually test the rams against 7" and 2-7%8" pipe or test ;oin.t . ".I`l~is tiv°as an lznforturiate oversight anal I lave in.E'orsned c7ur management team. ~~'e `~~ill ta)e tl~e olloz~~ing actic-ans to cYisure ful! compliaxice with tl~e regulations. - {`on~municate t11is incident across AI:)y~' operations anti in c>ur K:nc~~~-ledge IG•1~u~agementJlsessons Learned system - Specify ram sizes that require testing for each test cycle in every Fell Plan - .Include appropriate I3()I'1: testing. requirements in cacl~ plan forward docuntcnt generated by the ~~'ellsite Leaders IfycBu have any questions or concerns, please let me kr~o~v - esl-secially ~vitl~ regard to to our rniti<atioz~ me;asut•es fir cli~estion 3 alx~~re regarding I301'l~; testing. Sincerely, Paul Flanson 2/9/2009 MPS-43 PTD correction (PTD~08-176) ~ Page 2 of 3 From: Hanson, Paul Sent: Friday, February 06, 2009 5:13 PM To: 'Maunder, Thomas E (DOA)' Subject: FW: MPS-41 (208-159) and MPS-41A (208-161) Tom, I just wanted you to know that your inquiry below was forwarded to the wrong Paul Hanson in our address book. The Paul J Hanson listed below works in London, and he forwarded to me last night. I've been in meetings most of the day and only started sorting this out this afternoon. I will provide you with a complete response on Monday. Best Regards; Paul From: Hanson, Paul J Sent: Thursday, February 05, 2009 10:54 PM To: Hanson, Paul Subject: FW: MPS-41 (208-159) and MPS-41A (208-161) From: McLellan, Bryan J Sent: 05 February 2009 19:50 To: Hanson, Paul J Cc: Stewman, Sondra D; Maunder, Thomas E (DOA) Subject: FW: MPS-41 (208-159) and MPS-41A (208-161) Paul, Please see Tom's note below. I think his questions are meant for you. Bryan From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 05, 2009 9:23 AM To: McLellan, Bryan J Cc: Stewman, Sondra D; Regg, James B (DOA) Subject: MPS-41 (208-159) and MPS-41A (208-161) Bryan, I am reviewing the 407 recently submitted for these wells. 1. Was the surface casing reciprocated while cementing? PU and SO weight is given for circulating the last joint down, but I don't find any mention of moving pipe thereafter. 2. Was it intended to cut the 9-5/8" cement volume so "close"? 3. For running the 7" liner, were the 7" rams tested? Also, were the 2-7/8" x 5" tested on 2-7/8" for the inner string? It is stated on the report of the BOP test onl2/6 that both rams were tested with 5" and 4- 1/2" test joints. It appears that you all planned accordingly to have the BOP equipped with rams to cover all the tubular combinations. I look forward to your reply. Call or message with any questions. Tom Maunder, PE 2/9/2009 STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COM SION R~CE'vE®~.? WELL COMPLETION OR RECOMPLETION REPORT AND LOG JAN ~ ~ 20Q9 Alaska Oii & Gas Cons. ~;nmr»icc~nr, 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended 20AAC 25.105 2oAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well CIp1~~Ofal!~~gg,, ®Development "LJ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/17/2008 12. Permit to Drill Number 208-161 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/07/2008 ~ 13. API Number 50-029-23401-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/12/2008 14. Well Name and Number: MPS-41 A FEL, SEC. 12, T12N, R10E, UM 3224 FSL, 518 Top of Productive Horizon: 4559' FNL, 2629' FEL, SEC. 07, T12N, R11 E, UM 8. KB (ft above MSL): 71.53' Ground (ft MSL): 37.79' 15. Field /Pool(s): Milne Point Unit / Ugnu Total Depth: 4502' FNL, 1356' FEL, SEC. 07, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 7605' 3807' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 565493 y- 5999889 Zone- ASP4 10. Total Depth (MD+TVD) 7605' ~ 3807' 16. Property Designation: ADL 380110 TPI: x- 568196 y- 5997410 Zone- ASP4 - 5997478 Zone- ASP4 th: x- 569469 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No mi I r nic n Tint d inf rm i n r AAC 25.0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR / RES, DEN ! NEU w/ACAL, IFR / CASANDRA 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED -4 rf 1 rf 6 x A i r x. / 4' - " 7" 7 8' T -1 n m n r 23. Open to production or inject ion? ®Yes ^ No 24. Tuawc RECORD If Yes, list each i MD+TVD m P f T & B tt nterval open n Size and Number): rf r ti SIZE DEPTH .SET MD PACKER SET MD ; ( o op o o e o a o L-80 Slotted Liner 7" 29# 4-1/2", 12.6#, L-80 (Kill String) 2153' None , , MD TVD MD TVD 6227 3768' 3766' 5590' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - - 6801' - 7562' 3779' - 3808' DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED Freeze Protected with 14 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PfesS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. Y None ~` ~'~ r E~ ~} 4 2-J09 i ((4 FOrm 10-407 Revised 02/2007 CONTINUED ON REVERSE .SIDE s r '. ~a~s .~ ~~1 l 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top 37 79' 37 79 If yes, list intervals and formations tested, briefly summarizing test . . results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1451' 1435' detailed test information per 20 AAC 25.071. M87S 4473' 3632' None M87F 4721' 3717' M80T 4789' 3735' M80T 6324' 3765' M80T 6774' 3777' Formation at Total Depth (Name): Ugnu / M80T 4789' 3735' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certi for in is true a orrect to the best of my knowledge. Signed S F ra Stewman Title Drilling Technologist Date (~ ~ 1~- MPS-41A 208-161 Prepared ByNameMumber. Sondra Stewman, 564-4750 Well Number P Drilling Engineer: Paul Hanson, 564-4195 INSTRUCTIONS GENeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation 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. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 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 02/2007 Submit Original Only Tree: Cameron 4-1/16" 5M Wellhead:FMC Gen 6 11"- 5M Tubing head: 11" x 4-1/2", FMC tbg hanger 20" 92 Ib/ft, H-40 Welded 112' Insulated 9 5/8" 47#, L-80, BTC Csg. drift ID = 8.525", Csg. ID = 8.681" Burst= 6870 psi Collapse=4750 psi 4-1/2", 12.6# L-80, IBT-M Coupling Drift ID: 3.833" Burst: 8,430 psi/ 80%= 6,000psi Capacity= .0152 bbl/ft 4-1/2" X Nipple 2110` 4-1/2" WLEG 2151' 9-5/8" Casing Shoe 4140' 7" 26#, L-80, BTC- M Casing Csg drift ID = 6.151" Csg. ID = 6.276" Burst = 7240 psi Collapse = 5410 psi Top of MPS-41 7" Casing Stub @ 4275' MD MPS-41 P&A'd 7" L-80 Casing TD: 5077' \ 8-1/2" Hole DATE 12/15/2008 Ugnu Horizontal 8-1/2" Hole ~ REV. BY COMMENTS REH MPS-41 Pilot hole & Horizontal Sidetrack MILNE POINT UNIT WELL #: MPS-41A API NO: 50-029-23401-01-00 M P U S-41 A '" Orig. KB Elev. = 72` Orig. GL Elev. = 38.1' p o ~ ~,~ ~ HES 9 5/8" RBP with 27` 3950` of sand dumped ontop 7" x 9-5/8" C-2 ZXP 3968' Liner Top Pkr. Casing Seal Receptacle and Locator seal Assembly MPS-41 Open Hole Sidetrack 7" 29# slotted liner from 5590' - 6226' 6800' - 7603 7" 26# solid liner 3995' - 5590' 6226' - 6800' 7" Liner Shoe @ 7605' MD Well Inclination @ shoe = 90 degrees BP EXPLORATION (AK) ~ ~ gp Page 1 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: I :Date ;From - To Hours Task Code NPT Phase. i, Description of Operations 11/5/2008 16:00 - 17:30 1.50 MOB P PRE Blow Down lines on Rig Floor. -Prep Floor to skid. 17:30 - 18:30 1.00 MOB P PRE Skid Rig Floor to MOB Position. 18:30 - 20:30 2.00 MOB P PRE Move Rig off of well. -Spot rig by entrance of L pad. 20:30 - 21:00 0.50 MOB P PRE Prep Cellar for Move: -Remove Heaters. -Remove Mouse Hole. -Remove Doors from Cellar. 21:00 - 22:00 1.00 MOB P PRE Prep Cellar for Move: -Install Boosters. 22:00 - 00:00 2.00 MOB P PRE Moving Rig: -Move rig from L pad to V Pad. 11/6/2008 00:00 - 04:00 4.00 MOB P PRE Continue Moving Rig from L-Pad. -Move rig from V pad to Milne point turn off. 04:00 - 08:30 4.50 MOB P PRE Move Rig from MPU turn off to S-pad. 08:30 - 10:30 2.00 MOB P PRE Spot rig on MPS Pad. -Remove rear Booster Tires. -Set Rig Mats around Well. 10:30 - 12:00 1.50 MOB P PRE Spot Rig over MPS 41 Well. -Shim Rig in Place. 12:00 - 13:00 1.00 MOB P PRE PJSM for Skidding Rig Floor. -Skid Rig Floor to Drilling Position. 13:00 - 15:30 2.50 RIGU P PRE RU Rig Floor. -Hook Up Conveyor. 15:30 - 19:00 3.50 RIGU P PRE Install Surface Stack. -Install 4" Valves on Conductor. -Install Mouse Hole. -Install Cellar Doors. -Prepare Pits for Mud. Offload Spud Mud into Pits. -Accept rig ~ 16:00 hrs. 19:00 - 22:00 3.00 RIGU P PRE Inspect Derrick and Top Drive. -Change Saver Sub on Top Drive to 4-1/2" IF. -Change Screens on Shaker (125, 100 mesh). -Send Riser to Welding Shop to have shortened by 3'. 22:00 - 00:00 2.00 RIGU P PRE Install Riser and Turn Buckles. -Install Flow Line and Flow Line covers. 11/7/2008 00:00 - 00:30 0.50 RIGU P PRE Install Turn buckles on Riser. 00:30 - 02:30 2.00 RIGU P PRE Install Diverter Line in Cellar. 02:30 - 12:00 9.50 RIGU P PRE Load in Pipe Shed: -5" HWDP. -8" Non-Mag DC's. -5" DP. 12:00 - 14:00 2.00 RIGU P PRE All crews go to camp for MPU ATP meeting. -Motor man left on Rig. 14:00 - 14:30 0.50 RIGU P PRE Service Rig. Inspect derrick. -PJSM on PU 5" DP. 14:30 - 20:00 5.50 RIGU P PRE PU 5" DP from pipe shed 1 X 1. -Rack back 48 Stds of DP. 20:00 - 20:30 0.50 RIGU P PRE Diverter Function test: -Knife Valve on Diverter Line - 2 secs for Knife to full open. -29 seconds for Hydril to Close. -20" MSP 2000 Hydril - PflntBtl: 12/3020013 1'L:34:11 PM ~ ~ gp Page 2 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ', Code NPT Phase Description of Operations - - ~ ___ - - 11/7/2008 20:00 - 20:30 0.50 RIGU P PRE -Accumulator: 200 psi increase = 32 secs. -Full pressure 2 min. 39 secs. -4 bottles 2200 psi. AOGCC test witness waived by Bob Noble. 20:30 - 21:30 1.00 RIGU P PRE PU HWDP. -Hole Clear to 90' md. -PU Jars, Non Mag DC's, Rack Back in Derrick. 21:30 - 00:00 2.50 RIGU P PRE MOB BHA to Rig Floor. -Clear Floor of all Tools not needed. -RU Gyro Equipment. 11/8/2008 00:00 - 01:00 1.00 RIGU P PRE Continue to RU Gyro Equipment. 01:00 - 02:30 1.50 RIGU P PRE PU BHA #1 -MU 12.25" Bit. -PU Motor. Load Batteries in ABI. -MU Float Sub, UBHO and Orient. -MU 1 Stand HWDP. 02:30 - 03:00 0.50 RIGU P SURF Hold Pre Spud Meeting with Crew. -Fill Stack and check for Leaks. 03:00 - 05:00 2.00 DRILL P SURF Spud in ~ 03:00 hrs. -Drill 1 Stand down. -RU and Run Gyro. -Drill second stand down to 230' md. -Pump Rate of 504 gpm @ 800 psi. 05:00 - 07:00 2.00 DRILL P SURF Continue drilling ahead....from 230' to 316' and -Gyro as needed from 112' to 316' and 07:00 - 07:30 0.50 DRILL P SURF POH stand back HWDP. 07:30 - 10:00 2.50 DRILL P SURF PU & MU MWD tools. 10:00 - 11:00 1.00 DRILL N RREP SURF Replace cable on skate. 11:00 - 12:00 1.00 DRILL P SURF Continue to MU MWD tools. 12:00 - 15:00 3.00 DRILL P SURF MU: TM, UBHO sub. -Upload MWD. PU 1 NM Flex collar. -PJSM on Nukes -Load Nukes. -PU: 2 NM Flex collars, XO, 1 Std HWDP. -Shallow pulse test MWD. Set MWD depth. 15:00 - 00:00 9.00 DRILL P SURF Set Block height f/ MWD. -Drill f/ 316' to 900' md. -PUW 101 k, SOW 98k, ROT wt 100k, -462 gpm / 1260 psi. ART - 5.64 hrs AST - 1.55 hrs ADT - 7.19 hrs 11/9/2008 00:00 - 05:00 5.00 DRILL P SURF Continue to directionally drill 12 1/4" surface hole from 900' to 1,298' md. -PUW 103k, SOW 101 k, ROT wt 103k, gpm 405 / 1550 psi on Btm. -1390 psi off Btm, 2-5k Tq ~ 80 RPM, WOB 25k. 05:00 - 12:00 7.00 DRILL P SURF Continue to directionally drill ahead. -Drill from 1,298' to 1,815' md. -PUW 117k, SOW 112k, Rot wt 115k. -GPM 500 / 1940 psi on, 1720 psi off. -Tq 2k on, Tq 2k off ~ 80 RPM, WOB 25k. Printetl: 12/30/2008 12::14:11 Pnn g p Page 3 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~~ Task ~ Code II NPT Phase Description of Operations 11/9/2008 05:00 - 12:00 7.00 DRILL P SURF AST - 2.48 hrs. ART - 3.4 hrs. ADT - 5.88 hrs. 12:00 - 15:30 3.50 DRILL P SURF Directionally drill from 1,815' to 2,265' md. -PUW 123k, SOW 114k, ROT wt 120k. -GPM 500 / 1700 psi on, 1680 psi off. -Tq 3k on, Tq 2k off ~ 80 RPM, WOB 25k. -Increase pump rate to: -550 gpm w/ 2000 psi on & 1950 psi off. 15:30 - 16:30 1.00 DRILL P SURF Circulate bottoms up X 2. -550 gpm / 1930 psi. -MW in = 9.4 ppg. MW out = 9.45 ppg. 16:30 - 18:00 1.50 DRILL P SURF Pump out of the hole ~ Drlg rate. -550 gpm / 1900 psi. 18:00 - 19:00 1.00 DRILL P SURF RIH from 759'to 2,172' md. -Wash down from 2,175' to 2,265' md. -No fill noted. 19:00 - 00:00 5.00 DRILL P SURF Drill ahead from 2,265' to 2,551' md. -PUW 131 k, SOW 115k, ROT wt 127k. -GPM 550 / 1890 psi on, 1840 psi off. -Tq 4k on, Tq 3k off ~ 80 RPM, WOB 25k. AST - 1.58 hrs. Total daily AST - 4.06 hrs. ART - 1.1 hrs. Total daily ART - 4.5 hrs. ADT - 2.68 hrs. Total daily ADT - 8.56 hrs. 11/10/2008 00:00 - 05:00 5.00 DRILL P SURF Continue directionally drilling ahead. -Drill from 2,551' to 2,962' md. -PUW 135k, SOW 115k, ROT wt 125k. -GPM 550 / 2170 psi on, 1940 psi off. -Tq 5k on, Tq 3k off ~ 80 RPM, WOB 10-20k. 05:00 - 12:00 7.00 DRILL P SURF Continue directionally drilling ahead. -Drill from 2,962' and to 3,615' md. -PUW 145k, SOW 115k, ROT wt. 130k. -GPM 550 / 2,070 psi off, 2,230 psi on. -Tq 4k off / 6k on ~ 80 RPM. -WOB 15-20k. ART - 3.51 hrs. AST - 3.51 hrs. ADT - 7.02 hrs. 12:00 - 00:00 12.00 DRILL P SURF Continue directionally drilling ahead. -Drill from 3,615' and to 4,030' md. -PUW 150k, SOW 117k, ROT wt. 132k. -GPM 550 / 2,080 psi off, 2,140 psi on. -Tq 7k off / 9k on ~ 80 RPM. -WOB 15-20k. ART - 1.58 hrs. Total ART - 5.09 hrs. AST - 1.44 hrs. Total AST - 4.95 hrs. ADT - 3.02 hrs. Total ADT - 10.04 hrs. 11/11/2008 00:00 - 00:30 0.50 DRILL P SURF Continue directional drilling ahead. -Drill from 4,030' and to 4,052' md. rnmea: izi~uizuua u::w:n rnn ! ~ gp Page 4 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date i From - To Hours Task Code NPT Phase Description of Operations 11/11/2008 00:00 - 00:30 0.50 DRILL P SURF -PUW 150k, SOW 117k, ROT 134k. -GPM 550 2,070 psi off / 2,260 psi on. -RPM 80 ~ 6k off / 7-10k on. -WOB 30k. 00:30 - 02:00 1.50 DRILL P SURF Circulating BU for Samples. -Evaluate Logs. 02:00 - 03:00 1.00 DRILL P SURF Directional drill ahead to TD. -Drill from 4,052' and to 4,147' and (3,480'tvd) -PUW 150k, SOW 117k, ROT 135k. -GPM 550 ~ 2,100 psi off / 2,270 psi on. -RPM 80 ~ 7k off / 8-10 k on. -WOB 30k. ART - 0.23 hrs. Total ART - 16.48 hrs. AST - 0.67 hrs. Total AST - 12.46 hrs. ADT - 0.93 hrs. Total ADT - 28.94 hrs. 03:00 - 04:30 1.50 DRILL P SURF Circulating Hole clean. -Rotate @ 80 RPM, Reciprocate. -GPM 550 ~ 2,010 psi. 04:30 - 08:00 3.50 DRILL P SURF Pump out of hole. (From 4,146' and to 1,449' md) -GPM 550 ~ 2,000 psi. 08:00 - 11:00 3.00 DRILL P SURF Mad Pass from 1,449' and to 1,061' md. (Recorded) -180 FPH (~ 35 RPM. 11:00 - 11:30 0.50 DRILL P SURF Continue to pump out of hole. (From 1,061' and to 759' md). -GPM 550 ~ 2,000 psi. -Flow check well - No Flow. 11:30 - 13:30 2.00 DRILL P SURF RIH from 759' and to 4,054" md. -Wash down last stand from 4,054' and to 4,147' md. -GPM 450 ~ 1,530 psi. No problems. No fill observed. 13:30 - 15:00 1.50 DRILL P SURF Circulate 2 BU to clean hole. -GPM 450 ~ 1,530 psi. -Rotate and Reciprocate @ 90', RPM 60 - Torq 6k. 15:00 - 19:00 4.00 DRILL P SURF Pump out of Hole. (From 4,147' and to 759' md.) -GPM 450 ~ 1,400 psi. -Flow Check well - No Flow 19:00 - 23:30 4.50 DRILL P SURF LD BHA: -Rack Back SWDP, and Jars. -LD 2 Flex DC's. -PJSM on Nukes, Removed Nukes. -Download MWD. -LD Flex DC, TM, Nuke tool, RLL, DM, XO, Stab., Float Sub. -Drain Motor, Break Bit off and LD Motor. 23:30 - 00:00 0.50 DRILL P SURF Clean and Clear Rig Floor. 11/12/2008 00:00 - 00:30 0.50 DRILL P SURF Clear rig Floor of MWD Tools. 00:30 - 01:00 0.50 DRILL P SURF Lubricate Rig. -Inspect Top Drive. 01:00 - 03:00 2.00 CASE P SURF Rig Up to run 9-5/8" 47# L80 BTC-M CSG. -RU Franks Tool, Csg tongs. -RU Long bails, Slips. -PU Safety Valve. (9-5/8" X 1502 Swage w/full opening) 03:00 - 10:30 7.50 CASE P SURF Run 106 Jts. 9-5/8" 47# L80 BTC-M CSG. Printed: 12/30/2008 12:34:11 PM w gp Page 5 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/12/2008 03:00 - 10:30 7.50 CASE P SURF -Utilized Best-O-Life 2000 Thread Compound. -Run 1 straight Bladed Centrilizer on First 25 Jts. -Baker Lock all jts below Float Collar. -Fill every Jt w/ Franks tool. -Break Circulation every 25 Jts. -Circulate last jt. Down. C~? 210 gpm / 370 psi. -PUW 237k. SOW 150k. Noted tight spots C~ _2,400' and & -3,820' md. Circulate and wash through spots noted above. 10:30 - 11:00 0.50 CASE P SURF MU Hanger and Landing Jt. -Remove air slips. -Land Casing w/ Shoe C~ 4,140' md. 11:00 - 13:30 2.50 CASE P SURF Circulate hole Clean. -Stage up from 126 gpm to 336 gpm ~ 490 psi. -Condition Mud for Cement Job. Lower yP. 13:30 - 17:00 3.50 CEMT P SURF PJSM -Schlumberger pump 5 bbls water. -Test lines to 3,000 psi. -Pump 70.5 bbls 10 ppg Mud Push ~ 210 gpm / 150 psi. -Drop bottom plug. -Pump 436 bbls 10.7 ppg Lead (Deep CRETE) ~ 294 gpm / 230 psi. -Pump 45 bbls 12.0 ppg Tail (Deep CRETE) ~ 210 gpm / 260 psi. -Drop Top Plug. -Kick Plug out with 10 bbls water. -Schlumberger turned pumping over to rig. -Rig Pumped 283 bbls bumped plug ~ 126 gpm / 530 psi. -Pressure up to 1,500 psi for 10 min. (Charted). Good Test. -Check Floats. -CIP at 17:00 hrs. Received 12 bbls cement to surface. 17:00 - 20:30 3.50 CEMT P SURF PJSM -Flush Diverter X 3. -Clean Casing Tools. -LD Landing Jt. -LD Tools not needed. 20:30 - 00:00 3.50 DIVRTR P SURF PJSM - ND Diverter. -Remove Flow Line. -Remove Turnbuckles, Bleed off Line. -Remove Hole Fill Line. -LD Riser, ND Diverter Line, ND Accumulator Lines. -ND Diverter Spool. -Install Csg Speed Head, Tbg Spool. -Test Csg Speed Head Void to 1,000 psi. for 15 Min. Good Test. 11/13/2008 00:00 - 03:00 3.00 BOPSU P PROD1 NU Tubing Spool. -NU BOPE's. -Extend Choke Line. -NU Riser and Flow Line. 03:00 - 04:00 1.00 BOPSU P PROD1 RU to Test BOPE. -Install Test Plug. 04:00 - 11:00 7.00 BOPSU P PROD1 BOPE Test: Printed: 12/30/2008 12:34:11 PM • • gP Page 6 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours 'i Task ~ Code ! NPT Phase Description of Operations 11/13/2008 104:00 - 11:00 7.001 BOPSUFjP 11:00 - 11:30 0.50 BOPSU P 11:30 - 12:00 0.50 DRILL P 12:00 - 13:30 1.50 DRILL P 13:30 - 14:00 0.50 DRILL P 14:00 - 16:30 2.50 DRILL P 16:30 - 17:00 0.50 DRILL P 17:00 - 17:30 0.50 DRILL P 17:30 - 18:30 1.00 i CASE ~ P 18:30 - 21:30 3.001 DRILL ~ P 21:30 - 23:00 I 1.501 DRILL I P PROD1 -PJSM for testing BOPE's. -Begin testing BOPE's. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test Hydril w/ 5" test jt. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test choke valve #7. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Top & bottom Rams w/ 5" test joint. -All tests are a Pass. Accumulator: -33 seconds for 200 psi increase. -2 minutes 45 seconds for full pressure. -Bottles 4 X 2200 psi. -Test witness waived by John Crisp AOGCC. -Test witnessed by Well Site Leaders. PROD1 RD test equipment. -Pull test plug. PROD1 Install Wear ring. PRODi RD Floor Valves. -Install Bails and Elevators. -MOB BHA to Rig Floor. PROD1 MU BHA, Blt, Bit Sub, Float Sub. -PU 3 NMDC's, SWDP, and Jars. PROD1 PU DP 5" DP from pipe shed. -PU 1X1 for 7 Stds. RIH f/ derrick to 4,051' and . -Fill pipe ~ 2,531' md. PRODi Circulate BU ~ 4,051' md. -GPM 411 ~ 460 psi. PROD1 Mouse hole 1 jt of 5" DP. -Blow down Top Drive. -RU to Test Csg. PRODi Test 9 5/8" 47# L-80 BTC-M Csg. -Fill lines. -Test Csg to 2,500 psi for 30 min. (Charted) Good Test. -RD Test Equipment. PROD1 Slip and Cut Drilling Line: -PJSM for Slip and Cut. -Cut 1,600' of Drilling Line. PROD1 Drill Float equipment. -Drill from 4,058' and to 4,140' md. -Drill out Float collar, Shoe & 20' of new hole to 4,167' md. Printed: t2/30/ZOUS PL:34:11 F'M gp Page 7 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task '~, Code NPT Phase Description of Operations 11/13/2008 21:30 - 23:00 1.50 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 11/14/2008 00:00 - 01:30 1.50 DRILL P PROD1 01:30 - 02:30 1.00 DRILL P PROD1 02:30 - 04:00 1.501 DRILL P PROD1 04:00 - 04:30 0.501 DRILL P PROD1 04:30 - 07:30 3.00 DRILL P PROD1 07:30 - 08:00 0.50 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 12:30 3.50 DRILL P PROD1 12:30 - 13:00 0.50 DRILL P PROD1 13:00 - 15:00 2.00 DRILL P PROD1 15:00 - 15:30 0.50 DRILL. P PROD1 15:30 - 16:00 0.50 DRILL N DFAL PROD1 16:00 - 16:30 0.50 DRILL N DFAL PROD1 16:30 - 18:00 1.50 DRILL N DFAL PROD1 18:00 - 18:30 0.50 DRILL N DFAL PRODi 18:30 - 19:00 0.50 DRILL N DFAL PROD1 19:00 - 20:30 1.50 DRILL N DFAL PROD1 20:30 - 23:00 2.50 DRILL N DFAL PROD1 23:00 - 23:30 0.50 DRILL N DFAL PROD1 -PUW 145k, SOW 110k, ROT wt 125k. -420 gpm / 500 psi. Tq 7k ~ 80 RPM. Circulate hole clean. Rotate & reciprocate. -420 gpm / 510 psi. Displace to 9.4 ppg Bland coring fluid. -420 gpm / 680 psi. -Reciprocate & rotate during displacement. Stand back 1 Std. RU test equipment to perform LOT ~ 3 SPM. -760 psi leak off pressure w/ 9.4 ppg mud ~ 3,480 TVD. -EMW= 13.6 ppg. RD test equipment. Drill ahead from 4,167' to 4,265' md. -PUW 140k, SOW 100k, ROT wt 120k. -450 gpm / 920 psi off / 1040 psi on. -Tq 7k ~ 80 rpm. WOB 25k. Circulate hole clean 450 gpm / 920 psi. -Monitor well -Static. -MW in 9.4 ppg. MW out 9.4 ppg. POH w/ cleanout BHA on 5" DP. -LD BHA. Clean Rig Floor. MOB MWD tools to Rig Floor. -Hook Up Geo Skid. Service Rig: -Grease Blocks, Top Drive, and Draw works. PJSM for PU BHA. -MU BHA. Shallow Test MWD. -Pulse Test MWD. Good Test. RIH from 339' to 4,110' md. -Filled pipe ~ 2,321' md. Filled Pipe and check MWD. -No Pulse from MWD. -Trouble Shoot MWD. POH from 4,110' to 2,321' md. -Wet trip pipe. Test MWD. -Pulse Test MWD. No Good. POH from 2,321' to 339' md. -Wet trip Pipe. Test MWD. -Pulse Test MWD. Good Test. Rack Back 1 Stand SWDP. -Rack Back 1 Stand NMFC. Download MRIL. -PJSM on Nukes and Remove. -Download MWD. -LD MRIL, TM. -Replace Pulser. -MU TM, MRIL. MU float sub, Stabilizer, 1 Std NMFC, 1 Std SWDP. Pulse test MWD 550 gpm / 1350 psi. -Blow down Top Drive &Geo-Span. Pfiflt8tl: 12/:10/'LUUkf 1[::14:11 YM • BP Operations Summary Report Legal Well Name: MPS-41 Page 8 of 32 ~ Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: .Date From - To l Hours Task Code NPT Phase Description of Operations 11/14/2008 23:30 - 00:00 0.50 DRILL N DFAL PROD1 RIH w/Geo-pilot on 5" DP from 431' to 900' md. 11/15/2008 00:00 - 02:00 2.00 DRILL N DFAL PROD1 Continue to RIH f/ 900' to 4,155' md. 02:00 - 03:30 1.50 DRILL P 03:30 - 12:00 8.50 DRILL P 12:00 - 00:00 ~ 12.00 ~ DRILL ~ P 111/16/2008 (00:00 - 00:30 ( 0.501 DRILL ~ P 00:30 - 10:30 ~ 10.00 ~ DRILL ~ P 10:30 - 11:00 0.501 DRILL ~ P 11:00 - 12:30 ~ 1.50 ~ DRILL ~ P 12:30 - 13:30 I 1.001 DRILL I P -Pulse test MWD every 10 Stds. -PUW 115k, SOW 100k, ROT wt 115k. -Tq 5k ~ 10 RPM. PROD1 MU Top Drive. Wash down, Rotate f/ 4,155' to 4,266' md. -Tq 5-7 k ~ 10 RPM. PROD1 Directionally drill ahead from 4,266' to 4,667' md. -PUW 138k, SOW 103k, ROT wt 120k. -WOB 7-15k, Tq 6k ~ 120 RPM on Btm. -Tq off Btm 4-5k. 450 GPM. -Pressure on Btm 1720 psi, off Btm 1670 psi. ART - 7.68 hrs. PROD1 Directionally Drill ahead f/ 4,667' and to TD ~ 5,081' and / 4,075' tvd. -PUW 162k, SOW 114k, ROT wt 132k. -Tq on 7-9k, off 7k. 450 GPM. -Pressure on Btm 1,750 psi, off Btm 1,650 psi. ------------Formation Tops------------- -M80T = 4,572' md. -M80S = 4,808' md. -M70S = 4,890' md. -Nb = 4,940' md. ART - 10.52 hrs. Total daily ART = 18.20 hrs PROD1 Circulate /Geo discussion w/ Asset group. -440 gpm / 1540 psi. -Set Geo-pilot into home position. ------------Formation Tops------------ -M80T = 4,572' md. -M80S = 4,808' md. -M70S = 4,890' md. -Nb = 4,940' md. PROD1 Pump out of hole for MAD pass per geologist. -Pump out from 5,081' to 4,251' and -420 gpm / 1500 psi. -Rig crew perform hazard hunt. PROD1 Observe well -static. -RIH f/ 4,251' to 5,081' md. -PUW 165k, SOW 115k, ROT wt 135k. -Tq 5k ~ 50 RPM. PROD1 Condition Mud for logging. -Circulate two surface to surface volumes. -450 gpm / 1250 psi. PRODi Observe well -static. -Drop rabbit w/ wire. -Pump out of the hole f/ 5,081' to 4,110' md. rented: iusuieuu~s i~:s4:ii rnn ~ ~ BP Operations Summary Report Page 9 of 32 ~ Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date 'From- To i Hours Task Code NPT Phase. Description of Operations 11/16/2008 12:30 - 13:30 1.00 DRILL P PROD1 -400 gpm / 1080 psi. 13:30 - 14:00 0.50 DRILL P PROD1 CBU. Blow down Top Drive. -Observe well -static. 14:00 - 16:00 2.00 DRILL P PROD1 POH wet from 4,110' to BHA ~ 155' and 16:00 - 19:30 3.50 DRILL P PROD1 LD BHA: 19:30 - 21:00 1.50 DRILL P PROD1 21:00 - 00:00 3.00 DRILL P PROD1 11/17/2008 00:00 - 01:30 1.50 EVAL P PROD1 01:30 - 03:30 2.00 EVAL P PROD1 03:30 - 04:00 0.50 EVAL P PROD1 04:00 - 07:30 3.50 EVAL P PROD1 07:30 - 15:00 7.501 EVAL P PROD1 15:00 - 00:00 9.00 EVAL P PROD1 11/18/2008 00:00 - 12:00 12.00 EVAL P PROD1 12:00 - 00:00 12.00 EVAL P PROD1 11/19/2008 100:00 - 03:30 3.501 EVAL P PROD1 03:30 - 04:30 1.00 EVAL P PROD1 04:30 - 06:30 2.00 EVAL P PROD1 -LD Stab & Float sub. -Plug in MRIL tool. PJSM on nukes. -Remove nukes from tool. -Down load MW D. Flush BHA w/ water. -LD MRIL, TM, Nuke tool, HCIM, Smart stab, EWR. -LD Geo-Flex, Geo-pilot & Bit. -Rig crew perform hazard hunt. Clear Rig floor of all tools not needed for upcoming operations. -Clean Rig floor. PJSM. -PU SLB E-line tools to Rig floor. -MU Tools. PJSM... -DP conveyed Logs. Check wet head connection. MU XO. RIH w/ 5" DP from 167' to 3,815'. md. -Circulate every 1,000'. 126 gpm / 180 psi. Circulate pipe volume. -PU SLB E-line tools & equipment. PJSM... -RU sheaves. MU Side door entry sub. -Pump down Wet Head. Latch up. Secure cable in door. RIH w/ logging tools & 5" DP from 3,815' to 4,337' md. -Gather pressure readings from: -4,337', 4,350', 4,395', 4,499', 4,530', 4,555', 4,590', 4,605', -4,655', 4,670', 4,698', 4,715', 4,716', 4,790', 4,792', 4,830', -4,828', 4,854', 4,855.5'. ---all depths = md. -PUW 143k, SOW 112k. Begin sampling formation. -Formation Sample points 4,895' & 4,755' md. Continue Schlumberger taking MDT fluid samples w/ tools (~ 4,755' and 4696' md. -Rig crew continues to clean, scrub, paint and work on Rig. Continue Schlumberger taking MDT fluid samples w/ tools C~3 4,635' and 4628' md. -Rig crew continues to clean, scrub, paint and work on Rig. -Sampling ~ 4635' failed due to lost seal while sampling. Moved tools up to 4628' md. -PUW 140k /SOW 112k Continue Schlumberger taking MDT fluid samples w/ tools ~ 4628' md. -Take pressure values ~ 4610', 4600', 4595' and 4585' -Rig crew continues to clean, scrub, paint and work on Rig. POOH f/ 4585' to 3777', until side entry sub C~ rotary table. -RD side entry sub. -Pull off wet connector f/ head. Printed: 12/30/2008 12:34:11 PM • g F Page 10 of 32 ~ Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/19/2008 04:30 - 06:30 2.00 EVAL P PROD1 -Pull a-line out of drill pipe. -LD side entry sub and sheaves 06:30 - 08:00 1.50 EVAL P PROD1 Cont. POOH 5" DP w/ MDT logging assy. f/ 3777' to surface. 08:00 - 11:00 3.00 EVAL P PROD1 LD MDT logging assy. Clear rig floor 11:00 - 12:00 1.00 EVAL P PROD1 MU cleanout BHA w/ 8-1/2" tricone bit + 1 jt NMDC + Stabilizer + 2 jts NMDCs + 3 jts 5" HWDP +jars + 2 jts 5" HWDP. 12:00 - 12:30 0.50 EVAL P PROD1 Service top drive, blocks and drawworks. 12:30 - 14:30 2.00 EVAL P PRODi RIH w/ cleanout BHA to TD ~ 5081'. 14:30 - 16:00 I 1.501 EVAL P PROD1 16:00 - 17:00 1.00 EVAL P PROD1 17:00 - 17:30 0.50 EVAL P PROD1 17:30 - 19:00 1.50 EVAL P PROD1 19:00 - 20:00 1.00 EVAL P PRODi 20:00 - 20:30 0.50 EVAL P PROD1 20:30 - 22:30 2.00 EVAL P PROD1 22:30 - 00:00 1.50 EVAL P PROD1 11/20/2008 100:00 - 01:30 1.501 EVAL P PROD1 01:30 - 03:00 1.50 EVAL P PROD1 03:00 - 04:00 1.00 EVAL P PROD1 04:00 - 05:30 1.50 EVAL P PROD1 05:30 - 09:30 4.00 EVAL P PRODi 09:30 - 11:00 1.501 EVAL P PROD1 11:00 - 12:00 1.00 EVAL N DFAL PROD1 12:00 - 15:00 3.00 EVAL N DFAL PROD1 15:00 - 17:30 2.50 EVAL N DFAL PROD1 -Fill pipe ~ 2180' and 4140'. -Wash last stand to bottom. Circulate until hole clean. Rotate and reciprocate pipe while circulating. -110 RPM ~ 7k torque / ROTW 133k. -504 gpm ~ 890 psi. Pump out of the hole f/ 5081' to 4062' (inside 9-5/8" shoe). CBU. 546 gpm ~ 870 psi. -Blow down top drive -Flow check well. Cont. POOH f/ 4062' to 290' (BHA) -Rack Back HWDP and NMDCs. -LD Stabilizer, float sub, bit sub and bit. Clear rig floor of tools not needed for next operations. Clean rig floor. RU Schlumberger a-line equipment and logging tools. -RIH w/ logging tools on a-line to TD (5083' WLM). -Log 8-1/2" hole f/ TD to 9-5/8" casing shoe. Logging string: AIT/CNUTLD/ECS/HNGS/BHC. -Continue log section in 8-1/2" hole f/ 4900' to 4200'. (AIT/C N L/T L D/ECS/HNGS/BHC ) -POOH a-line w/ logging tools to surface. RD & LD logging tools. Check and prepare firing head. Mobilize to rig floor and RU sidewall core tools. -Radio silence when arming tools on rig floor and until tools ~ 200' below rotary table. RIH w/ sidewall core tools on a-line. -Attempt 45 sidewall cores. Misfire 19, recover 26: 4858', 4856', 4845', 4831', 4805', 4656', 4654', 4653', 4646', 4638', 4627', 4620', 4611', 4602', 4595', 4587', 4581', 4554', 4530', 4499', 4419', 4394', 4384', 4348', 4335' and 4310'. -POOH to 200' -Establish radio silence. -POOH f/ 200' to surface. -LD sidewall core tools. -Fire test head. PU sidewall core tools. -Establish radio silence. -MU sidewall core tools and RIH to 200'. RIH w/ sidewall core tools on a-line -Attempt 24 sidewall cores. Misfire 18, recover 6: 4882', 4853', 4805', 4799', 4784' and 4772' -POOH to 200' -Establish radio silence -POOH f/ 200' to surface. LD sidewall core tools. Printed: 12/30/2008 12:34:17 PM ~ ~ gp Page 11 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To ,Hours Task Code NPT Phase Description of Operations 11/20/2008 15:00 - 17:30 2.50 EVAL N DFAL PROD1 -PU and MU sidewall core tools. RIH to 200' 17:30 - 22:00 4.50 EVAL N DFAL PROD1 RIH w/ sidewall core tools on a-line. -Attempt 21 sidewall cores. Misfire 1, recover 20: 4722', 4720', 4715', 4710', 4700', 4698', 4691', 4685', 4678', 4675', 4671', 4761', 4743', 4735', 4731', 4870', 4816', 4792', 4747' and 4556'. -POOH to 200'. Establish radio silence. -POOH to surface. LD tools 22:00 - 23:30 1.50 EVAL P PROD1 RD Schlumberger a-line equipment. 23:30 - 00:00 0.50 BOPSU P PROD1 Function test BOPs: top rams, blind rams, bottom rams, annular preventer, HCR kill and HCR choke (use one stand 5" DP to function test top and bottom rams and annular preventer). 11/21/2008 00:00 - 00:30 0.50 CASE P PROD1 MU cleanout BHA: 8-1/2" tricone bit + bit sub + float sub + 1 jt NMDC + stabilizer + 2 jts NMDC + 3 jts 5" HWDP +jars + 2jts 5" HWDP. 00:30 - 03:00 2.50 CASE P PROD1 RIH w/ cleanout BHA f/ 290' to 5000'. -Fill pipe C~ 2180' and 4125'. -Obtain parameters: PUW 150k /SOW 115k / ROTW 130k. -Establish circulation ~ 504 gpm / 950 psi. Rotate down to TD ~ 5081'. 03:00 - 05:00 2.00 CASE P PROD1 CBU 4x and condition mud, 504 gpm ~ 950 psi. Rotate and reciprocate, 110 RPM / 7k torque. 05:00 - 06:00 1.00 CASE P PROD1 Pump out of the hole to the shoe. 06:00 - 06:30 0.50 CASE P PROD1 CBU ~ shoe. 504 gpm ~ 740 psi 06:30 - 08:30 2.00 CASE P PROD1 -Blow down top drive. -Flow check well. -POOH to 290' (BHA) 08:30 - 10:00 1.50 CASE P PROD1 LD BHA: HWDP, NMDCs, jars, float sub, bit sub and bit. 10:00 - 11:00 1.00 WHSUR P PRODi -Pull wear bushing. -Install test plug. 11:00 - 12:30 1.50 BOPSU P PROD1 C/O top 3-1/2" x 6" VBR to 7" rams. 12:30 - 13:30 1.00 BOPSU P PROD1 -Install 7" test jt and RU testing equipment. -Test 7" rams (top) to 250 psi low - 3500 psi high x 5 min each on chart. -RD testing equipment. LD 7" test jt and pull test plug. 13:30 - 15:30 2.00 CASE P PROD1 RU to run 7" casing: C/O bales, install air spiders and elevators, install Frank's fill up tool. 15:30 - 21:30 6.00 CASE P PROD1 Run 7" 26# L-80 BTC-M casing to 9-5/8" shoe per running order. -Install ES-Cementer and pup jt w/ RA tag in string per plan. Bakerlok connections at ES-Cementer. -Install 2 straight centralizers per jt on all jts below ES-Cementer (except on jts to be placed in front of intervals to be perforated later). Install bow flex centralizer 10' below and 10' above ES-Cementer. -Break circulation half way in, 210 gpm ~ 450 psi. 21:30 - 22:30 1.00 CASE P PROD1 Circulate string volume prior to entering open hole. 210 gpm ~ 550 psi. -Check parameters ~ shoe: PUW: 145k /SOW 112k. 22:30 - 00:00 1.50 CASE P PRODi Cont. running 7" 26# L-80 BTC-M casing per running order to 5077'. -Total jts run: 123 -PUW: 155k /SOW: 120k. Printed: 12/30/2008 12:34:11 I'M gp Page 12 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date I, From - To I Hours Task Code NPT Phase Description of Operations 11/22/2008 00:00 - 01:30 1.50 CASE P PROD1 -MU landing jt w/ mandrel hanger. -Circulate down and land casing. 126 gpm ~ 250 psi -Circulate 2 casing volumes and condition mud. 210 gpm C~ 590 psi. Reciprocate casing (20' strokes) while circulating. -Hold PJSM on cementing casing while circulating. 01:30 - 02:00 0.50 CASE P PROD1 -LD Franks fill up tool. -RU XO and cementing head. 02:00 - 02:30 0.50 CASE P PROD1 Cont. circulating while Schlumberger batch cement. 02:30 - 03:30 1.00 CEMT P PROD1 Give it to Schlumberger: 1. Pump 5 bbls of water and test lines to 3500 psi. 2. Pump 52 bbls 10.0 ppg Mudpush ~ 5 BPM. 3. Drop bottom plug. 4. Pump 38.5 bbls 15.8 ppg class "G" cement ~ 5 BPM. 5. Drop top plug and kick out w/ 10 bbls of water. 03:30 - 04:00 0.50 CEMT P PROD1 Switch to rig pumps: -Displace cement w/ 182 bbls 9.2 ppg mud ~ 5 BPM, reducing rate to 3 BPM before bumping plug. FCP: 650 psi. -Bump plug w/ 1650 psi. -Bleed off pressure. Disconnect cement line and check floats. OK -Cement in place ~ 04:00 hours -Reciprocate casing (20' strokes) until bumping plug. 04:00 - 05:00 1.00 CASE P PROD1 -Line up cementing head. -Pressure up to 3600 psi and open ES-Cementer. -Circulate through ES-Cementer, 5 BPM ~ 560 psi. Observe returns of all Mudpush pumped. No cement to surface. 05:00 - 06:00 1.00 CASE P PROD1 -Pump 30 bbls Biozan pill. -Drop closing plug. Displace pill down casing through ES-Cementer. FCP= 350 psi. -Land closing plug. Pressure up and observe ES-Cementer close ~ 1450 psi. Cont. Pressure up to 2500 psi and hold x 1 min per HES Rep. Biozan pill is spotted in annulus from ES-Cementer up. -Bleed off pressure and observe no flow back. 06:00 - 08:00 2.00 CASE P PROD1 -Blow down cement line. -LD cement head and XO. -Back out landing jt and LD same. -Blow down choke line and kill line. -Vac out stack. 08:00 - 10:30 2.50 WHSUR P PROD1 -MU packoff running tool and install mandrel hanger packoff. Damage seal in the process. -Pull packoff, replace seal and reinstall. RILDS. -Test packoff to 4300 psi per FMC Rep. Clear rig floor. 10:30 - 12:00 1.50 BOPSU P PROD1 -C/O top rams to 3-1/2" x 6" VBR. -C/O saver sub to 4" HT38 12:00 - 14:00 2.00 BOPSU P PROD1 RU to test BOP. 14:00 - 18:30 4.50 BOPSU P PRODi Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 3-1/2" test jt. Test top and bottom rams w/ 5" and 3-1/2" test jts. Test witnessed by WSL and Toolpusher. Chuck Scheve, AOGCC Rep, waived witness of test. Nnnted: uisuizuus 1"L:34:11 YM ~ e gp Page 13 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~' Task ~ Code II, NPT ~ Phase ~ Description of Operations 11/22/2008 14:00 - 18:30 4.50 BOPSU P PROD1 -Perform koomey test: 1. System Pressure: 3000 psi 2. Pressure after close: 1700 psi 3. 200 psi attained at 30 sec 4. Full pressure attained at 2 min 55 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 31 components: 1. 13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 5" Inside BOP and FOSV (ball type), 4" Inside BOP and FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 18:30 - 19:00 0.50 BOPSU P PRODi RD testing equipment. 19:00 - 19:30 0.50 WHSUR P PROD1 -Install wear bushing. -Blow down choke and kill lines. 19:30 - 21:00 1.50 CASE P PRODi MU cleanout BHA w/ 6-1/8" tricone bit + bit sub + (12) 4-3/4" DCs +jar (PU 4-3/4" DCs and jar 1x1 f/ pipe shed). -PU 1 jt 4" DP. 21:00 - 23:00 2.00 CASE P PROD1 -Cut and slip drilling line (59.5') -Inspect and service top drive. 23:00 - 00:00 1.00 CASE P PROD1 PU 4" DP 1x1 f/ pipe shed and RIH w/ cleanout BHA to +/- 1000'. 11/23/2008 00:00 - 00:30 0.50 CASE P PROD1 -Inspect and service top drive, blocks and drawvvorks. -Blow down choke and bleeder. 00:30 - 03:00 2.50 CASE P PROD1 Cont. PU 4" DP 1x1 f/ pipe shed and RIH w/ cleanout BHA f/ 1000' to 4100'. 03:00 - 03:30 0.50 CASE P PROD1 CBU to break gels, 231 gpm ~ 1120 psi. 03:30 - 04:00 0.50 CASE P PROD1 -RU testing equipment. -Test casing to 3000 psi x 10 min on chart. -RD testing equipment 04:00 - 04:30 0.50 CASE P PROD1 Cont. PU 4" DP 1x1 f/ pipe shed and RIH f/ 4100'. Tag ES-Cementer ~ 4297'. -PUW 120k /SOW 90k / ROTW 100k. 04:30 - 05:00 0.50 DRILL P PRODi Drill out ES-Cementer. 2-10k WOB, 80 RPM ~ 2k torque, 252 gpm ~ 1300 psi. -Ream several times through ES-Cementer after drilling out. -Wash down to 4322'. 05:00 - 06:00 1.00 CASE P PRODi Cont. PU 4" DP and RIH f/ 4322'. Tag cement stringers C~3 4944'. Clean cment stringers to 4965'. Wash and ream to 4991'. 06:00 - 07:00 1.00 CASE P PROD1 CBU, 336 gpm ~ 1250 psi. 07:00 - 08:30 1.50 CASE P PROD1 -RU testing equipment. -Test casing to 3500 psi x 30 min on chart. -RD testing equipment. 08:30 - 10:00 1.50 CASE P PROD1 -Pump Hi-vis spacer sweep and flush well w/ 400 bbls 8.5 ppg seawater. -Displace seawater w! 9.3 ppg brine (demulsifier in brine C~ 1 rnntea: mauiewo IZ:J4:11 rive gP Page 14 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: ~ Phase ' Description of Operations Date From - To Hours Task Code NPT 11/23/2008 08:30 - 10:00 1.50 CASE P PROD1 gal/ 1000 bbls concentration per Schlumberger). 10:00 - 11:30 1.50 CASE P PROD1 -RU testing equipment. -Test casing to 4000 psi on chart. Pressure bleeds down 100 psi in 15 min. Bump up to 4000 psi. Pressure bleeds down 100 psi in 30 min. Test good. -RD testing equipment. Blow down kill line. 11:30 - 14:30 3.00 CASE P PRODi POOH and rack back 4" DP to 401' (BHA). 14:30 - 15:00 0.50 CASE P PROD1 -Rack back 3 stands 4-3/4" DCs. -LD jars, bit sub and bit. 15:00 - 16:30 1.50 EVAL P PROD1 RU Schlumberger a-line equipment. 16:30 - 20:30 4.00 EVAL P PROD1 -RIH w/ USIT/CBUCCUGR log to 4121'. Slack off ~ 4121'. -Pull and get stuck C~ 4080'. Work a-line and pull until 4000 Ibs tension on head. Pull tools free. -POOH to check tools. 20:30 - 21:30 1.00 EVAL N DPRB PROD1 -Tools ~ surface: centralizers OK, all tools out. USIT sensor cage was missing (sensor OK). LD tools. -PU junk basket w/ 6-1/8" ring gauge and MU to GR/CCL. 21:30 - 00:00 2.50 EVAL N DPRB PROD1 -RIH w/ ring gauge/junk basket/CCL/GR on a-line. Tag junk (sensor cage) ~ 4080'. Work and push junk to 4315'. Got stuck. -Work a-line and pull free. POOH w/drag indicating possible junk. 11/24/2008 00:00 - 01:30 1.50 EVAL N DPRB PROD1 -Tools at surface: junk basket empty, marks in ring gauge. -LD tools. RD Schlumberger a-line equipment and clear rig floor. 01:30 - 02:00 0.50 CASE N DPRB PROD1 MU BHA w/ 6-1/8" tricone bit + 7" casing scraper + bit sub + 4 stands 4-3/4" DCs. 02:00 - 03:30 1.50 CASE N DPRB PROD1 RIH w/ cleanout BHA on 4" DP. Tag junk ~ 4872'. PU and check again, observe no tag. Cont. RIH to 4991'. 03:30 - 04:30 1.00 CASE N DPRB PROD1 CBU, 336 gpm ~ 2020 psi 04:30 - 06:30 2.00 CASE N DPRB PROD1 POOH f/ 4991' to 375' (BHA) 06:30 - 07:00 0.50 CASE N DPRB PROD1 -Rack back 4 stands 4-3/4" DCs. -LD bit, bit sub and casing scraper. 07:00 - 08:00 1.00 EVAL P PRODi RU Sclumberger a-line equipment. 08:00 - 10:30 2.50 EVAL P PRODi -RIH w/ USIT/GPIT/GR/CCL on e-line to 4975'. -Take USIT/GPIT/GR/CCL log f/ 4975' to 100'. -Observe TOC ~ 4335' WLM. Observe RA tag in casing ~ 4251' WLM 10:30 - 11:30 1.00 EVAL P PROD1 RD Schlumberger tools and a-line equipment. Clear rig floor. 11:30 - 12:00 0.50 EVAL P PROD1 -RD 4" DP elevators. -Mobilize to rig floor 3-1/2" tubing elevators, slips, powwer tongs and torque turn equipment. 12:00 - 13:30 1.50 EVAL P PROD1 RU to run TCP/DST assembly 13:30 - 16:30 3.00 EVAL P PROD1 MU and RIH TCP/DST assembly per Schlumberger Rep. -Will perforate and evaluate int. 4710'-4730' 16:30 - 17:30 1.00 EVAL P PROD1 RU to run 3-1/2" tubing: install long bale and compensator, power tongs and torque turn equipment. 17:30 - 00:00 6.50 EVAL P PROD1 PU 3-1/2" 9.2# L-80 1x1 f/ pipe shed and RIH with TCP/DST assembly. -Run 51 jts TCII followed by NSCT jts on top. -Torque turn connections to opt. MU torque according to connection type. 11/25/2008 00:00 - 03:00 3.00 EVAL P PROD1 Cont. RIH 3-1/2" 9.2# L-80 (TCII on bottom 51 jts, NSCT on Nnrnea: ir~suieuuu i~:~4:ii rm • gP Page 15 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~! Hours Task Code NPT Phase Description of Operations 11/25/2008 00:00 - 03:00 3.00 EVAL P PROD1 top) with TCP/DST assy. to 4757'. -Run total 136 jts of 3-1/2" tubing. -PUW 100k /SOW 80k 03:00 - 05:00 2.00 EVAL P PROD1 RU Schlumberger a-line equipment to correlate packer and guns position. 05:00 - 06:30 1.50 EVAL P PROD1 -Run correlation log on a-line to position packer and TCP guns. -POOH a-line and RD. 06:30 - 07:30 1.00 EVAL P PROD1 -LD jt #136 and #135. -MU 5.87' pup jt. MU jt #135 and RIH. Set on slips. 07:30 - 08:30 1.00 EVAL P PROD1 -Mobilize flowhead and pump in sub to rig floor. -Install pump in sub on top of flowhead. -MU flowhead and XO to string. 08:30 - 09:30 1.00 EVAL P PROD1 -Line up injection line to IA. -Pressure up IA to 200 psi x 5 min and verify CV valve shut. 09:30 - 10:30 1.00 EVAL P PROD1 -Line up cement line on flowhead wing valve. -Test tubing string to 4000 psi x 10 min on chart. -Blow down and RD cement line. 10:30 - 11:30 1.00 EVAL P PROD1 -PU tubing string and engage packer. Slack off, position guns in front of int. 4710'-4730' and set packer. -Pressure up to 1000 psi and verify packer set. 11:30 - 12:00 0.50 EVAL P PROD1 -Blow down and RD injection line. -Mobilize hard line f/ nitrogen to rig floor. 12:00 - 15:00 3.00 EVAL P PROD1 -RU lines to flowhead to inject nitrogen and for DST test. -Test lines with nitrogen to 4000 psi. 15:00 - 16:00 1.00 EVAL P PROD1 -Pressure up IA to 1000 psi to enable IRDV valve. -Bleed off. Pressure up IA to 1400 psi and open IRDV valve. Observe 200 psi drop indicating IRDV open. 16:00 - 18:00 2.00 EVAL P PROD1 Displace 37 bbls brine out of tubing with nitrogen, locating fluid level ~ +/-4257'. Wait 30 min for stabilization. -Total nitrogen pumped: 52 MSCF. 18:00 - 19:00 1.00 EVAL P PROD1 Pump 10 bbls down IA and pressure up to 600 psi. Bleed back (8 bbls returned). Close circ. valve. 19:00 - 19:30 0.50 EVAL P PROD1 Pressure up in IA to 500 psi. Bleed off. Pressure up to 1400 psi. Repeat process. Open ball/tester valve above pert. guns. 19:30 - 20:00 0.50 EVAL P PROD1 -Open swab valve in flowhead and drop bar to fire guns and perforate int. 4710'-4730'. Nitrogen pressure in tubing ~ 1450 psi. -There was no indication of firing on surface. Continue with procedure per BP Heavy Oil Team P.E (James Young). 20:00 - 00:00 4.00 EVAL P PROD1 -Initial nitrogen pressure in tubing C~ 1450 psi. Bleed down 25 psi to tiger tank. Continue bleed down 15 psi to tiger tank every hour per P.E schedule. -RU Schlumberger wireline equipment and pressure control on top of flowhead. 11/26/2008 00:00 - 02:30 2.50 EVAL P PROD1 -Cont. bleeding off tubing pressure (nitrogen) 15 psi every hour per schedule. -Test wireline pressure control to 2000 psi x 5 min (had to change o'ring 2x) 02:30 - 05:30 3.00 EVAL P PROD1 -Cont. bleeding off tubing pressure (nitrogen) per schedule. -RIH PBMS + weight bars + fire bar retrieving tool on a-line. -Detect fluid level @ 4070'. Cont. RIH wireline and could not get passed 4190' (top of 4-3/4" DCs on DSt string). -POOH wireline. Pnntetl: 12/30/2008 1'2:34:11 PM gp Page 16 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date I From - To 'Hours Task Code NPT Phase Description of Operations 11/26/2008 05:30 - 07:30 2.00 EVAL P PROD1 -RD wireline. Install bull nose extension. -RIH w/ bull nose extension on a-line and tag bar ~ 4570'. Bar is sitting on top of IRDV, which did not open before. TCP guns did not fire. POOH w/ wireline. -Cont. bleeding off tubing pressure per schedule while RIH w/ wireline. 07:30 - 08:30 1.00 EVAL P PROD1 -Build pressure in tubing back to 1302 psi w/ nitrogen. -Pressure up IA to 1000 psi and bleed back to 500 psi x 2min. Run pressure up to 1000 psi and IRDV open. -Bar drops f/ top of IRDV after it opened and fire TCP guns in int. 4710'-4730'. Good indication on surface of guns firing. 08:30 - 11:00 2.50 EVAL P PROD1 -RD nitrogen hard line. -Establish tubing bleed off schedule. 11:00 - 13:30 2.50 EVAL P PROD1 -RIH w/ PBMS tool on a-line. Tag fluid level ~ 4010'. POOH w/ a-line. -Cont. bleeding off tubing per schedule while running wireline. 13:30 - 20:30 7.00 EVAL P PROD1 -Install sample tool on a-line. Reinstall lubricator and test quick test sub to 3000 psi. -RIH w/ sample tool on a-line and tag fluid level ~ 3916'. Cont. RIH to 4623' and collect fluid sample. -POOH a-line w/ sample tool. 20:30 - 22:30 2.00 EVAL P PROD1 -Remove sample tool (tool came covered in oil on the outside). -Install new sample tool. -Reinstall lubricator. Attempt to test quick test sub. Change o-rings. Test to 3000 psi. 22:30 - 00:00 1.50 EVAL P PROD1 -RIH w/ new sample tool on a-line. -Pressure up IA to 2450 psi to open SCAR. Hold pressure x 1 hr. 11/27/2008 00:00 - 06:30 6.50 EVAL P PRODi -Bleed off pressure in IA. -Cont. RIH second sample tool on a-line. Tag fluid level C~3 +/- 3810' -Collect fluid sample. Correlate w/ RA tag in tubing. Corrected fluid level depth after correlating to 3784'. -POOH a-line w/ second sample tool. Observe fluid level when pulling out ~ 3750' (+/- 3-1/2 hrs between fluid level readings). 06:30 - 08:00 1.50 EVAL P PROD1 Shut in swab valve -Bleed pressure from lubricator -Remove sample tool (tool came covered in oil on the outside). -Install new sample tool. -Reinstall lubricator -Test quick test sub to 3000 psi. Equalize lubricator. 08:00 - 15:00 7.00 EVAL P PROD1 -RIH w/ sample tool on a-line. -Take third fluid sample ~ 3705'. -POOH a-line w/ sample tool. 15:00 - 16:30 1.50 EVAL P PROD1 -Shut in swab valve and bleed pressure f/ lubricator. -Retrieve sample tool. RD a-line equipment. -Pressure up IA to 1000 psi and enable IRDV. Bleed off pressure. -Pressure up IA to 1400 psi. Close tester valve. Hold pressure x 1 min to open circulating valve. Observe pressure drop as circulating valve open. 16:30 - 18:30 2.00 EVAL P PROD1 -Bleed nitrogen out of tubing to tiger tank, while cirulating top of hole to keep same full (25 bbls to keep hole full). Printed: 12/30/2008 12:34:11 PM gp Page 17 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To i Hours Task ', Code NPT Phase Description of Operations 11/27/2008 16:30 - 18:30 2.00 EVAL P PROD1 -Collect dead crude samples on surface when tubing pressure bled completely (0 psi) and oil reached surface. -Reverse circulate tubing volume with 37 bbls 9.3 ppg brine, taking returns out to tiger tank. 165 gpm ~ 740 psi -Cont. reverse circulating 60 bbls 9.8 ppg brine, taking clean returns back to pits and oil contaminated returns to rockwasher. 170 gpm ~ 680 psi. 18:30 - 20:00 1.50 EVAL P PROD1 -Pressure up IA to 600 psi and hold x 6 min, then bleed off. This closes circulating valve. -Open tester valve by pressuring up IA to 500 psi x 2 min. Then up to 1000 psi and hold x 4 min. Cont. up to 1400 psi to lock tester valve open. Bleed off. -Bullhead 4 bbls down tubing and inject to formation, 0.5 BPM ~ 620 psi. Stop pump and hold pressure. Pressure bled to formation 500 psi in 20 min. Finish bleeding off. (This operation bullheads to formation volume between circulating valve and bottom of DST string not reverse circulated in previous steps, and prior to open packer by-pass). 20:00 - 21:30 1.50 EVAL P PROD1 -PU string to open packer by-pass. -Reverse circulate through packer by-pass 60 bbls 9.3 ppg brine, taking clean returns back to pits and oil contaminated returns to rockwasher. 114 gpm ~ 280 psi. 21:30 - 22:30 1.00 EVAL P PROD1 -Unseat packer. Observe well U-tubing f/ IA to tubing. -Circulate well volume (165 bbls) w/ 9.3 ppg brine. Observe well static. 22:30 - 23:30 1.00 EVAL P PROD1 LD flowhead and mobilize off rig floor. 23:30 - 00:00 0.50 EVAL P PROD1 RU to pull and LD 3-1/2" tubing 11/28/2008 00:00 - 00:30 0.50 EVAL P PROD1 Finish RU to pull and LD 3-1/2" tubing. 00:30 - 06:30 6.00 EVAL P PRODi POOH and LD 3-1/2" 9.2# L-80 (NSCT &TCII) tubing to pipe shed. -Use compensator to LD tubing. 06:30 - 10:30 4.00 EVAL P PROD1 -Rack back 4-3/4" DCs. -LD DST tools. Clear rig floor 10:30 - 11:30 1.00 EVAL P PROD1 MU 7" EZSV bridge plug and RIH w/ 4-3/4" DCs f/derrick. 11:30 - 14:30 3.00 EVAL P PROD1 -Cont. RIH 7" EZSV bridge plug and 4-3/4" DCs on 4" DP to 4650'. -Circulate and reciprocate pipe x 5min, 144 gpm ~ 240 psi. -Set EZSV bridge plug ~ 4650' (COE). Isolate int. 4710'-4730' 14:30 - 15:00 0.50 EVAL P PROD1 CBU - 370 gpm ~ 1280 psi. 15:00 - 15:30 0.50 EVAL P PROD1 -RU testing equipment. -Test 7" casing and bridge plug to 4000 psi x 10 min on chart. -RD testing equipment. 15:30 - 17:00 1.50 EVAL P PROD1 POOH and rack back 4" DP to 350' (DCs). 17:00 - 17:30 0.50 EVAL P PROD1 Lubricate rig and inspect top drive. 17:30 - 19:00 1.50 EVAL P PROD1 Rack back 4-3/4" DCs. -Drift same to 2-1/16" while racking back. 19:00 - 19:30 0.50 EVAL P PROD1 LD HES running tool and clear rig floor. 19:30 - 23:00 3.50 EVAL P PROD1 MU and RIH TCP/DST string per Schlumberger Rep. 23:00 - 00:00 1.00 EVAL P PROD1 RU to run 3-1/2" tubing: C/O bales, install compensator and torque turn equipment. 11/29/2008 00:00 - 08:00 8.00 EVAL P PROD1 RIH 3-1/2" 9.2# L-80 (TCII &NSCT) tubing 1x1 with TCP/DST string to 4630' -Torque turn connections to opt. torque according to Printetl: 12/30/2008 12:34: T1 rnn g F Page 18 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 11/29/2008 00:00 - 08:00 8.00 EVAL P PROD1 connection type. -Total jts 3-1/2" tubing run: 132 -PUW 95k /SOW 80k 08:00 - 11:00 3.00 EVAL P PROD1 -RU Schlumberger a-line. -RIH GR/CCL on e-line to correlate guns position. Could not get past 1785'. -POOH a-line. Log tool came covered with oil on the outside. 11:00 - 12:00 1.00 EVAL N PROD1 Reverse circulate 9.3 ppg brine, 210 gpm ~ 740 psi 12:00 - 14:00 2.00 EVAL N DPRB PRODi -Spot 35 bbls heated 9.3 ppg brine+ ScreenKleen pill in tubing. Let it soak f/ 40 min. -Reverse circulate out pill. -Circulate surface-surface w/ 9.3 ppg brine, 215 gpm ~ 740 psi. -Close circulation valve in DST string per Schlumberger Rep. 14:00 - 15:30 1.50 EVAL N DPRB PRODi -Attempt to run GR/CCL log on a-line. Could not get past 2000'. -POOH and hang tool on side. Log tool came covered with oil on the outside. 15:30 - 17:30 2.00 EVAL N DPRB PROD1 -Open circulating valve in DST string per Schlumberger Rep. -Reverse circulate 9.3 ppg brine while waiting for Little Red Services to pump heated diesel. 17:30 - 22:30 5.00 EVAL N DPRB PROD1 -RU Llttle Red Services. -Pump down tubing 35 bbls ScreenKleen pill (w/ rig pumps), followed by 36 bbls 130 degF diesel (w/ Little Red). -Let heated diesel soak in tubing (soak f/ 3.5 hrs while waiting f/ new 9.3 ppg brine). -RD Little Red. 22:30 - 23:00 0.50 EVAL N DPRB PROD1 -Reverse circulate diesel out of tubing to tiger tank. -Reverse circulate ScreenKleen pill out to rockwasher. 23:00 - 00:00 1.00 EVAL N DPRB PROD1 -Pump 30 bbls hi-vis sweep. -Displace well w/ 160 bbls new 9.3 ppg brine. 290 gpm ~ 700 psi. 11/30/2008 00:00 - 01:00 1.00 EVAL P PROD1 -RIH w/ correlation log on a-line. -Observe RA tag in tubing ~ 4373 WLM (1.5' shallow from tubing tally) -POOH a-line 01:00 - 02:00 1.00 EVAL P PROD1 -LD jts #132 and #131. -MU space out pup jts (3.85' & 5.87') on top of jt #130. -MU jt #131. RIH and position guns on depth to perforate int. 4585'-4605'. 02:00 - 04:00 2.00 EVAL P PROD1 -RD compensator. C/O elevators. -Mobilize flowhead to rig floor. -RU pump in sub on top of flowhead. -C/O XO on bottom of flowhead. MU flowhead and XO to string -Close circulating valve in DST string per Schlumberger Rep. 04:00 - 05:00 1.00 EVAL P PROD1 -RU cement line to flowhead and testing equipment. -Test tubing to 4000 psi x 10 min on chart. Test good. 05:00 - 06:00 1.00 EVAL P PROD1 Set DST packer and set 25k down -Test same to 1000 psi per Schlumberger Rep. -Open Circ. valve -Load BHF firing bar 06:00 - 09:30 3.50 EVAL P PROD1 RU wireline lubricator, grease head, fast test sub, W.L. BOP & sheaves rnncea: iciauicuvo ~c:av. i i r~~~ gP Page 19 of 32 ~ Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 11/30/2008 06:00 - 09:30 3.50 EVAL P PROD1 -Test lubricator to 2000 psi f/ 5 min. 09:30 - 11:30 2.00 EVAL P PROD1 RU lines for N2 displacement 11:30 - 13:30 2.00 EVAL N PROD1 13:30 - 15:30 2.00 EVAL N PROD1 15:30 - 17:30 2.00 EVAL P PROD1 17:30 - 18:30 1.00 EVAL P PROD1 18:30 - 19:30 1.00 EVAL P PROD1 19:30 - 22:30 3.00 EVAL P PROD1 22:30 - 00:00 1.50 EVAL P PROD1 12/1/2008 00:00 - 05:30 5.50 EVAL P PROD1 05:30 - 06:30 1.00 EVAL P PROD1 06:30 - 12:00 5.50 EVAL P PROD1 -Purge all lines w/ N2 -Test lines to 4000 psi -PJSM w/ all involved w/ upcoming operation Displacing tubing w/ N2 -Stop at 28 bbls away and monitor trip tank -Continue pumping N2 -Overdisplaced tubing allowing N2 into annulus Bleed N2 into slop tank while filling annulus and keeping backpressure at 700-1100 psi on annulus -Reverse circ. tubing volume + 10 bbls -Circulate N2 out of annulus through choke and gas buster -Shut in and observe for pressure - OK -Open well and circ. surface to surface -Blow down lines Cycle C.V. to ensure DST equip. operable - OK -PJSM on N2 displacement -Displace tubing w/ N2 -Track volume in trip tank -Total displacement = 36.62 bbls -Calculated displacement to top of IRDV = 37.25 bbls -Total N2 pumped = 31.417 Mscf -Close circulating valve. -Open tester valve and lock it open. -Open swab valve and drop bar to fire guns. No indication on surface of firing. -Repeat process to open tester valve in case bar was sitting on top of it. No indication of firing on surface. -RIH a-line w/ correlation log. Detect fluid level (~3 4157'. Tag bar ~ 4550' on top of firing head. Guns fired and perforate int. 4585'-4605' when bar tagged with a-line. Indication of firing on surface. -Bleed off 25 psi in tubing and check fluid level again. Fluid level ~ 4146'. -Wait 10 min and check fluid level again. Fluid level ~ 4138'. -POOH w/ a-line -Shut in swab valve. -Bleed off lubricator and disconnect same at fast test sub. -Install oil sampler on a-line. -Connect lubricator and test on fast test sub to 2000 psi. -Bled 59 psi during change of tools on a-line. -Equalize pressure in lubricator and open swab valve. -RIH w/fluid sampler on a-line. Tag fluid level ~ 3950'. -Bleed nitrogen pressure in tubing as required. -Collect first fluid sample. -POOH a-line w/ fluid sampler. -Shut in swab valve. -Bleed off lubricator and disconnect same at fast test sub. -C/O oil sampler tool. -Connect lubricator and test on fast test sub to 2000 psi. -Equalize pressure in lubricator and open swab valve. -RIH w/fluid sampler on a-line. Tag fluid level ~ 3790'. Printetl: 12/30/20013 1Y:34: T1 PM gP Page 20 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: !,Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 ~IRig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/1/2008 06:30 - 12:00 5.50 EVAL P PROD1 -Bleed nitrogen pressure in tubing as required. -Collect second fluid sample. -POOH a-line w/fluid sampler. 12:00 - 13:30 1.50 EVAL P PROD1 -Shut in swab valve. -Bleed off lubricator and disconnect same at fast test sub. -Disconnet second sampler. Install 2 new oil sampler tools set at different opening times. -Connect lubricator and test on fast test sub to 2000 psi. 13:30 - 21:30 8.00 EVAL P PRODi -Equalize pressure in lubricator and open swab valve. -RIH w/ fluid samplers #3 and #4 on a-line. -Collect 3rd and 4th fluid samples ~ 3657' and 3641' (sampler tools open at different times). -POOH a-line w/fluid sampler tools. 21:30 - 22:30 1.00 EVAL P PROD1 -LD a-line tools. -RD lubricator, wireline BOP and rest of a-line equipment. 22:30 - 00:00 1.50 EVAL P PROD1 -Close tester valve and open circulating valve per Schlumberger Rep. -Bleed off nitrogen pressure to tiger tank while keeping IA full w/ 9.3 ppg brine. Take 19.5 bbls brine to fill IA. -After nitrogen bled, cont. reverse circulating w/ 9.3 ppg brine, taking returns out to tiger tank until clean enough to divert to rockwasher. Reverse circulate total 28 bbls, 114 gpm ~ 600 psi. 12/2/2008 00:00 - 01:00 1.00 EVAL P PROD1 Reverse circulate well w/ 9.3 ppg brine, taking dirty returns to rockwasher and clean returns to pits. 01:00 - 02:00 1.00 EVAL P PROD1 -RU Little Red and test lines. -Little Red pumps 38 bbls 130 degF diesel and spot in tubing. 2 BPM C~3 750 psi. -RD Little Red. 02:00 - 03:00 1.00 EVAL P PROD1 Let heated diesel soak in tubing. 03:00 - 03:30 0.50 EVAL P PROD1 -Reverse circulate diesel out to tiger tank w/ 38 bbls 9.3 ppg brine. -Cont. reverse circulating to pits w/ 38 bbls 9.3 ppg brine. Returns clean. 03:30 - 05:00 1.50 EVAL P PROD1 -Close circulating valve and open tester valve per Schlumberger Rep. -Bullhead 3 bbls to formation, hesitating at max. 800 psi w/ 0.5 BPM. -Let pressure bleed to formation after bullheading. - Pressure bleeds 700 psi in 15 min. 05:00 - 05:30 0.50 EVAL P PROD1 -PU. Open packer by-pass and unseat packer. -Reverse circulate 60 bbls 9.3 ppg brine, taking returns to pits. 05:30 - 06:00 0.50 EVAL P PRODi - LD Flowhead. 06:00 - 07:00 1.00 EVAL P PROD1 - RU to LD 3.5" tubing with compensator. 07:00 - 12:00 5.00 EVAL P PROD1 -POOH LD 3.5" tubing from 4,630' to 535' md. 12:00 - 14:00 2.00 EVAL P PROD1 - RD 3.5" tubing equipment. Remove long bails. -Install short bails. Clear rig floor. 14:00 - 17:30 3.50 EVAL P PROD1 Stand back one stand of collars, LD the rest of the D.C's. -PJSM on laying down Guns -All Guns fired. -LD DST tools and guns. 17:30 - 18:30 1.00 EVAL P PROD1 -Clear rig floor of vendors tools. 18:30 - 20:30 2.00 PXA P PROD1 -RIH from derrick with 4" DP. -Tag top of EZSV ~ 4,650' md. rnntea: iusureuun icsv:ii rnn gp Page 21 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/2/2008 20:30 - 23:00 2.50 PXA P PROD1 - CBU at 284 gpm / 580 psi. -Reciprocate while waiting for SLB cement unit to rig up. -PUW 105k SOW 95k. 23:00 - 23:30 0.50 PXA P PROD1 PJSM on cementing. -SLB pumped: -11.1 bbls of water ahead. -Test lines to 3000 psi -OK. -11.5 bbls of 15.8 ppg class "G" Cmt. -Follow with 5 bbls of water. -Displace Cmt with Rig pumps. -Balance plug on bottom w/ 39 bbls of 9.0 ppg NaCI. -164 gpm / 50 - 140 psi. 23:30 - 00:00 0.50 PXA P PROD1 -POOH slowly to 4,300' md. -Fluid column is in balance. 12/3/2008 00:00 - 00:30 0.50 PXA P PROD1 Continue to POH slowly w/ 4" DP to 4,265' md. 00:30 - 01:30 1.00 PXA P PROD1 PU 1 Jt of 4" DP. Drop wiper ball. -Circ out Cmt -Trace amounts of Cmt to surface. -504 gpm / 1480 psi. -Reciprocate 4,286' to 4,255' md. -Rotate ~ 80 rpm. 01:30 - 03:30 2.00 PXA P PROD1 LD 1 single. Stand back 1 stand to 4,170' md. -Cut & slip 1 1/4" Drlg line (59.5'). -Service Top Drive. Inspect brake bands. -Continue to circulate to warm OA annulus fluids. -Fluid temp in = 88 F. Fluid temp out = 79 F. 03:30 - 05:00 1.50 PXA P PROD1 Flow check -Dry job -Blow down -POH w/ Mule shoe on 4" DP f/ 4,170' and to surface. -LD Mule shoe. 05:00 - 05:30 0.50 PXA P PROD1 MU 5 1/2" Multi-String Cutter dressed for 7" 26# casing. -RIH on 4" DP 2 stands. 05:30 - 06:30 1.00 PXA P PROD1 Cut & slip 1 1/4" drilling line to remove bad spot. 06:30 - 08:30 2.00 PXA P PROD1 Continue RIH w/ 4" DP to 4,275' md. 08:30 - 11:00 2.50 PXA P PRODi Circulate heated brine w/ 147 gpm / 510 psi. -Returns are 85-87 degF 11:00 - 12:00 1.00 PXA P PROD1 RU test equipment. -Test 9 5/8" casing /cement plug to 1000 psi f/ 10min on chart - OK. -RD test equipment. 12:00 - 13:00 1.00 PXA P PROD1 PU single DP -Pumping w/ 84 gpm / 180 psi. -Tag casing collar at 4,297' md. -Stop pumps - PU & spot knives at 4,277' md. -Rotating w/ 60 rpm / 2k torque. -Bring pumps on and stage up to 202 gpm / 900 psi. -Observe torque increase -Increase rotary to 100 rpm. -Observe pressure drop, went to 350 psi when pipe cut out. 13:00 - 14:00 1.00 PXA P PROD1 Close annular preventer. -Open "OA" valve to pits. -Break circ. w/ 218 gpm / 570 psi. -Circulate mud and Biozan pill out of 9 5/8" X 7" annulus. -Open Annular preventer. Flow check well -Static. 14:00 - 16:00 2.00 PXA P PROD1 POH w/Cutter on 4" DP f/ 4,277' to surface. -Knives showed good wear pattern. 16:00 - 16:30 0.50 PXA P PROD1 LD BHA. Clear Rig floor of Vendor tools. rrintea: izrsuizuuu izsa:n rm gp Page 22 of 32 Operations Summary Report Legal Well Name: MPS-41 Common W Event Name Contractor Rig Name: Date ell Name: : D Name: D D From - To MPS-41 RILL+C OYON OYON Hours OMPLE DRILLIN 14 Task TE G INC Code . NPT Start Rig R Rig N Phase ', Spud Date: 11/7/2008 : 11/6/2008 End: elease: 12/17/2008 umber: Description of Operations 12/3/2008 16:30 - 17:00 0.50 PXA P PROD1 Pull Wear ring. -Install Test plug. 17:00 - 18:00 1.00 PXA P PROD1 Change Top Rams from 3 1/2" X 6" to 4 1/2" X 7". 18:00 - 19:00 1.00 PXA P PROD1 Test Top Rams to 250 psi low / 3500 psi high. -Test each f/ 5 minutes & chart.- Pass. 19:00 - 20:00 1.00 PXA P PROD1 MU Spear on 1 Jt of 4" DP. 20:00 - 22:30 2.50 PXA P PROD1 Spear into 7" Csg & engage Spear. -Pull 175k on 7" Csg & Hanger. Hanger started moving ~ 125k. -Csg would not pull free. -Work up Csg pull from 175 - 375k. Pump 420 gpm / 450 psi. -Frozen mud & cuttings seen in returns. -Pump Hi Vis Sweep. -Csg would not pull free. LD Spear. 22:30 - 23:30 1.00 PXA P PROD1 Pull Packoff. Install Test plug. 23:30 - 00:00 0.50 PXA P PROD1 Change Top Rams back to 3 1/2" X 6" 12/4/2008 00:00 - 00:30 0.50 PXA P PROD1 Continue to change Rams to 3 1/2" X 6" Rams. 00:30 - 01:00 0.50 PXA P PROD1 RU & test Rams. -Test to 250 psi low & 3500 psi high. -Hold each test for 5 charted minutes -Pass. 01:00 - 01:30 0.50 PXA P PROD1 Pull test plug. 01:30 - 02:00 0.50 PXA P PROD1 Install Wear ring. 02:00 - 04:30 2.50 PXA P PROD1 MU Multi-String cutter, Stab & XO on 4" DP. -RIH w/ Cutter on 4" DP to 3,898' md. -PUW 101, SOW 90k, ROT wt 98k. -Pump 84 gpm / 150 psi. -Wash down & tag collar ~ 3,966' md. -Turn off pumps. PU 20'. -Engage Cutter ~ 3,946' md. -Pump rate: 84 - 252 gpm / 150 - 780 psi. -40 - 100 rpm / 2 - 7k Tq. -Observed pressure drop from 750 to 400 psi after cut. 04:30 - 06:00 1.50 PXA P PROD1 POH w/ Multi-String cutter on 4" DP from 3,946' md. -POH to surface. 06:00 - 06:30 0.50 PXA P PROD1 Pull wear ring. 06:30 - 07:00 0.50 PXA P PROD1 Install test plug & 7" test Jt. 07:00 - 07:30 0.50 PXA P PROD1 Change out Top Rams to 4 1/2" X 7" Variables. 07:30 - 08:00 0.50 PXA P PROD1 Test Top Rams - 250 low psi / 3500 psi high psi. -Test each for 5 charted minutes -Pass. 08:00 - 08:30 0.50 PXA P PROD1 Pull Test plug. LD 7" Test Jt. 08:30 - 09:00 0.50 PXA P PROD1 MU Spear, XO & 1 Jt of 4" DP. 09:00 - 09:30 0.50 PXA P PROD1 RIH. Engage Hanger. -Pull Hanger free w/ 155k. -Pull to Rig floor w/ 145k to 175k (25-30k overpull). 09:30 - 10:00 0.50 PXA P PROD1 CBU 336 gpm / 690 psi. 10:00 - 10:30 0.50 PXA P PROD1 Dis-engage from Fish. -Make service breaks & LD Spear, XO & DP. -LD Hanger & pup Jt. -C/O Elevators. Blow down Top Drive. 10:30 - 12:00 1.50 PXA P PROD1 RU Csg equipment. -POH LD 7" Csg from 3,946' to 3,461' md. 12:00 - 12:30 0.50 PXA P PROD1 Lubricate Rig. Inspect Top drive. Printed: iv~urzuua iz:'sa:n rm ~ ~ g p Page 23 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To '', Hours Task Code NPT Phase i Description of Operations 12/4/2008 12:30 - 16:30 4.00 PXA P PROD1 16:30 - 17:00 0.50 PXA P PRODi 17:00 - 19:00 2.00 PXA P PROD1 '~ 19:00 - 19:30 0.50 PXA P PROD1 19:30 - 20:00 0.50 PXA P PROD1 20:00 - 22:00 2.00 PXA P PROD1 22:00 - 00:00 2.00 PXA P PROD1 12/5/2008 00:00 - 03:00 3.00 PXA P PROD1 03:00 - 04:00 1.00 PXA P PROD1 04:00 - 05:30 1.50 PXA P PROD1 05:30 - 07:00 1.50 PXA P PROD1 07:00 - 07:30 0.50 PXA P PRODi 07:30 - 08:30 ~ 1.00 PXA ~ P ~ ~ PROD1 08:30 - 09:30 1.00 PXA P PROD1 09:30 - 10:00 0.50 PXA P PROD1 10:00 - 12:00 2.00 PXA P PRODi 12:00 - 14:00 ~ 2.00 PXA ~ P ~ ~ PROD1 14:00 - 15:30 ~ 1.50 ~ PXA ~ P ~ ~ PROD1 15:30 - 16:00 ~ 0.50 ~ PXA ~ P ~ ~ PROD1 Continue to LD 7" Csg from 3,461' and to surface. -Recovered 95 full Jts & 1 cut Jt ~ 21.99'. RD Csg equipment. Change out Saver sub, Bell guide & Jaws to 5" on Top Drive. Install Wear ring. PU Fishing BHA to Rig floor: -Spear, XO, Spear Ext, LBS, Oil jar & Intensifier jar. MU BHA to 324' md. RIH w/ Fishing assy from 324' to 3,900' and on 5" DP. Break circulation 228 gpm / 300 psi.PU 145k, SOW 110k. -Turn pumps off. Tagged fish ~ 3,947' md. -Start jarring 225k up wt. Work up to 300k up wt. -Jarred 16 times before pipe started moving. -Turn on pumps to help w/ hydraulicing out of the hole. -Pump rate: 150 - 300 gpm / 200 - 600 psi. -Pipe stared moving ~ 00:45 hrs. -Moved fish 40' up. Stood back 1 Std. -PU 1 single of 5" DP. -Continued Jarring w/ pump on to 3,720' md. -Pull without Jarring to 3,625' md. Circulate hole clean ~ 231 gpm / 430 psi. -Inspect derrick. POH w/ Fish on 5" DP from 3,625' and to BHA ~ 324' md. LD BHA. -Acc. jars, 9- 6 1/4" DC's, oil jars and bumper sub. RU casing tongs and 7" handling tools. -PJSM. -LD spear and cut jt. LD 7" casing -Recovered: bottom of jt # 96 (19.27') - 7 full jts (# 97-103) -1 Pup w/ RA tag (3.82) -Cut joint (21.52') RD casing tools. -Clear floor of casing equip. and Baker fishing tools. Clean rig floor. -Rehang make up tongs. MU 3 1/2" muleshoe, XO, 1 stand 4" DP & XO. -RIH w/ 5" DP. -Tag fill at 4,158' and (18' out of 9 5/8" shoe). Screw in T.D. -Obtain parameters: -PUW 126k -SOW 105k -ROW 118k. -Break circulation w/ 126 gpm 90 psi. -Stage pumps up to 336 gpm / 220 psi. -Rotate w/ 20 rpm -Wash and ream down from 4,158' md. -Tag hard spot /cement at 4,342' md. Pump H.V. sweep around. -336 gpm / 280 psi. -PJSM w/ cementers and truck drivers. -Sand back w/ sweep. Schlumberger pump: -22 bbls fresh water. -Test lines to 3000 psi. -Pump 25 bbls 17 ppg Class "G" cement. -8 bbls fresh water behind. Printetl: 1'L/:1U/'LUUt3 1"L:;i4:11 YM B P Page 24 of 32 Operations Summary Report 'Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To I! Hours Task Code NPT Phase Description of Operations ~ 12/5/2008 ~ 16:00 - 16:30 ~ 0.50 ~ PXA ~ P ~ ~ PROD1 16:30 - 17:00 0.501 PXA P PROD1 17:00 - 18:00 ~ 1.00 ~ PXA ~ P ~ PRODi 18:00 - 19:30 1.50 PXA P PROD1 19:30 - 00:00 4.50 PXA P PRODi 12/6/2008 00:00 - 00:30 0.50 PXA P PROD1 00:30 - 01:30 1.00 PXA P PROD1 01:30 - 02:30 1.00 PXA P PROD1 02:30 - 03:00 0.50 PXA P PROD1 03:00 - 03:30 0.50 PXA P PROD1 03:30 - 05:00 1.50 PXA P PROD1 05:00 - 10:30 5.50 PXA P PROD1 10:30 - 13:30 3.00 PXA P PROD1 13:30 - 16:00 2.50 PXA P PROD1 16:00 - 17:00 1.00 PXA P PROD1 17:00 - 17:30 0.50 PXA P PROD1 17:30 - 21:30 0.00 DRILL P PROD2 Displace w/ 9.0 ppg brine using rig pumps. -336 gpm / 200 psi. -Pumped a total of 55.7 bbls to balance cement plug. -CIP at 16:30 hrs. POH slowly. -Stand back 4 stands to 3,967' md. -Drop HES DP wiper ball. Screw in T.D. -Circulate w/ 336 gpm / 200 psi. -Trace of cement observed upon bottoms up. POH from 3,967' and to surface. -LD XO's & Mule shoe. PJSM on LD 4" DP & 4 3/4" D.C's. from derrick. -LD 4 3/4" D.C's & 4" DP from derrick. Lubricate Rig. Inspect Top Drive. Continue to LD 4" DP from derrick in mouse hole. -Clean pits for OBM. Move BHA in Pipe shed. Drain Stack. Pull Wear ring. Install Test plug with a 5" Test Jt. RU to Test BOP's. Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 5" test jt. Test top and bottom rams w/ 5" and 4-1/2" test jts. Test witnessed by WSL, Toolpusher, Jeff Jones, AOGCC Rep -Perform koomey test: 1. System Pressure: 3050 psi 2. Pressure after close: 1750 psi 3. 200 psi attained at 32 sec 4. Full pressure attained at 2 min 37 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 31 components: 1. 13-5/8" annular 2. 4-1/2" x 7" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 5" Inside BOP and FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) Change out HCR Choke valve. Sim Ops:RU to test HCR Choke and Choke line. -PU BHA to Rig floor. -Test HCR Choke valve and Choke line. Pull Test Plug. -Install Wear ring. RU Geo-Pilot skid. -Blow down Choke line & Kill line. PJSM on Nukes. rnntea: ~~aaurzuuu IZ:J4:1 I rm ~ ~ ~~C ~"~ BP Page 25 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours I Task ~ Code ~ NPT Phase Description of Operations 12/6/2008 17:30 - 21:30 0.00 DRILL P PROD2 -MU BHA: PDC bit, Geo-Pilot, DM, EWR, Stab, PWD. -Load Nukes. MU TM, Float sub, Stab & (3) Flex D.C's. 21:30 - 22:00 0.00 DRILL P PROD2 Shallow Pulse test MWD. Blow down Top Drive. 22:00 - 22:30 0.50 DRILL P PROD2 PU 5 Jts of SWDP & Jars. 22:30 - 00:00 1.50 DRILL P PROD2 PU 5" DP from Pipe shed 1 X 1. -Single in hole to 1,972' md. 12/7/2008 00:00 - 01:00 1.00 DRILL P PROD2 Continue to PU DP from Pipe shed 1 X lfrom 1,972' to 2,604' md. 01:00 - 01:30 0.50 DRILL P PROD2 RIH w/ 5" DP from derrick to 3,800' md. 01:30 - 02:30 1.00 DRILL P PROD2 Cut & slip 59.5' of 1 1/4" drilling line. -Service Top Drive. 02:30 - 03:30 1.00 DRILL P PROD2 RIH f/ 3,800' to 4,045' md. Tag hard Cmt ~ 4,045' md. -Set down 15k to verify. 03:30 - 04:30 1.00 DRILL P PROD2 Circulate surface to surface ~ 420 gpm / 950 psi. -Reciprocate DP. 04:30 - 06:00 1.50 DRILL P PROD2 RU & test Csg to 1000 psi for 10 charted minutes. -Record pressure drop down for 10 minutes. -Prepare Pits for MOBM. 06:00 - 07:30 1.50 DRILL P PROD2 Bring on MOBM to Pits. 07:30 - 09:00 1.50 DRILL P PROD2 PJSM on fluid displacement. `~` \ -Displace brine to 9.2 ppg Rheliant MOBM. -Pump rate 400 gpm / 1210 psi. 09:00 - 10:00 1.00 DRILL P PROD2 RU & test Csg to 1000 psi for 10 charted minutes. -Record pressure drop down for 10 minutes. ~~ -Blow down Top Drive. 10:00 - 11:00 1.00 DRILL P PROD2 Drill Cmt from 4,045' to Csg shoe ~ 4,140' md.~ -PUW 138k, SOW 110k, ROT wt 123k. -RPM 70 C~3 3-8k Tq, WOB 10k, 450 gpm / 1560 psi. #~~j-~ ~~ 11:00 - 12:00 1.00 DRILL P PROD2 Time drill f/ 4,140' to 4,145' md. -PUW 138k, SOW 110k, ROT wt 123k. -RPM 70 ~ 3-8k Tq, WOB 10k, 450 gpm / 1560 psi. AST = 1 hr ADT = 1 hr 12:00 - 18:30 6.50 DRILL P PROD2 Continue to Time drill f/ 4,145' to 4,203' md. -4,182' and = 60% formation. 4,188' and = 65% formation. 18:30 - 19:00 0.50 DRILL P PROD2 CBU. Condition mud for F.I T. to 11.5 ppg EMW. -RU test equipment. 19:00 - 20:30 1.50 DRILL P PROD2 Perform F.I.T.. MW = 9.2 . TVD = 3,477'. -Impose 420 psi & hold -Pass. -RD test equipment. 20:30 - 00:00 3.50 DRILL P PROD2 Directionally drill ahead from 4,203' to 4,346' md. -PUW 136k, SOW 110k, ROT wt 125k. -RPM 110, Tq on 5, Tq off 3-4k, 530 gpm / 1980 psi. -WOB 5k. AST = 8.21 hrs ADT = 9.21 hrs. 12/8/2008 00:00 - 02:30 2.50 DRILL P PROD2 Continue directionally drilling from 4,346' to 4,450' md. -PUW 135k, SOW 110k, ROT wt 125k. -475 gpm / 1660 psi off, 1710 psi on Btm. -WOB 10k, RPM 100, Tq 5k off, 6k on Btm 02:30 - 03:00 0.50 DRILL P PROD2 Pump out of hole to 4,070' and ~ Drlg rate. rnncea: ~u°wcwo ic.ov.i i rrvi ~ ~ g P Page 26 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2008 02:30 - 03:00 0.50 DRILL P PROD2 -Discuss w/ Town Max DLS allowed. 03:00 - 03:30 0.50 DRILL P PROD2 Circulate hole clean ~ 450 gpm / 1510 psi. 03:30 - 04:00 0.50 DRILL P PROD2 RIH f/ 4,070' to 4,450' md. -Wash down last stand. 04:00 - 05:00 1.00 DRILL P PROD2 Drill f/ 4,450' to 4,595' md. -PUW 135k, SOW 110k, ROT wt 125k. -400 gpm / 1320 psi off, 1490 psi on Btm. -WOB 25k, RPM 80, Tq off 5k, Tq on Btm 7k. 05:00 - 05:30 0.50 DRILL P PROD2 Not achieving build angle needed. -Circulate. Flow check well -static. -Pump out of hole ~ Drlg rate f/ 4,595' to 4,070' md. 05:30 - 06:00 0.50 DRILL P PROD2 CBU. Circulate Csg clean. -400 gpm / 1150 psi. Monitor well -static. -MW in = 9.2 ppg. MW out = 9.2 PP9• 06:00 - 08:30 2.50 DRILL P PROD2 POH w/ Geo-Pilot on 5" DP from 4,070' to BHA ~ 391' md. 08:30 - 09:00 0.50 DRILL P PROD2 Stand back HWDP & 6 3/4" D.C's. 09:00 - 11:30 2.50 DRILL P PROD2 PJSM on handling Nukes. -Pull Nuclear sources. Download MWD & ACAL. 11:30 - 12:00 0.50 DRILL P PROD2 LD Stab & Float sub. AST = 2.17 hrs. ART = 0 hrs. ADT = 2.17 -Total ADT = 11.38 hrs. 12:00 - 13:30 1.50 DRILL P PROD2 Continue to LD Drlg BHA # 8. 13:30 - 14:30 1.00 DRILL P PROD2 Pull Wear ring. Clean wear ring (sanded up). -Service & function Top Rams. 14:30 - 18:00 3.50 DRILL P PROD2 MU BHA # 9: -PDC bit, 7" Sperrydrill Lobe 7/8. -6.0 STG, Non-Mag Float sub, Integral Blade Stab, DM, EWR. -MU: Smart Stab, HCIM / PWD / DGR. -Load Nukes. MU: TM, 3 X Non-Mag Flex D.C's. 1 Std of HWDP. -Steam Sperry tools due to cold (No communication during upload). 18:00 - 18:30 0.50 DRILL P PROD2 Shallow pulse test MWD tools. -Blow down Top Drive. 18:30 - 20:30 2.00 DRILL P PROD2 MU 2 Jts HWDP & Drlg Jars to 392' md. -RIH w 5" DP to 4,547' md. Fill pipe every 2,000'. 20:30 - 21:00 0.50 DRILL P PROD2 Wash down from 4,547' to 4,595' md. -450 gpm / 1880 psi. Hole looked good. 21:00 - 00:00 3.00 DRILL P PROD2 Drill ahead f/ 4,595' to 4,832' md. -PUW 138k, SOW 108k, ROT wt 124k. -WOB 20k, RPM 80, Tq on 6k, Tq off 5k. -450 gpm / 1900 psi on / 1830 psi off. AST = 1.35 hrs. ART = 0.43 hrs. ADT = 1.78 hrs. 12/9/2008 00:00 - 12:00 12.00 DRILL P PROD2 Directionally drill from 4,832' to 6,059' md. -PUW 145k, SOW 90k, ROT wt 120k. -GPM 430 / 2040 psi on Btm - 1870 psi off Btm. -WOB 4-7k, Tq 7-9 k on Btm - 6k off Btm. AST = 4.91 hrs. ART = 2.01 hrs. ADT = 6.92 hrs. 12:00 - 14:00 2.00 DRILL P PROD2 Circulate hole clean hole clean while rotating 80 rpm. -Reciprocate 90' strokes. Nnnted: iu~wzuoa 1'134:11 YM g p Page 27 of 32 ~ Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/9/2008 12:00 - 14:00 2.00 DRILL P PROD2 14:00 - 16:00 2.00 DRILL P PROD2 16:00 - 16:30 0.50 DRILL P PROD2 16:30 - 19:30 3.00 DRILL N DFAL PROD2 19:30 - 20:30 1.00 DRILL N PROD2 20:30 - 00:00 3.50 DRILL N PROD2 12/10/2008 100:00 - 03:30 I 3.501 DRILL N PROD2 03:30 - 06:00 2.50 DRILL N PROD2 06:00 - 09:00 3.00 DRILL N PROD2 09:00 - 12:00 i 3.001 DRILL ~ P ~ ~ PROD2 12:00 - 14:30 2.501 DRILL P PROD2 14:30 - 17:30 3.00 I DRILL N DPRB PROD2 17:30 - 18:00 ~ 0.50 ~ DRILL ~ N ~ DPRB ~ PROD2 18:00 - 19:30 ~ 1.50 ~ DRILL ~ P ~ ~ PROD2 19:30 - 23:30 4.001 DRILL ~ N ~ DPRB ~ PROD2 -450 gpm / 1780 psi. Pump out of hole from 6,055' to 4,077' md. (inside 9 5/8" casing). -372 gpm / 1300 psi. CBU. Monitor well for 10 minutes inside Csg shoe -static. -Blow down Top Drive. Continue to POH f/ 4,077' to BHA ~ 392' md. (Wet). Clean Rig floor. PJSM on Nukes. -Down load MWD, Flush Motor. -LD Bit & BHA: 7" Sperry Drill Lobe 7/8, Float sub, Stab. -DM HOC, Stab, HCIM/PWD/DGR & TM HOC. -PU: Bit, Geo-Pilot, Flex collar, EW R, Smart stab. -HCIM /PWD /DGR, Nukes, TM HOC, Float sub & Stab. -Upload MWD. Steam & pump through MWD to warm it up for Upload. -Upload MWD. Shallow test MWD &Geo-Pilot. -Load nuclear sources. -MU 6 3/4" D.C's & 5" HWDP. RIH w/ Drlg assy on 5" DP from 391' to 5,390' md. -Fill DP every 2,000'. Wash down last stand to 5,490' md. Begin drilling Kick off trough from 5 500' to 5 550' md. -PUW 138k, SOW 96, ROT wt 118. -425 gpm / 1610 psi. -100 RPM / 5k Tq. -kicked off ~ 5,522' md. Directionally drill new hole from 5,522' to 5,630' md. -PUW 140k, SOW 96k, Rot wt 120k. -450 gpm / 1700 psi. -WOB 5k, RPM 120 / 6k Tq. AST = 2.07 hrs. ART = 0 hrs. ADT = 2.07 hrs. Directionally drill from 5,630' to 5,865' md. -PUW 140k, SOW 96k, Rot wt 120k. -450 gpm / 1700 psi. -WOB 5k, RPM 120 / 6k Tq. POH from 5,865' to 5,301' md. -Take 4 point surveys ~ 5,301' & 5,111' md. -Take single point surveys C 5,079', 5,048' & 5,016' md. RIH from 5,016' to 5,775' md. -Wash down from 5,775' to 5,865' md. -450 gpm / 1620 psi. Directionally drill from 5,865' to 6.147' md. -PUW 138k, SOW 95k, ROT wt 118k. -WOB 10-20k, RPM 90 / 8-10k Tq on / 5-7k Tq off. -400 gpm / 1620 psi. Stand back 1 stand to 6,077' and & circulate. -Wait on Directional survey corrections. -Circulate 400 gpm / 1400 psi. -RPM 70 / 7-9k Tq off. PUW w/ ROT 117k, SOW w/ ROT 110k. Discuss with town the need for an OH sidetrack. rnnceo: iu~wzwa lY:J4:11 rm ~ r gP Page 28 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ,Code ~' NPT Phase ~ Description of Operations 12/10/2008 19:30 - 23:30 4.00 DRILL N DPRB PROD2 23:30 - 00:00 0.50 DRILL N DPRB PROD2 12/11/2008 00:00 - 02:30 2.50 DRILL N DPRB PROD2 02:30 - 03:00 0.50 DRILL N 03:00 - 03:30 0.50 DRILL N 03:30 - 05:00 1.50 DRILL P 05:00 - 06:00 1.00 DRILL N 06:00 - 09:30 3.501 DRILL N 09:30 - 12:00 I 2.501 DRILL I P 12:00 - 00:00 12.00 DRILL P 12/12/2008 100:00 - 10:00 10.00 DRILL P 10:00 - 12:00 12:00 - 15:30 15:30 - 21:30 21:30 - 22:00 22:00 - 23:30 23:30 - 00:00 12/13/2008 00:00 - 01:00 2.00 DRILL P 3.50 DRILL P 6.00 DRILL P 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 1.00 DRILL P DPRB PROD2 DPRB PROD2 PROD2 DPRB PROD2 DPRB I PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 -See remarks. Blow down Top Drive. POH from 6,077' to 5,869' md. AST = 1.74 hrs. ART = 0 hrs. ADT = 1.74 hrs. POH for surveys. Survey: (4,893' and 1-point), (4,799' and 1-point), -(4,703' and 4-points), (4,545' and 1-point), (4,450' and 1-point) Pump out to Csg shoe ~ 4,070' and ~ Drlg rate. -400 gpm / 1400 psi. CBU: 425 gpm / 1350 psi. Cut & slip 59.5' of 1 1/4" drilling line. -Service Top Drive. RIH to 5,207' md. Screw in T.D.- Wash last stand down to 5,300' md. -450 gpm / 1690 psi. Buiilding trough for open hole sidetrack #2. -Trough from 5.340'-5.390' md. -PUW 136k -SOW 100k -ROW 120k. -450 gpm / 1700 psi - 100 rpm w/ 5k tq. -KOP = 5,390' md. Drilling new hole from 5.390' to 5,439' md. -PUW 136k -SOW 100k -ROW 120k. -450 gpm / 1700 psi - 100 rpm w/ 5k tq. AST = 0.45 hrs. ART = 0 hrs. ADT = 0.45 hrs. Directionally drill ahead in OH Sidetrack #2. -Drill from 5,439' to 6,523' md. -PUW 145k -SOW 86k -ROW 117k. -450 gpm / 1750 psi - 100 rpm w/ 7k tq on / 6k Tq off. -WOB 6k. AST = 7.36 hrs. ART = 0 hrs. ADT = 7.36 hrs. Continue to directionally drill ahead in OH Sidetrack #2. -Drill from 6,523' to 7,605' md. ~ -PUW 145k -SOW 85k -ROW 117k. -450 gpm / 1810 psi - 100 rpm w/ 8k tq on / 7k Tq off. -WOB 5-7k. CBU X 3. -450 gpm / 1820 psi. RPM 90 /7-9k Tq off Btm. Pump out of the hole from 7,605' to 5,400' md. -400 gpm / 1560 psi. MADD pass from 5,400' up to 4,545' md. -200 FPH. 375 gpm / 1200 psi. -RPM 30 / 5-6k Tq off Btm. Pump out of the hole 4,545' to 4,075' md. 400 gpm / 1120 psi. Circulate Csg clean. -420 gpm / 1160 psi. Monitor well -static. RIH w/ 5" DP from 4,075' to 5,301' md. MU Top Drive ~ 5,301' md. rnncea: izisuizuuo izsv:i i rm • • gP Page 29 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2008 ~ 00:00 - 01:00 ~ 1.00 ~ DRILL ~ P 01:00 - 02:00 I 1.001 DRILL I P 02:00 - 03:30 1.50 DRILL P 03:30 - 04:00 0.50 DRILL P 04:00 - 05:30 1.50 DRILL P 05:30 - 11:00 I 5.501 DRILL I P 11:00 - 11:30 0.50 DRILL P 11:30 - 12:00 0.50 DRILL P 12:00 - 12:30 0.50 DRILL P 12:30 - 15:00 2.50 DRILL P 15:00 - 19:00 I 4.001 DRILL I P 19:00 - 21:00 2.001 CASE ~ P 21:00 - 00:00 I 3.001 CASE I P 12/14/2008 00:00 - 02:30 2.50 CASE P 02:30 - 04:00 1.50 CASE P 04:00 - 12:00 8.00 CASE P 12:00 - 12:30 I 0.501 CASE I P PROD2 -Circulate & Orient Geo-Pilot to enter OH Sidetrack #2. -RIH from 5,301' to 5,480' and slowly taking surveys. -Blow down Top Drive. PROD2 Continue to RIH to 6,680' md. -Tight spot noted ~ 6,680' to 6,700' md. -Work through tight spot two times -good. -Continue to RIH to 7,605' md. - PROD2 Circulate, clean up hole. -400 gpm / 1540 psi. PROD2 PJSM on displacement to Versa Pro OBM. -Continue to Circulate. Clean Pits. PROD2 Displace to 9.2 ppg Versa Pro SF from Rheliant MOBM. -Pump: 40 bbls LVT. 650 bbls of Versa Pro. -450 gpm / 1720 psi. 50 RPM. PROD2 Pump out of hole from 7,605' to 4,075' md. -382 gpm / 1300 psi. -Tight spots noted ~ 6,690' & 6,580' md. -Worked through tight spots -Good. -Drop Rabbit on Std # 24. PROD2 Reciprocate & rotate while CBU X 2. -525 gpm / 2150 psi. PROD2 Blow down Top Drive &Geo-Pilot skid. -POH from 4,075' to 3,800' and w/ 5" DP. PROD2 Lubricate Rig, Blocks, Swivel packing & Draw works. PROD2 Continue to POH from 3,800' to BHA 118' md. NOTE: -Function test Bag, Top & Btm Rams. -Function test HCR Kill &HCR Choke ~ 485' md. PROD2 PJSM on Nukes: Remove Nukes. -Down load MWD. -LD: NMDC's, TM, Nuke tool, PWD, Stabs, Float sub. -LD: EWR, DM, Geo-Pilot & Bit. PROD2 Clear Rig floor of all tools not needed for upcoming job. -PU 7" Csg equipment._ -Remove Iron Roughneck track. PROD2 PJSM on running 7" 29# slotted liner & 7" 26# solid liner (all BTC-M). -Run 7" liner to 2,390' md. -Place floating centralizers on Jt # 21, Jt # 26 & Jt # 34. -Utilize "Best O Life 2000" Thread compound. PROD2 Continue to run 7" 26# liner (wet) from 2,390' to 3,667' md. PROD2 RD: Conventional Power Tongs & Elevators. -Clear & clean Rig floor. -PU: False table, 2 7/8" Elevators, Torque Turn equipment. -PU Stack Tongs. PROD2 PJSM on running 2 7/8" work string. -RU & run 115 joints + pup (3,566.73') 2 7/8" inner string. -Torque turn all connections to optimum 1930 ft/Ibs. -PU space out pups -Tag drillable packoff. -LD space out pups. PROD2 MU ZXP Liner hanger assembly. '~ -RI w 5 stan s o and (20' above 9 5/8" shoe). rnntea: iuauizv~n IL:S4:1 I nw gp Page 30 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To i Hours Task Code NPT Phase Description of Operations 12/14/2008 12:00 - 12:30 0.50 CASE P PROD2 12:30 - 13:00 0.501 CASE P PROD2 13:00 - 18:00 ~ 5.001 CASE P PROD2 18:00 - 19:00 ~ 1.00 ~ CASE ~ P ~ ~ PROD2 19:00 - 19:30 I 0.501 CASE I P I I PROD2 19:30 - 00:00 4.50 CASE P PROD2 12/15/2008 00:00 - 02:30 2.50 CASE P PROD2 02:30 - 03:30 1.00 CASE P PROD2 03:30 - 10:30 7.00 CASE P PROD2 10:30 - 11:30 1.00 CASE P PROD2 11:30 - 12:00 0.50 CASE N HMAN PROD2 12:00 - 15:00 3.00 CASE N HMAN PROD2 15:00 - 17:00 2.00 CASE N HMAN PROD2 17:00 - 00:00 7.00 CASE N WAIT PROD2 12/16/2008 00:00 - 02:00 2.00 CASE N WAIT PROD2 02:00 - 03:00 1.00 CASE N HMAN PROD2 03:00 - 03:30 0.50 CASE P PROD2 03:30 - 05:00 1.50 CASE P PROD2 Note: Dropped a 3/4" X 3" pin down hole. -Pin was holding the slip handles onto the slips. Break circulation w/ 105 gpm / 750 psi. -Stage up to 147 gpm / 850 psi. -RD 2 7/8" Tongs, RD False table. -Install Iron roughneck track. RIH w/ 7" liner & 2 7/8" work string on 5" DP. -RIH from 3,648' to 7,605' md. Tagged Btm ~ 7,611' md. -Pumped DP volume ~ 4,119' and due to over flow out DP. -126 gpm / 740 psi. -Subsequently, screwed Top Drive into each JT. / -Screw in to eliminate over flow of MOBM. Obtain parameters: PUW 180k, SOW 80k. -PU to spot shoe ~ 7,605' md. -Drop 29/32 Ball. Pump ball down. -Initial pump rate 126 gpm / 810 psi. -Final pump rate 42 gpm / 420 psi. -Ball set C~ 663 Stks. Pressure up to 2000 psi. -Liner Hanger set ~ 1800 psi. -Continue to pressure up to 4000 psi. -ZXP packer set ~ 3900 psi. -Liner Top ~ 3,967' md. -Rotate off Hanger w/ 15 RH turns. Pull up 1'. -Test backside to 1500 psi f/ 15 minutes. -Chart test - OK. -Pull running Tool out of Liner. POH w/ Running Tools from 3,967' to 3,589' md. -Stand back 4 Stds. LD 5" DP from 3,589'to 1,000', 5" DP measurement depth. Continue to LD 5" DP from 1,000' to 0', 5" DP depth. Service break all Baker Liner running Tools. RU 2 7/8" handling equipment. -LD 2 7/8" FOX work string from 3,547' to surface. -Pulling wet. -Vacuum OBM from each Jt before laying down. LD Slick stick, clean Tools. -Clear & clean Rig floor. PU Lubricator extension. -Set & PU SLB Slick line Tools. PJSM. -RU Slick line. MU Slick line Tools. -Pressure test Lubricator to 400 psi -Pass. RIH w/ Gauge Ring & Junk Basket inside 9 5/8" Csa. -RIH to 3,952' Slick line measurement. -No pin found. -PJSM on RD SLB. -RD SLB & leave on Rig floor due to Phase 3 conditions. Stand down due to Phase 3 conditions. In contact w/ Herb Williams & IMT. Continue stand down due to Phase 3 weather. RD & LD: SLB equipment & Tools. PU & MU RBP running tool & 9 5/8" RBP. RIH w/ 9-5/8" RBP on 5" DP f/ surface to 3950'. rnntea: uiswzuuts rr.~a:n rm gP Page 31 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task I Code ~ NPT Phase Description of Operations 12/16/2008 03:30 - 05:00 1.50 CASE P 05:00 - 06:30 1.50 CASE P 06:30 - 12:00 5.50 CASE N 12:00 - 15:30 3.50 CASE P 15:30 - 18:00 2.501 CASE P 18:00 - 19:30 1.50 CASE P 19:30 - 20:00 0.50 CASE P 20:00 - 21:30 1.50 CASE P 21:30 - 00:00 2.50 CASE P 12/17/2008 00:00 - 00:30 0.50 CASE P 00:30 - 02:00 1.501 WHSUR P 02:00 - 02:30 0.50 RU 02:30 - 05:30 3.00 RU 05:30 - 06:00 I 0.50 06:00 - 07:30 1.501 WHSUR P 07:30 - 09:00 1.501 BOPSUgP 09:00 - 12:00 3.001 WHSUR P 12:00 - 14:30 I 2.501 WHSUR I P PROD2 -Obtain parameters: PUW 115k /SOW 108k. PROD2 -Set 9-5/8" RBP per HES Rep COE ~ 3950' Too of RflP, F. N ~ 3945'. -Rack back 1 stand 5" DP. RU testing equipment. -Test RBP to 1000 six 15 min on chart. -RD testing equipment. Blow down cement and kill lines. WAIT PROD2 Circulate well while waiting on 9.7 ppg brine to arrive due to road conditions after Phase 3 weather. PROD2 Dis lace well w/ 9.7 brine -Pump 40 bbls LVT + 25 bbls hi-vis spacer + 50 bbls Safe Surf O pill + 25 bbls hi-vis spacer + 200 bbls seawater. -Pump 280 bbls 9.7 ppg brine. -210 gpm ~ 460 psi (ICP) / 90 psi (FCP). PROD2 -RU and dum 1200# of 20-40 sand n t -Pump 35 bbls 9.7 ppg brine. -Rack back 1 stand 5" DP. Pump 25 bbls 9.7 ppg brine. Rack back another stand 5" DP. PROD2 P to pipe shed f/ 3875' to 2374'. PROD2 RIH 4 stands 5" DP f/ derrick to 2751'. PROD2 -Cut and slip drilling line (59.5'). -Service top drive and blocks. PROD2 Cont. POOH and LD 5" DP to pipe shed f/ 2751' to surface. PROD2 -LD RBP running tool and clear rig floor. -Inspect and service top drive. PROD2 -Pull wear bushing. -Install isolation sleeve in wellhead. Test same to 3000 psi x 15 min per FMC Rep. RUNCMP RU to run 4-1/2" kill strin C/O elevators, install power tongs. RUNCMP -PU 4-1/2" jt #1. MU 4-1/2" WLEG on bottom of jt and 4-1/2" X-nipple on top of jt. -Run 4-1/2" 12.6# - I - '. Total jts run: RUNCMP -MU tubing hanger and landing jt. -Land tubing hanger. RILDS. -PUW 72k /SOW 74k RUNCMP -Back out and LD landing jt. -FMC Re . d rod TWC. -RU testing equipment. Test TWC f/ above to 3000 osi x 10 min on chart Test f/ below to 1000 psi x 10 min on chart. RD testing equipment. RUNCMP -Blow down hole fill and bleeder lines. -Vac out BOP stack. -LD mouse hole and riser. -ND BOP and choke line. RUNCMP -NU adapter flange and dry hole tree. -Test adapter void to 5000 psi x 30 min per FMC Rep. -Test dry hole tree w/diesel to 3000 psi x 15 min on chart. RUNCMP -Install DSM lubricator and extensions and test to 500 psi x 5 min. -Pull TW -RU Little Red Services and test lines to 3500 psi. -Little Red pumps 14 bbls diesel down IA, taking returns out tubing, for freeze protect. Printed: 12/30/2008 12:34:11 PM gP Page 32 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT ~ Phase ~ Description of Operations 12/17/2008 14:30 - 15:30 1.00 WHSUR P RUNCMP -Jump IA to tubing. Let diesel U-tube. -Clear rig floor in preparation for rig move while U-tubing diesel. 15:30 - 16:30 1.00 WHSUR P RUNCMP -Check pressures. Blow down lines and RD tubing side. -Test BPV f/ below to 1000 psi x 10 min on chart. Use diesel f/ test w/ Little Red. -Little Red suck out lines. RD Little Red. 16:30 - 18:00 1.50 WHSUR P RUNCMP -Remove secondary valve in IA and pump in flanges. -Install blank flanges and gauges. -Secure cellar. OA=O psi / IA=O psi / TBG=O psi. Release ria ~ 18:00. Nrinted: i[iawtuua ir:w:ii rnn Sperry Drilling Services Survey Report Company: BP Amoco Date: 12/30/2008 Time: 13:32:45 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: MPS-41, True North Site: M Pt S Pad Vertical (TVD) Refer ence: MPS-41 71.5 I Well: MPS-41 Section (VS) Reference: Well (O.OON,O.OOE,1 21.73Azi) 1 ~'1'cllpath: MPS-41A Survey Calculation Method: Minimum Curvature llb: Oracle Survey DID Iucl Azim TVD SysTVll N/S E/W b1apN MapE 1'001 ft deg deg ft ft ft ft ft ft ' - ___ 33.74 0.00 0.00 33.74 -37.79 0.00 0.00 5999888.58 565493.29 TIE LINE 73.00 0.38 334.02 73.00 1.47 0.12 -0.06 5999888.70 565493.23 CB-GYRO-MS 162.00 0.21 222.16 162.00 90.47 0.26 -0.30 5999888.84 565492.99 CB-GYRO-MS 251.00 0.46 272.88 251.00 179.47 0.16 -0.76 5999888.73 565492.53 CB-GYRO-MS 351.00 0.42 232.13 350.99 279.46 -0.05 -1.45 5999888.52 565491.84 CB-GYRO-MS 442.00 0.74 181.86 441.99 370.46 -0.84 -1.73 X999887.73 565491.56 CB-GYRO-MS 528.63 1.47 146.58 528.60 457.07 -2.33 -1.14 5999886.25 565492.17 MWD+IFR+MS 618.13 3.06 135.98 618.09 546.50 -5.00 1.15 5999883.59 565494.49 MWD+IFR+MS 706.57 3.91 137.59 706.31 634.78 -8.93 4.83 5999879.70 565498.19 MWD+IFR+MS 803.02 4.62 140.99 802.49 730.96 -14.37 9.49 5999874.29 565502.90 MWD+IFR+MS 896.82 5.85 144.37 895.90 824.37 -21.19 14.65 5999867.52 565508.13 MWD+IFR+MS 989.19 8.31 143.02 987.56 916.03 -30.35 21.41 5999858.42 565514.96 MWD+IFR+MS 1083.61 10.18 145.31 1080.75 1009.22 -42.66 30.26 5999846.19 565523.92 MWD+IFR+MS 1180.79 12.08 149.01 1176.10 1104.57 -58.45 40.39 5999830.50 565534.19 MWD+IFR+MS 1275.09 15.30 145.49 1267.71 1196.18 -77.16 52.52 5999811.89 565546.48 MWD+IFR+MS 1366.86 17.89 144.26 1355.65 1284.12 -98.58 67.62 5999790.60 565561.76 MWD+IFR+MS 1460.55 19.33 146.04 1444.44 1372.91 -123.13 84.69 5999766.21 565579.04 MWD+IFR+MS 1553.82 19.10 144.74 1532.51 1460.98 -148.39 102.12 5999741.10 565596.70 MWD+IFR+MS 1648.35 20.12 146.37 1621.56 1550.03 -174.56 120.05 5999715.10 565614.86 MWD+IFR+MS 1742.45 22.69 144.96 1709.16 1637.63 -202.90 139.44 5999686.93 565634.49 MWD+IFR+MS 1837.55 25.49 142.98 1795.97 1724.44 -234.26 162.30 5999655.77 565657.62 MWD+IFR+MS 1931.98 25.42 142.91 1881.23 1809.70 -266.65 186.75 5999623.60 565682.36 MWD+IFR+MS 2024.99 26.28 147.47 1964.94 1893.41 -299.94 209.87 5999590.52 565705.76 MWD+IFR+MS 2119.30 26.53 149.59 2049.42 1977.89 -335.71 231.75 5999554.95 565727.96 MWD+IFR+MS 2213.60 26.59 153.10 2133.77 2062.24 -372.69 251.96 5999518.15 565748.49 MWD+IFR+MS 2307.25 29.86 155.79 2216.28 2144.75 -412.66 271.01 5999478.35 565767.89 MWD+IFR+MS 2402.97 33.72 158.11 2297.62 2226.09 -459.06 290.70 5999432.13 565787.98 MWD+IFR+MS Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 Well: MPS-41 Slot Name: 5002923401 Well Position: +N/-S -81.86 ft Northing: 5999888.58 ft Latitude: 70 24 36.523 N +E/-W -852.55 ft Easting : 565493.29 ft Longitude: 149 28 0.159 W Position Uncertainty: 0.00 ft Wellpath: MPS-41A 500292340101 Drilled From: Tie-on Depth: MPS-41AP61 5390.00 ft Current Datum: MPS-41 Height 71.53 ft Above System Datum: Mean Sea Level Magnetic Data: 11 /15/2008 Field Strength: 57662 nT Declination: Mag Dip Angle: 22.62 deg 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.74 0.00 0.00 121.73 Survey Program for Definitive Wellpath Date: 12/30/2008 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft 33.74 442.00 MPS-41 CB-GYRO-MS (33.74-442.0 CB-GYRO-MS Camera based gyro multishot 442.00 4140.00 MPS-41 MWD+SAG+CA+IIFR+MS (44 MWD+IFR+MS MWD +IFR + Multi Station 4145.00 5352.28 MPS-41APB1 MWD+SAG+CA+IIFR+MS MWD+IFR+MS MWD +IFR + Multi Station 5390.00 7574.10 MPS-41A MWD+SAG+CA+IIFR+MS (5 MWD+IFR+MS MWD +IFR + Multi Station • Sperry Drilling Services Survey Report Compxuy: BP Amoco Date: 12/30/2008 Timc: 13:32:45 Page: 2 'I Field: Mi lne Point Co-ord inate(NE) Reference: Well: MPS-41, True North I Site: M Pt S Pad Vertical (TVD) Reference: MPS -41 71.5 ~ Well: MPS-41 Section (VS) Referen ce: Well (O.OON,O.OOE,1 21.73Azi) Wellpath: MPS-41 A Survey Calculation M ethod: Minim um Curvature Db: Oracle Survev MD [ncl LILIITI TVD Sys TVD NlS E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2499.15 34.51 159.04 2377.25 2305.72 -509.28 310.40 5999382.09 565808.11 MWD+IFR+MS 2593.48 38.00 160.17 2453.31 2381.78 -561.57 329.81 5999329.98 565827.98 MWD+IFR+MS 2687.91 39.94 163.58 2526.73 2455.20 -618.00 348.25 5999273.72 565846.91 MWD+IFR+MS 2782.87 43.38 166.17 2597.67 2526.14 -678.92 364.67 5999212.94 565863.86 MWD+IFR+MS 2876.92 44.01 169.75 2665.68 2594.15 -742.45 378.20 5999149.55 565877.95 MWD+IFR+MS 2972.26 44.46 168.93 2733.99 2662.46 -807.81 390.51 5999084.30 565890.83 MWD+IFR+MS 3067.08 45.04 167.41 2801.33 2729.80 -873.14 404.20 5999019.10 565905.09 MWD+IFR+MS 3159.00 46.30 164.77 2865.57 2794.04 -936.95 420.01 5998955.44 565921.46 MWD+IFR+MS 3251.92 48.12 161.29 2928.70 2857.17 -1002.14 439.94 5998890.43 565941.96 MWD+IFR+MS 3344.07 48.12 159.70 2990.22 2918.69 -1066.81 462.85 5998825.98 565965.43 MWD+IFR+MS 3433.40 48.76 155.08 3049.50 2977.97 -1128.47 488.54 5998764.54 565991.66 MWD+IFR+MS 3531.19 49.57 150.38 3113.46 3041.93 -1194.19 522.44 5998699.13 566026.13 MWD+IFR+MS 3624.43 49.43 147.26 3174.03 3102.50 -1254.84 559.14 5998638.81 566063.36 MWD+IFR+MS 3713.98 49.24 143.87 3232.39 3160.86 -1310.85 597.54 5998583.14 566102.24 MWD+IFR+MS 3812.99 51.90 141.18 3295.27 3223.74 -1371.51 644.08 5998522.90 566149.31 MWD+IFR+MS 3910.89 55.17 138.75 3353.46 3281.93 -1431.75 694.74 5998463.11 566200.49 MWD+IFR+MS 4003.51 57.73 135.56 3404.65 3333.12 -1488.31 747.24 5998407.02 566253.48 MWD+IFR+MS 4098.42 58.16 134.31 3455.02 3383.49 -1545.12 804.18 5998350.72 566310.91 MWD+IFR+MS 4140.00 57.90 134.09 3477.04 3405.51 -1569.71 829.47 5998326.35 566336.41 MWD+IFR+MS 4145.00 57.87 134.07 3479.70 3408.17 -1572.66 832.51 5998323.43 566339.48 MWD+IFR+MS 4228.48 59.65 133.79 3522.99 3451.46 -1622.17 883.91 5998274.38 566391.31 MWD+IFR+MS 4323.01 62.84 135.61 3568.46 3496.93 -1680.47 942.80 5998216.60 566450.69 MWD+IFR+MS 4412.75 65.10 132.98 3607.85 3536.32 -1736.76 1000.51 5998160.83 566508.90 MWD+IFR+MS 4511.55 67.71 132.28 3647.39 3575.86 -1798.07 1067.13 5998100.11 566576.04 MWD+IFR+MS 4593.70 69.90 132.68 3677.09 3605.56 -1849.79 1123.61 5998048.89 566632.97 MWD+IFR+MS 4688.39 72.46 130.55 3707.64 3636.11 -1909.30 1190.61 5997989.98 566700.49 MWD+IFR+MS 4782.21 75.54 126.93 3733.50 3661.97 -1965.70 1260.95 5997934.20 566771.31 MWD+IFR+MS 4880.91 80.32 125.25 3754.14 3682.61 -2022.52 1338.93 5997878.07 566849.77 MWD+IFR+MS 4973.05 86.68 122.15 3764.56 3693.03 -2073.27 1415.05 5997827.99 566926.33 MWD+IFR+MS 5067.00 88.07 120.34 3768.87 3697.34 -2121.95 1495.29 5997780.02 567006.98 MWD+IFR+MS 5161.86 89.10 118.00 3771.21 3699.68 -2168.17 1578.08 5997734.54 567090.17 MWD+IFR+MS 5257.80 91.73 115.81 3770.51 3698.98 -2211.57 1663.62 5997691.89 567176.08 MWD+IFR+MS 5352.28 91.94 113.49 3767.49 3695.96 -2250.96 1749.44 5997653.26 567262.24 MWD+IFR+MS 5390.00 89.94 116.06 3766.87 3695.34 -2266.76 1783.68 5997637.76 567296.61 MWD+IFR+MS 5456.74 88.34 115.78 3767.87 3696.34 -2295.93 1843.70 5997609.13 567356.87 MWD+IFR+MS 5549.03 89.83 113.88 3769.35 3697.82 -2334.67 1927.44 5997571.12 567440.95 MWD+IFR+MS 5635.81 89.52 109.89 3769.84 3698.31 -2367.01 2007.95 5997539.49 567521.73 MWD+IFR+MS 5733.19 90.20 106.60 3770.08 3698.55 -2397.50 2100.42 5997509.82 567614.45 MWD+IFR+MS 5827.50 90.26 104.34 3769.70 3698.17 -2422.65 2191.31 5997485.47 567705.55 MWD+IFR+MS 5922.51 90.69 102.41 3768.91 3697.38 -2444.63 2283.73 5997464.30 567798.15 MWD+IFR+MS 6020.27 90.13 101.18 3768.21 3696.68 -2464.61 2379.42 5997445.16 567894.01 MWD+IFR+MS 6116.13 90.82 98.94 3767.42 3695.89 -2481.35 2473.80 5997429.25 567988.52 MWD+IFR+MS 6209.82 91.00 96.39 3765.93 3694.40 -2493.85 2566.63 5997417.57 568081.45 MWD+IFR+MS 6301.54 90.51 93.46 3764.72 3693.19 -2501.72 2658.00 5997410.50 568172.87 MWD+IFR+MS 6398.42 89.27 89.69 3764.90 3693.37 -2504.38 2754.82 5997408.69 568269.70 MWD+IFR+MS 6489.36 88.96 85.29 3766.31 3694.78 -2500.40 2845.64 5997413.46 568360.47 MWD+IFR+MS 6586.31 87.96 82.15 3768.92 3697.39 -2489.80 2941.96 5997424.91 568456.69 MWD+IFR+MS 6680.84 87.73 82.00 3772.47 3700.94 -2476.75 3035.52 5997438.75 568550.12 MWD+IFR+MS 6773.69 86.37 81.32 3777.25 3705.72 -2463.33 3127.27 5997453.00 568641.74 MWD+IFR+MS 6867.79 85.75 82.46 3783.72 3712.19 -2450.08 3220.20 5997467.06 568734.54 MWD+IFR+MS 6960.33 86.25 84.05 3790.17 3718.64 -2439.24 3311.87 5997478.70 568826.11 MWD+IFR+MS 7054.19 86.31 86.26 3796.26 3724.73 -2431.33 3405.20 5997487.43 568919.35 MWD+IFR+MS 7147.54 87.67 88.39 3801.16 3729.63 -2426.98 3498.31 5997492.59 569012.41 MWD+IFR+MS • • Sperry Drilling Services Survey Report Company: BPAmoco Date: 12/30/2008 Ti me: 13:32:45 Yage: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: MPS-41, True North Site: M Pt S Pad .Vertical (TVD) Reference: MPS-41 71.5 Wdl: MPS-41 Section (VS) Reference: Well (O.OON,O.OOE,121.73Azi) Wellpalh: MPS-41A Survc}~ Calculation Method: Minimum Curvature DU: Oracle Survey Mll ft Incl deg Azim deg TVD ft Svs TVD ft N/S ft E/~V ft MapN ft MapE ft Tool 7241.89 87.30 90.37 3805.30 3733.77 -2425.96 3592.56 5997494.44 569106.64 MWD+IFR+MS 7336.15 89.27 92.01 3808.13 3736.60 -2427.92 3686.75 5997493.31 569200.83 MWD+IFR+MS 7428.14 90.26 93.41 3808.50 3736.97 -2432.27 3778.63 5997489.77 569292.74 MWD+IFR+MS 7522.56 90.63 94.73 3807.77 3736.24 -2438.97 3872.81 5997483.89 569386.96 MWD+IFR+MS 7574.10 90.01 94.85 3807.48 3735.95 -2443.27 3924.17 5997480.04 569438.35 MWD+IFR+MS 7605.00 90.01 94.85 3807.48 3735.95 -2445.89 3954.95 5997477.70 569469.16 PROJECTED to TD ti Sperry Drilling Services Survey Report Company: BP Amoco __ llate: 12F30/2008 _ Time: 13:45:45 Page: 1 ~I Field: Mihie Point Co-ordinate(NE) Reference: Well: MPS-41, True North Site: M Pt S Pad Vertical (TVD) Refer ence. MPS-41 71.5 Well: MPS-41 Section (VS) Ret'crence: Well (O.OON,O.OOE,1 35.19Azi) Wellpath: MPS-41 APB1 Survey Galculatiou >V lethod: Minimum Curvature Db: Oracle Survey n1D Intl Azim TVD $ys TVD N/S G/W 11apN 1\1apL Tool ft deg deg ft ft ft ft ft ft ~ 33.74 0.00 0.00 33.74 -37.79 0.00 0.00 5999888.58 565493.29 TIE LINE 73.00 0.38 334.02 73.00 1.47 0.12 -0.06 5999888.70 565493.23 CB-GYRO-MS 162.00 0.21 222.16 162.00 90.47 0.26 -0.30 5999888.84 565492.99 CB-GYRO-MS 251.00 0.46 272.88 251.00 179.47 0.16 -0.76 5999888.73 565492.53 CB-GYRO-MS 351.00 0.42 232.13 350.99 279.46 -0.05 -1.45 5999888.52 565491.84 CB-GYRO-MS 442.00 0.74 181.86 441.99 370.46 -0.84 -1.73 5999887.73 565491.56 CB-GYRO-MS 528.63 1.47 146.58 528.60 457.07 -2.33 -1.14 5999886.25 565492.17 MWD+IFR+MS 618.13 3.06 135.98 618.03 546.50 -5.00 1.15 5999883.59 565494.49 MWD+IFR+MS 706.57 3.91 137.59 706.31 634.78 -8.93 4.83 5999879.70 565498.19 MWD+IFR+MS 803.02 4.62 140.99 802.49 730.96 -14.37 9.49 5999874.29 565502.90 MWD+IFR+MS 896.82 5.85 144.37 895.90 824.37 -21.19 14.65 5999867.52 565508.13 MWD+IFR+MS 989.19 8.31 143.02 987.56 916.03 -30.35 21.41 5999858.42 565514.96 MWD+IFR+MS 1083.61 10.18 145.31 1080.75 1009.22 -42.66 30.26 5999846.19 565523.92 MWD+IFR+MS 1180.79 12.08 149.01 1176.10 1104.57 -58.45 40.39 5999830.50 565534.19 MWD+IFR+MS 1275.09 15.30 145.49 1267.71 1196.18 -77.16 52.52 5999811.89 565546.48 MWD+IFR+MS 1366.86 17.89 144.26 1355.65 1284.12 -98.58 67.62 5999790.60 565561.76 MWD+IFR+MS 1460.55 19.33 146.04 1444.44 1372.91 -123.13 84.69 5999766.21 565579.04 MWD+IFR+MS 1553.82 19.10 144.74 1532.51 1460.98 -148.39 102.12 5999741.10 565596.70 MWD+IFR+MS 1648.35 20.12 146.37 1621.56 1550.03 -174.56 120.05 5999715.10 565614.86 MWD+IFR+MS 1742.45 22.69 144.96 1709.16 1637.63 -202.90 139.44 5999686.93 565634.49 MWD+IFR+MS 1837.55 25.49 142.98 1795.97 1724.44 -234.26 162.30 5999655.77 565657.62 MWD+IFR+MS 1931.98 25.42 142.91 1881.23 1809.70 -266.65 186.75 5999623.60 565682.36 MWD+IFR+MS 2024.99 26.28 147.47 1964.94 1893.41 -299.94 209.87 5999590.52 565705.76 MWD+IFR+MS 2119.30 26.53 149.59 2049.42 1977.89 -335.71 231.75 5999554.95 565727.96 MWD+IFR+MS 2213.60 26.59 153.10 2133.77 2062.24 -372.69 251.96 5999518.15 565748.49 MWD+IFR+MS 2307.25 29.86 155.79 2216.28 2144.75 -412.66 271.01 5999478.35 565767.89 MWD+IFR+MS 2402.97 33.72 158.11 2297.62 2226.09 -459.06 290.70 5999432.13 565787.98 MWD+IFR+MS 2499.15 34.51 159.04 2377.25 2305.72 -509.28 310.40 5999382.09 565808.11 MWD+IFR+MS Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: MPS-41 Slot Name: 5002923401 Well Position: +N/-S -81.86 ft Northing: 5999888.58 ft Latitude: 70 24 36.523 N +E/-W -852.55 ft Easting : 565493.29 ft Longitude: 149 28 0.159 W Position Uncertainty: 0.00 ft Wellpath: MPS-41AP61 Drilled From: MPS-41 500292340170 Tie-on Depth: 4145.00 ft Current Datum: MPS-41 Height 71.53 ft Above System Datum: Mean Sea Level Magnetic Data: 11/15/2008 Declination: 22.62 deg Field Strength: 57662 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg. 33.74 0.00 0.00 135.19 Survey Program for Definitive Wellpath Date: 12/28/2008 Validated: Yes Version: 9 Actual From To Survey Toolcode Tool Name ft ft 33.74 442.00 MPS-41 CB-GYRO-MS (33.74-442.0 CB-GYRO-MS Camera based gyro multishot 442.00 4140.00 MPS-41 MWD+SAG+CA+IIFR+MS (44 MWD+IFR+MS MWD +IFR + Multi Station 4145.00 6012.48 MPS-41APB1 MWD+SAG+CA+IIFR+MS MWD+IFR+MS MWD +IFR + Multi Station f ) . • Sperry Drilling Services Survey Report - .Company: BP Amoco - - _ -- Date: - - 12/30/2008 Time: 13 :45:45 Page: 2 Field: Mi lne Poi nt Co-ord inate(NE) Ref ertn~e: Well: MPS-41, True North Site: M Pt S P ad Vertical (TVD) Refer ence: MPS- 41 71 .5 Well: M PS-41 Section (VS) Keference: Well ( O.OON,O. OOE, 135.19Azi) ~ ~ Wdlpath: M PS-41AP61 Survev Calcula tion M ethod: Minim um Curv ature llb: Oracle ~~, Survey _ fvID L~cl Azim TVD Sys TVD NlS E/W MapN Map>J Tool ft deg deg ft ft fit ft ft ft 2593. 48 38 .00 160. 17 2453 .31 2381. 78 -561.57 329. 81 5999329. 98 565827. 98 MWD+IFR+MS 2687. 91 39 .94 163. 58 2526 .73 2455. 20 -618.00 348. 25 5999273. 72 565846. 91 MWD+IFR+MS 2782. 87 43 .38 166. 17 2597 .67 2526. 14 -678.92 364. 67 5999212. 94 565863. 86 MWD+IFR+MS 2876. 92 44 .01 169. 75 2665 .68 2594. 15 -742.45 378. 20 5999149. 55 565877. 95 MWD+IFR+MS 2972. 26 44 .46 168. 93 2733 .99 2662. 46 -807.81 390. 51 5999084. 30 565890. 83 MWD+IFR+MS 3067. 08 45 .04 167. 41 2801 .33 2729. 80 -873.14 404. 20 5999019. 10 565905. 09 MWD+IFR+MS 3159. 00 46 .30 164. 77 2865 .57 2794. 04 -936.95 420. 01 5998955. 44 565921. 46 MWD+IFR+MS 3251. 92 48 .12 161. 29 2928 .70 2857. 17 -1002.14 439. 94 5998890. 43 565941. 96 MWD+IFR+MS 3344. 07 48 .12 159. 70 2990 .22 2918. 69 -1066.81 462. 85 5998825. 98 565965. 43 MWD+IFR+MS 3433. 40 48 .76 155. 08 3049 .50 2977. 97 -1128.47 488. 54 5998764. 54 565991. 66 MWD+IFR+MS 3531. 19 49 .57 150. 38 3113 .46 3041. 93 -1194.19 522. 44 5998699. 13 566026. 13 MWD+IFR+MS 3624. 43 49 .43 147. 26 3174 .03 3102. 50 -1254.84 559. 14 5998638. 81 566063. 36 MWD+IFR+MS 3713. 98 49 .24 143. 87 3232 .39 3160. 86 -1310.85 597. 54 5998583. 14 566102. 24 MWD+IFR+MS 3812. 99 51 .90 141. 18 3295 .27 3223. 74 -1371.51 644. 08 5998522. 90 566149. 31 MWD+IFR+MS 3910. 89 55 .17 138. 75 3353 .46 3281. 93 -1431.75 694. 74 5998463. 11 566200. 49 MWD+IFR+MS 4003. 51 57 .73 135. 56 3404 .65 3333. 12 -1488.31 747. 24 5998407. 02 566253. 48 MWD+IFR+MS 4098. 42 58 .16 134. 31 3455 .02 3383. 49 -1545.12 804. 18 5998350. 72 566310. 91 MWD+IFR+MS 4139. 72 57 .90 134 .09 3476 .89 3405. 36 -1569.54 829. 30 5998326. 52 566336. 24 9 5/8" 4140. 00 57 .90 134 .09 3477 .04 3405. 51 -1569.71 829. 47 5998326. 35 566336. 41 MWD+IFR+MS 4145. 00 57 .87 134 .07 3479 .70 3408.. 17 -1572.66 832. 51 5998323. 43 566339. 48 MWD+IFR+MS 4228. 48 59 .65 133 .79 3522 .99 3451 .46 -1622.17 883. 91 5998274. 38 566391. 31 MWD+IFR+MS 4323. 01 62 .84 135 .61 3568 .46 3496 .93 -1680.47 942. 80 5998216. 60 566450. 69 MWD+IFR+MS 4412. 75 65 .10 132 .98 3607 .85 3536 .32 -1736.76 1000. 51 5998160. 83 566508. 90 MWD+IFR+MS 4511. 55 67 .71 132 .28 3647 .39 3575 .86 -1798.07 1067. 13 5998100. 11 566576. 04 MWD+IFR+MS 4593. 70 69 .90 132 .68 3677 .09 3605 .56 -1849.79 1123. 61 5998048. 89. 566632. 97 MWD+IFR+MS 4688. 39 72 .46 130 .55 3707 .64 3636 .11 -1909.30 1190. 61 5997989. 98 566700. 49 MWD+IFR+MS 4782. 21 75 .54 126 .93 3733 .50 3661 .97 -1965.70 1260. 95 5997934. 20 566771. 31 MWD+IFR+MS 4880. 91 80 .32 125 .25 3754 .14 3682 .61 -2022.52 1338. 93 5997878. 07 566849. 77 MWD+IFR+MS 4973. 05 86 .68 122 .15 3764 .56 3693 .03 -2073.27 1415. 05 5997827. 99 566926. 33 MWD+IFR+MS 5067. 00 88 .07 120 .34 3768 .87 3697 .34 -2121.95 1495. 29 5997780. 02 567006. 98 MWD+IFR+MS 5161. 86 89 .10 118 .00 3771 .21 3699 .68 -2168.17 1578. 08 5997734. 54 567090. 17 MWD+IFR+MS 5257. 80 91 .73 115 .81 3770 .51 3698 .98 -2211.57 1663. 62 5997691. 89 567176. 08 MWD+IFR+MS 5352. 28 91 .94 113 .49 3767 .49 3695 .96 -2250.96 1749 .44 5997653. 26 567262. 24 MWD+IFR+MS 5390. 00 91 .66 112 .94 3766 .30 3694 .77 -2265.82 1784 .09 5997638. 71 567297. 01 MWD+IFR+MS 5446. 22 91 .23 112 .11 3764 .89 3693 .36 -2287.35 1836 .01 5997617. 64 567349. 11 MWD+IFR+MS 5539. 44 91 .93 110 .02 3762 .32 3690 .79 -2320.84 1922 .96 5997584. 91 567436. 34 MWD+IFR+MS 5635. 59 90 .31 106 .52 3760 .44 3688 .91 -2350.97 2014 .23 5997555. 59 567527. 86 MWD+IFR+MS 5730. 28 87 .41 103 .79 3762 .32 3690 .79 -2375.71 2105 .59 5997531. 65 567619. 43 MWD+IFR+MS 5825. 17 84 .34 101 .82 3769 .15 3697 .62 -2396.69 2197 .86 5997511. 48 567711. 87 MWD+IFR+MS 5919. 89 83 .03 101 .47 3779 .56 3708 .03 -2415.69 2290 .07 5997493. 29 567804. 23 MWD+IFR+MS 6012. 48 85 .75 100 .74 3788 .61 3717 .08 -2433.44 2380 .48 5997476. 34 567894. 79 MWD+IFR+MS 6059. 00 85 .75 100 .74 3792 .06 3720 .53 -2442.08 2426 .06 5997468. 09 567940. 44 PROJECTED to TD U Sperry Drilling Services Survey Report • - -_ __ ~~ Company: BP Amoco ~'~ Field: Milne Point --- Date: 12/30/2008 Time: 13:01:20 Page: 1 Co-ordinate(NL') Reference: Well: MPS-41, True North ~~ Site: M Pt S Pad Vertical (TVD) Refer ence: MPS-41 71.5 Well: MPS-41 Section (VS) Reference: Well (O.OON,O.OOE,1 36.20Azi) Wellpath: MPS-41APB2 Survey Calculation Method: Minimum Curvature _ ._. Db: Oracle __ Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Le vel Geomagnetic Model: bggm2007 Well: MPS-41 Slot Name: 5002923401 Well Position: +N/-S -81.86 ft Northing: 5999888.58 ft Latitude: 70 24 36.523 N +E/-W -852.55 ft Easting : 565493.29 ft Longitude: 149 28 0.159 W Position Uncertainty: 0.00 ft Wellpath: MPS-41AP62 Drilled From: MPS-41APB1 500292340171 Tie-on Depth: 5515.00 ft Current Datum: MPS-41 Height 71.53 ft Above System Datum: Mean Sea Level Magnetic Data: 1 1/15/2008 Declination: 22.62 deg Field Strength: 57662 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33. 74 0.00 0.00 136.20 Survey Program for Definitive Wellpath Date: 12/28/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 33.74 442.00 MPS-41 CB-GYRO-MS ( 33.74-442.0 CB-GYRO-MS Camera based gyro multishot 442.00 4140.00 MPS-41 MWD+SAG+CA+IIFR+MS (44 MWD+IFR+MS MWD +IFR + Multi Station 4145.00 5446.22 MPS-41APB1 MWD+SAG+CA+IIFR+M S MWD+IFR+MS MWD +IFR + Multi Station 5515.00 6147.00 MPS-41AP62 MWD+SAG+CA+IIFR+M S MWD+IFR+MS MWD +IFR + Multi Station Survey __ _ MD Incl Azim TVD Sys TVD N/S "' E/bV MapN MapE Tool ft deg deg ft ft ft ft ft ft - - -__ _ _ 33.74 0.00 __ 0.00 33.74 -37.79 0.00 0.00 5999888.58 565493.29 TIE LINE 73.00 0.38 334.02 73.00 1.47 0.12 -0.06 5999888.70 565493.23 CB-GYRO-MS 162.00 0.21 222.16 162.00 90.47 0.26 -0.30 5999888.84 565492.99 CB-GYRO-MS 251.00 0.46 272.88 251.00 179.47 0.16 -0.76 5999888.73 565492.53 CB-GYRO-MS 351.00 0.42 232.13 350.99 279.46 -0.05 -1.45 5999888.52 565491.84 CB-GYRO-MS 442.00 0.74 181.86 441.99 370.46 -0.84 -1.73 5999887.73 565491.56 CB-GYRO-MS 528.63 1.47 146.58 528.60 457.07 -2.33 -1.14 5999886.25 565492.17 MWD+IFR+MS 618.13 3.06 135.98 618.03 546.50 -5.00 1.15 5999883.59 565494.49 MWD+IFR+MS 706.57 3.91 137.59 706.31 634.78 -8.93 4.83 5999879.70 565498.19 MWD+IFR+MS 803.02 4.62 140.99 802.49 730.96 -14.37 9.49 5999874.29 565502.90 MWD+IFR+MS 896.82 5.85 144.37 895.90 824.37 -21.19 14.65 5999867.52 565508.13 MWD+IFR+MS 989.19 8.31 143.02 987.56 916.03 -30.35 21.41 5999858.42 565514.96 MWD+IFR+MS 1083.61 10.18 145.31 1080.75 1009.22 -42.66 30.26 5999846.19 565523.92 MWD+IFR+MS 1180.79 12.08 149.01 1176.10 1104.57 -58.45 40.39 5999830.50 565534.19 MWD+IFR+MS 1275.09 15.30 145.49 1267.71 1196.18 -77.16 52.52 5999811.89 565546.48 MWD+IFR+MS 1366.86 17.89 144.26 1355.65 1284.12 -98.58 67.62 5999790.60 565561.76 MWD+IFR+MS 1460.55 19.33 146.04 1444.44 1372.91 -123.13 84.69 5999766.21 565579.04 MWD+IFR+MS 1553.82 19.10 144.74 1532.51 1460.98 -148.39 102.12 5999741.10 565596.70 MWD+IFR+MS 1648.35 20.12 146.37 1621.56 1550.03 -174.56 120.05 5999715.10 565614.86 MWD+IFR+MS 1742.45 22.69 144.96 1709.16 1637.63 -202.90 139.44 5999686.93 565634.49 MWD+IFR+MS 1837.55 25.49 142.98 1795.97 1724.44 -234.26 162.30 5999655.77 565657.62 MWD+IFR+MS 1931.98 25.42 142.91 1881.23 1809.70 -266.65 186.75 5999623.60 565682.36 MWD+IFR+MS 2024.99 26.28 147.47 1964.94 1893.41 -299.94 209.87 5999590.52 565705.76 MWD+IFR+MS 2119.30 26.53 149.59 2049.42 1977.89 -335.71 231.75 5999554.95 565727.96 MWD+IFR+MS 2213.60 26.59 153.10 2133.77 2062.24 -372.69 251.96 5999518.15 565748.49 MWD+IFR+MS 2307.25 29.86 155.79 2216.28 2144.75 -412.66 271.01 5999478.35 565767.89 MWD+IFR+MS 2402.97 33.72 158.11 2297.62 2226.09 -459.06 290.70 5999432.13 565787.98 MWD+IFR+MS • Sperry Drilling Services Survey Report Company: BP Al1l000 Field: Milne Point Site: M Pt S Pad ~i'cll: MPS-41 ~~I Wcllpath: MPS-41APB2 Survey Mll Lncl ft deg im deg ___ VD ft _ _ _ ,ys TVD ft 'Date: 12/30/2008 Time: 13:01:20 Page: Z Co-ordinate(NE) Kefercnce: Well: MPS-41, True North Vertical (TVll) Kefercnce: MPS-41 71.5 Section (VS) Kefercnce: Well (O.OON,O.OOE,136.20Azi) Survey Calcnlatioi~ iVlcthod: Minimum Curvature llb: Oracle N/S E/W blapN b4apE Tool ft ft ft ft 2499.15 34 .51 159 .04 2377 .25 2305 .72 -509.28 310. 40 5999382. 09 565808. 11 MWD+IFR+MS 2593.48 38 .00 160 .17 2453 .31 2381 .78 -561.57 329. 81 5999329. 98 565827. 98 MWD+IFR+MS 2687.91 39 .94 163 .58 2526 .73 2455. 20 -618.00 348. 25 5999273. 72 565846. 91 MWD+IFR+MS 2782.87 43 .38 166 .17 2597 .67 2526. 14 -678.92 364. 67 5999212. 94 565863. 86 MWD+IFR+MS 2876.92 44 .01 169 .75 2665 .68 2594. 15 -742.45 378. 20 5999149. 55 565877. 95 MWD+IFR+MS 2972.26 44 .46 168 .93 2733 .99 2662. 46 -807.81 390. 51 5999084. 30 565890. 83 MWD+IFR+MS 3067.08 45 .04 167 .41 2801 .33 2729 .80 -873.14 404. 20 5999019. 10 565905. 09 MWD+IFR+MS 3159.00 46 .30 164 .77 2865 .57 2794 .04 -936.95 420. 01 5998955. 44 565921. 46 MWD+IFR+MS 3251.92 48 .12 161 .29 2928 .70 2857 .17 -1002.14 439. 94 5998890. 43 565941. 96 MWD+IFR+MS 3344.07 48 .12 159 .70 2990 .22 2918 .69 -1066.81 462. 85 5998825. 98 565965. 43 MWD+IFR+MS 3433.40 48 .76 155 .08 3049 .50 2977 .97 -1128.47 488. 54 5998764. 54 565991. 66 MWD+IFR+MS 3531.19 49 .57 150 .38 3113 .46 3041 .93 -1194.19 522. 44 5998699. 13 566026. 13 MWD+IFR+MS 3624.43 49 .43 147 .26 3174 .03 3102 .50 -1254.84 559. 14 5998638. 81 566063. 36 MWD+IFR+MS 3713.98 49 .24 143 .87 3232 .39 3160. 86 -1310.85 597. 54 5998583. 14 566102. 24 MWD+IFR+MS 3812.99 51 .90 141 .18 3295 .27 3223. 74 -1371.51 644. 08 5998522. 90 566149. 31 MWD+IFR+MS 3910.89 55 .17 138 .75 3353 .46 3281. 93 -1431.75 694. 74 5998463. 11 566200. 49 MWD+IFR+MS 4003.51 57 .73 135. 56 3404 .65 3333. 12 -1488.31 747. 24 5998407. 02 566253. 48 MWD+IFR+MS 4098.42 58 .16 134. 31 3455 .02 3383. 49 -1545.12 804. 18 5998350. 72 566310. 91 MWD+IFR+MS 4140.00 57 .90 134. 09 3477 .04 3405. 51 -1569.71 829. 47 5998326. 35 566336. 41 MWD+IFR+MS 4145.00 57 .87 134. 07 3479 .70 3408. 17 -1572.66 832. 51 5998323. 43 566339. 48 MWD+IFR+MS 4228.48 59 .65 133. 79 3522 .99 3451. 46 -1622.17 883. 91 5998274. 38 566391. 31 MWD+IFR+MS 4323.01 62 .84 135. 61 3568 .46 3496. 93 -1680.47 942. 80 5998216. 60 566450. 69 MWD+IFR+MS 4412.75 65 .10 132. 98 3607 .85 3536. 32 -1736.76 1000. 51 5998160. 83 566508. 90 MWD+IFR+MS 4511.55 67 .71 132. 28 3647 .39 3575. 86 -1798.07 1067. 13 5998100. 11 566576. 04 MWD+IFR+MS 4593.70 69 .90 132. 68 3677 .09 3605. 56 -1849.79 1123. 61 5998048. 89 566632. 97 MWD+IFR+MS 4688.39 72 .46 130. 55 3707 .64 3636. 11 -1909.30 1190. 61 5997989. 98 566700. 49 MWD+IFR+MS 4782.21 75 .54 126. 93 3733 .50 3661. 97 -1965.70 1260. 95 5997934. 20 566771. 31 MWD+IFR+MS 4880.91 80 .32 125. 25 3754 .14 3682. 61 -2022.52 1338. 93 5997878. 07 566849. 77 MWD+IFR+MS 4973.05 86 .68 122. 15 3764 .56 3693. 03 -2073.27 1415. 05 5997827. 99 566926. 33 MWD+IFR+MS 5067.00 88 .07 120. 34 3768 .87 3697. 34 -2121.95 1495. 29 5997780. 02 567006. 98 MWD+IFR+MS 5161.86 89 .10 118. 00 3771 .21 3699. 68 -2168.17 1578. 08 5997734. 54 567090. 17 MWD+IFR+MS 5257.80 91 .73 115 .81 3770 .51 3698. 98 -2211.57 1663. 62 5997691. 89 567176. 08 MWD+IFR+MS 5352.28 91 .94 113 .49 3767 .49 3695. 96 -2250.96 1749. 44 5997653. 26 567262. 24 MWD+IFR+MS 5390.00 91 .66 112 .94 3766 .30 3694. 77 -2265.82 1784. 09 5997638. 71 567297. 01 MWD+IFR+MS 5446.22 91 .23 112 .11 3764 .89 3693. 36 -2287.35 1836. 01 5997617. 64 567349. 11 MWD+IFR+MS 5515.00 91 .75 110 .57 3763 .10 3691 .57 -2312.37 1900. 05 5997593. 18 567413. 36 MWD+IFR+MS 5599.76 89 .21 111 .10 3762 .39 3690 .86 -2342.51 1979. 25 5997563. 74 567492. 82 MWD+IFR+MS 5643.20 89 .58 111 .60 3762 .85 3691 .32 -2358.32 2019. 71 5997548. 28 567533. 41 MWD+IFR+MS 5742.50 86 .93 113 .10 3765 .87 3694 .34 -2396.06 2111. 50 5997511. 35 567625. 52 MWD+IFR+MS 5832.50 86 .86 116 .97 3770 .75 3699 .22 -2434.08 2192. 91 5997474. 05 567707. 25 MWD+IFR+MS 5928.50 89 .40 118 .27 3773 .88 3702 .35 -2478.56 2277. 91 5997430. 32 567792. 63 MWD+IFR+MS 6023.08 88 .78 117 .02 3775 .38 3703 .85 -2522.44 2361. 68 5997387. 18 567876. 77 MWD+IFR+MS 6104.18 90 .76 116 .78 3775 .71 3704 .18 -2559.13 2434. 00 5997351. 13 567949. 41 MWD+IFR+MS 6147.00 90 .76 116 .78 3775 .14 3703 .61 -2578.42 2472. 23 5997332. 18 567987. 80 MWD+IFR+MS gp Page 1 of 1 Leak-Off Test Summary Legal Name: MPS-41 Common Name: MPS-41 - - - - -T - _ __ _ Test Date ! Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW - --- 11/14/2008 __ LOT 4,167.0 (ft) 3,480.0 (ft) 9.40 (ppg) 760 (psi) 2,459 (psi) 13.60 (ppg) 12/7/2008 FIT 4,203.0 (ft) 3,477.0 (ft) 9.20 (ppg) 420 (psi) 2,082 (psi) 11.53 (ppg) ~~ Printed: 12/30/2008 12:34:04 PM • • ~ ~ --~x ~- ~-~ .~ ^- 4 ~~ '.~ ~.~ r,~, -~ ' ~ h u ~ El~~ ~~~ r- ~-~ 1y} F ~ ~ t ~~ k a 1< / ~ ~ 1 ft /~ SARAH PALIN, GOVERNOR ALASsA ou Ann c~As COnSERQATIOl1T CO1rII~IISSIOn Dan Kara Senior Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Milne Point Field, UGNU Oil Pool, MPS-41A BP Exploration Alaska Inc. Permit No: 208-161 Surface Location: 3224' FSL, 518' FEL, SEC. 12, T12N, R10E, UM Bottomhole Location: 4501' FNL, 1357' FEL, SEC. 07, T12N, R11E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to complete and produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and. approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager), S erely ie~ Seamount, Jr. Chair DATED this "da of October, 2008 Y cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMON ~~ . PERMIT TO DRILL ~~~ 20 AAC 25.005 1 a. Type of work ^ Drill ~ Redrill~ ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service Mukiple Zone ^ Stratigraphic Test ®Development Oil ~ Single Zone 1 c. Specify if well is proposed for: 0 Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: MPS-41A • 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD ~ 7543 TVD 3855 ~ 12. Field /Pool(s): Milne Point Unit / Ugnu , 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 380110 FSL, 518 FEL, SEC. 12, T12N, R10E, UM 3224 Top of Productive Horizon: R11E, UM 4277' FNL 3358' FEL SEC. 07 T12N 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2008 , , , , Total Depth: 4501' FNL, 1357' FEL, SEC. 07, T12N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 687' 4b. Location of Well (State Base Plane Coordinates): Surface: x-585493 ' y-5999889 ' Zone-ASP4 10. KB Elevation Planned (Hei ht above GL): 7 , ' feet 15. Distance to Nearest Well within Pool: 280' 16. Deviated Wells: Kickoff Depth: 4137 feet Maximum Hole An le: 88 d Tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1687 Surface: 1305 ` 1 r ifi n T - mn r s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 1 7" L- 7 n n in r 1 g, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 5073' Total Depth TVD (ft): 4 73' Plugs (measured): None Effective Depth MD (tt): 5073' Effective Depth TVD (ft): 4073' Junk (measured): None Casing Length Size Cement Volume MD TV Conductor /Structural ' Surface 41 D 41 ' Intermediate Pr ' Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Nam (a ` Si nature ~~- Contact Paul Hanson, 564-4195 Title Senior Drillin En finer Prepared By Name/Number: Phone 564-5667 Date /O u7 Sondra Stewman, 564-4750 Commi lion UsQ Onl Permit To Drill • o?D~/~J API Number: 50- ®~?9®?.3~OlOlOD Permit App val See cover letter for U ` r r it 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 shales: Samples Req'd: ^ Yes 17~No Mud Log Req'd: ^ ~'es C3~No HZS Measures: Q~Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~jj~~ P~~ ~~~~~ ~~ 3~ Date APPROVED BY T COMM SSIONER Form 10-401 Revised 12/2005 Submiii,ln Dt,~ lica~e by To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Paul Hanson, ODE Date: October 3, 2008 Re: Permits to Drill MPS-41 and MPS-41 A, and Sundry Permit to abandon MPS-41. MPS-41/41A will be the first of three wells drilled at Milne Point in Q4 of 2008 to test production methods for UGNU Heavy Oil. This well is part of a larger program to advance heavy oil production to commercial scale. The MPS-41/MPS-41A appraisal well/ Horizontal Producer is scheduled to be drilled by Doyon Rig #14 with an estimated spud date of 11 /01 /08. Operations are expected to require 33 days to complete. The basic drilling plan is to spud the well with a 12-1/4" bit and drill to TD at 4138' ± MD where 9-5/8" casing will be run and cemented to surface. An 8-1/2" hole (MPS-41) will then be drilled to TD at 5073' ± MD. After gathering extensive a-line logs, MDT samples and sidewall cores, 7" casing will be run and cemented to accommodate a planned cased hole DST program. The objective is to collect PVT-quality oil samples from the UGNU sands. After. the DST program, the open perforations of the 7" casing plugged and abandoned rior to cuttin and ullin the 7" from 100' below the surface casin shoe to drill the UGNU Horizontal Producer-leg of this well (MPS-41 A). The horizontal section of this well (8-1/2" hole) will be drilled off a cement Kick-off plug to a final depth of 7542' ± MD, with approximately 2000' of horizontal exposure in the upper UGNU sands targeted. After a MAD PASS logging and conditioning run, a 7" ~h-~ ~ slotted x blank liner will be run with approximately 150' of lap with 9-5/8" casing. A retrievable bridge plug will be set above the liner top and pressure tested prior to ~~~~~ \ circulating the well to 9.7 ppg NaCI brine (-2° TCT). The well will be temporarily completed with a kill string and dry-hole tree and freeze protected to 200' TVD. Attached for your review is a Well Plan Summary, directional plans, Wellbore Schematics, PTD forms 10-401 (2) for MPS-41 and MPS 41 A, and Sundry Perrnit Application 10-403 for P&A of MPS-41. If you should have any questions concerning these applications or supporting documentation, please give me a call at (907) 564-4195. Thank you for your assistance. egards, Paul Hanson ADW-ACT Drilling Engineer MPS-41 Page 1 Well Name: MPS-41 and MPS-41 A Ugnu Appraisal/Horizontal Test Well Drilling and Evaluation Plan Summary T e of Well: A raisal Well Surface Location: 2056' FNL and 518' FEL (AS Built) Section 12, T12N, R10E UM ' ' N = 5,999,889 E = 565,493 9-5/8" Surface Casing Point 3,604' FNL and 4,476' FEL Section 7, T12N, R11 E UM E = 566,337' N = 5,998,348' Z = 3,421' TVDSS T2 - 10' below top M80T in MPS- 3,844' FNL and 4.190' FEL 41 Section 7, T12N, R11 E UM ' E = 566,626' N = 5,998,110' TVDSS Z = 3,689 T3 - TD MPS-41 4,061' FNL and 3,907` FEL Section 7, T12N, R11 E UM E = 566,912' N = 5,997,896' Z = 4,000' TVDSS T1 -Top of pump tangent in 4,277 FNL and 3,358' FEL MPS-41 A Section 7, T12N, R11 E UM E = 567,464' N = 5,997,685' Z = 3,707' TVDSS T2 -Invert point along horizontal 4,408 FNL and 3,043' FEL in MPS-41 A Section 7, T12N, R11 E UM ' E = 567,780' N = 5,997,557' TVDSS Z = 3,717 T3 - TD of horizontal section in 4,501' FNL and 1,357' FEL MPS-41 A Section 7, T12N, R11 E UM ' E = 569,468' N = 5,997,479' TVDSS Z = 3,782 Distance to Property line 687' (shortest distance from well path to MPU/PBU unit bounda Distance to nearest well 280' from MPS-11 UGNU M80 penetration ` AFE Number: 337483 Estimated Start Date: 01 Nov 2008 Ri Do on 14 Ri da s to com lete: 33 5,073 4,073' MD: (MPS-41) .I.VD; (MPS-41) Max Inc: 88° KOP: 400' KBE: 72.5' / 7,543 / 3,855 MPS-41 A MPS-41 A Well Desi n: A raisal/Horizontal Producer 7" Slotted Liner Ob'ective: U nu M Sands -Data Ac uisition and Horizontal Test - ~~ MPS-41 Page 2 i ~- Mud Program: 12-1 /4" Surface Hole (0' - 4.138' MD1: ~~ k Soud Densi P~ XP H AP#°Fil#rate Chlorides ~ m ' # 8.6-9.8 10-25 30-50 8.5-9.5 NC-8 <1000 8-1/2" Hole - 4,138' - 5,073' MD MPS-41: LSND Densi PV `'YP . H API` Fi#trate < MBT 8.8-9.4 8-15 26-32 9.0-9.5 6-8 <25 8-1 /2" Hele - (4.138' - 7.5431 MPS-41 A: RHELIANT Mineral Oil-Based Dettsi PV ~!(P H HTHPFiltrate `3'o Oil ~9.0-9.3 15-20 15 ~- 20 N/A < 3 75 ~ h`~ Com letion Fluid - MPS-41 A: VERSAPRO SF Mineral Oil-Based ~~ Densi - FY . 'YP HTHPFiltrate °/a'Oi1 ~9.0-9.3 20-35 10-20 N/A N/A 50 . Upon completion of running of the 7" slotted x blank liner, an RBP will be set above the liner top, and the wellbore above the liner will circulated to seawater. Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Casing/Tubing Program Hole Size Csg/Liner WUFt Grade Conn Burst Collapse Length Top Bottom Diam MD/ MD/ TVDrkb TVDrkb 48-in 20-in 92 H-40 Weld 1530 520 120-ft 0 120' / Insulated 120' 12.25-in 9 5/8-in 47 L-80 BTC 6870 4750 4138' 0 4138'/ 3493' 8.5-in 7-in 26** L-80 BTC-M 7240 6600 5073' 0 5073' MPS-41 ** This is the 7" long string for the temporary completion of MPS-41 for the purpose of conducting DST 8.5-in 7-in 26* L-80 BTC-M 7240 6600 3555' 3988 7543'/ MPS-41A 3855' * 26# will be used above the slotted liner. The slotted liner is 29# with 1/8""' slots, 2-inches long at 32 spf in a "staggered" pattern. 29# was used to compensate for the weakening of the pipe due to slots. Tubing 4.5-in 12.6 L-80 IBT-M 8430 7500 2070' 0 2070'/ 2000' MPS-41 Page 3 Cement Program: Surface ~ ~7 ~~'Cf-- From To Lead Cement 0 112 112 1958 1958 3638 Casin Size 9-5/8", 47#, L-80, BTC Surface Casin to 4,138' Lead cement = 3,638' MD to surface with 40% excess below the PF and Basis 150% excess above through the PF. Tail cement = 500' MD above shoe lus 40% excess Total Cement Wash 10 bbl water Volume• 463 bbl Spacer 100-bbl 10.0-Ib/ al Mud ush II S aver \ / Lead 415 -Bbl, 606 sx of 10.7 ppg DeepCrete - 3.85 ft3/sx ~~ Tail 69-bbl, 173-sx 12.5 Ib/ al Dee Crete - 2.24ft /sx CCU Tem ~ ~60° F Tail Cement 3638 4138 4056 4138 Surface Casing Cement Volumes -Calculated MPS-41 and 41A Hole Casing Total Yield Total Length Size Size Volume Excess BBLs CuFt/sx Sacks 112 18.376 9.625 26.7 0.00% 26.7 3.85 38.9 1846 12.25 9.625 103.0 150.00% 257.4 3.85 375.4 1680 12.25 9.625 93.7 40.00% 131.2 3.85 191.3 120.4 415.3 605.6 500 13.5 9.625 43.5 40.00% 60.9 2.24 152.7 82 9.95 0 7.9 0 7.9 2.24 19.8 68.8 172.5 DST Interval -MPS-41 7", 26#, L-80, BTC-M From ES Cementer C~--4288' to 5073' (MPS-41). Casing Size Assume 280' shoe track to control rathole below lower pert zone. Actual de th to be determined b to data. Basis Lead cement = 5073' MD to ES Cementer with 30% excess in o en-hole . Total Cement Wash 5 bbl water Volume: 463 bbl Spacer 50-bbl 10.0-Ib/ al Mud ush II S acer Lead 44 -Bbl, 210 sx of 15.8 Class G -1.16 ft /sx Temp ~71 ° F ___ MPS-41 7", 28# Casing From TD at 5073 To ES Cementer at 4288' (MPS-41) From To Length Hole Casing Volume Excess Total Yield Total Size Size BBLs CuFt/sx Sacks 4288 5073 785 8.5 7 17.7 30.00% 23.0 1.16 111.6 4793 5073 280 8.681 0 20.5 0 20.5 1.16 99.2 43.5 210.8 MPS-41 Page 4 Evaluation Program: 12-1/4" Section Open Hole: • Photo Gyro • MWD/GR/Res • IFR/CASANDRA, • Sperry InSite • DEN/NEU w/ACAL i 8-1/2" Section While Drilling MPS-41 MPS-41 Evaluation • DIR/GR/RES MDT-UGNU M70 & • IFR/CASANDRA, M80 • Sperry InSite • NGT/PEX/ECS/AIT • DEN/NEU w/ACAL Sonic Scanner/FMI • MRIUGABI • Sidewall Cores • Mudloggers • Cutting Samples • ubes W hile Drilling MPS-41 A _ , -DIR/GR/RES • DEN/NEU w/ACAL • IFR/CASANDRA, • Sperry InSite Cased Hole: • R/USIT • DST-UGNU M80L and M80U in MPS-41 Formation .Markers (MPS-41): Formation Tops MD ~F.l.~ TVD ~~ TVDss ~~ Pore Pre sure EMW ~ppg) BPRF 1958 1903 -1830 809 8.50 U nu 4a (from MPS-11) 2964 2733 -2660 1176 8.50 220 Fault (P50) 3914 3379 -3306 1461 8.50 To Coal Zone 3922 3384 -3311 1463 8.50 TUZC 4095 3473 -3400 1503 8.50 9-5/8" Casin Point 4137 3493 -3421 1512 8.50 M87S 4430 3652 -3579 1582 8.50 M87F (-U u Ma) 4534 3719 -3646 1612 8.50 M80T (-MB 1) 4585 3752 -3679 1626 8.50 M80 1Rflood 4674 3811 -3738 1312 5.5 - 8.0 MBOS 4793 3889 -3816 1687 8.50 M70S/SBF2 -To NA 4851 3927 -3854 1503 6.0 - 9.0 To NB (from MPS_l l) 4875 4008 -3935 1535 6.0 - 9.0 TD 5073 4073 -4000 1560 6.0 - 9.0 MPS-41 Page 5 • ~~ Recommended Bit Program: BHA Hole Size 'Depth (MD) f=ootage Bit Type TFA : GPM 1 12-1 /4" 0 - 4,138' 4,138' Baker Hughes MXL - 1 .5 - .7 550-650 2 8-1/2" 4,138' - 5,073' 935' FM3643Z Gong gauge Pic) .7 - 1.0 550-660 3 8-1/2" 4138' - 7,543' 3,405' FM3643Z Gong gauge Poc) .7 - 1.0 550-650 Well Control: Intermediate/Production hole: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • BOP Test Frequency: • Integrity tests: • Kick tolerance: • Planned completion fluid: 1687 psi at 3816' TVDss (M80S) 1305 psi at (Based on a full column of gas at 0.1 psi/ft) 3,500 psi Every 2 weeks FIT or LOT to 11.5 Ib/gal 20' below the 9-5/8" shoe. Infinite with 9.31b/gal mud at below the 9-5/8" shoe. 8.6 ppg brine above RBP. Drilling Hazards & Contingencies: Running Gravel/heavy clay problems have been encountered in some MPU wells. High viscosity mud will be utilized to augment hole cleaning. Hydrates could be encountered. Expected potential depth for hydrates would be from base of permafrost at 2070' MD. Keep the mud as cool as possible, targeting a flow line temperature of 60° F. Lost Circulation • Lost Circulation is not anticipated as a major problem. However, good drilling practices need to be maintained to minimize the potential for pressure induced lost circulation. Expected Pressures • Formation pressure in the Ugnu is expected to be 8.35 ppg. • Formation pressure in the Schrader is expected to be ~7.0 ppg. Pad Data Sheet • Refer to the MPS-Pad Pad Data Sheets for off-set well data. Hydrocarbons • Hydrocarbons are anticipated in the Ugnu & Schrader Bluff intervals. Faults • The wellbore will encounter one interpreted fault, the KWS_220. This is a down-to-the- west , N-S striking fault with a displacement of approximately 120'. There is uncertainty MPS-41 Page 6 in the interpreted location of this fault plane; the P50 is expected at -3306. TVDss, however, the fault could be encountered as early in the well as -3223 TVDss (P10, 3769' MD) or as late as -3241 TVDss (P90, 3799' MD). Though this fault is interpreted to be a single fault plane, there is a possibility that it could be a zone of disruption affecting tens of MD feet of the wellbore, all within the defined zone of uncertainty. (Note that measured depths given are interpolated from MPS-41 WP(6). Hydrogen Sulfide • Hydrogen sulfide is not anticipated. The closest wells had <2 ppm. Anti-collision Issues • All off-set wells Pass Major Risk for this wellplan. Distance to Nearest Property • 687' (shortest distance from well path to MPU/PBU unit boundary). Distance to Nearest Well Within Pool • 280' from MPS-11 UGNU M80 penetration. DRILL & COMPLETION PROCEDURE Pre-Rig Operations 20" conductor casing has been installed to 112' MD. Drilling: MPS-41 & 41 A Basic Plan 1. MIRU Doyon 14 and install diverter on conductor pipe and function test. 2. PU 5" DP. Drill 12-1/4' surface hole to 4138' MD (3483 TVDrkb) with water-base spud mud. Condition to run casing. 3. Run 9-5/8" surface casing and cement to surface. 4. ND Diverter, NU and test BOPE (Test BOPs to 3500 psi). 5. Drill out 9-5/8" casing plus 20'. Perform a LOT. 6. Drill 8-1/2" "pilot " (MPS-41) with water based mud through the Ugnu and Schrader N -sands to 5073' MD (4073' TVDrkb). Condition hole for MDT, a-Line logs, and sidewall cores. 7. Conduct open hole evaluation (MDT - M70 (Schrader NA) and M80L) in water based mud per MDT Sampling Plan and well-site geologist. POOH. 8. Evaluate MPS-41 per E-line Logging Program including sidewall cores. MPS-41 Page 7 • 9. RIH w/clean-out assembly and condition for casing. 10. Run and cement 7" casing. Bring cement to approximately 150' above the Ugnu M87S at 4430' MD, 3652 TVDrkb). TOC to be at 4288' MD, 3569' TVDrkb. Note that this is 150' below the 9-5/8" surface casing shoe and approximately 300' above the uppermost perforation depth for DST testing. Pressure up to open the ES Cementer. Cement will be circulated out above desired TOC through a Halliburton ES Cementer w/ seawater to reduce cut-&-pull risk. After returns clean up, displace seawater followed by 30 bbl of 3 ppb Biozan (cement contamination) pill. Kick out closing plug. Close the ES-Cementer with 1600 psi and check for flow. 11. Test BOPE. 12. MU 6-1/8" clean-out assembly, RIH to ES Cementer depth. 13. Test 7" casing to 2,000 psi and hold for 10 minutes (record). 14. Drill out closing plug and TIH and tag baffle adapter. Use viscous sweeps as needed and clean out wellbore. 15. Test 7" 26# L-80 BTC-M casing to 3000 psi f/ 30 mins -Record on chart . 16. Run USIT log from TD to surface to identify channeling, TOC and insure cut-&- pull. 17. Rig up and conduct DSTs of the M80L and M80U Ugnu as detailed in the DST Sampling Plan. RD DST equipment. Note that two individual zones will be perforated and tested. The upper zone will be isolated from the lower zone by a cast iron bridge plug prior to the perforating and testing of the upper zone. 18. RIH w/DP and P&A the MPS-41 leg (open perfs) with cement. • RIH and drill out the cast iron bridge plug. POOH • Pick up a cement stinger and RIH. Lay in a balanced plug of 15.8 Class G cement of sufficient volume to fill the volume from PBTD/top of fill to 100' above the upper perfs. Circulate above TOC. POOH 19. PU Cut and pull assembly and tag and test TOC. Cut 7" casing 50' above cement (approximately 4230' MD -approximately 50' above the ES Cementer and 100' below the 9-5/8" shoe). Pump balanced cement kick-off plug and bring cement ~ 100' into the 9-5/8" casing. ~~~ ~ ~~~~ 20. RIH w/drilling assembly and tag/test cement. Displace to 9.2 ppg Rheliant MOBM per MI Swaco displacement procedures 21. Drill 8-1/2" hole from surface casing C«34138'MD to 7543' MD (3855' TVDrkb) per plan MPS-41A Wp 13. 22. Condition hole for LWD logging. MPS-41 Page 8 • • 23. MAD PASS horizontal wellbore (DIR/GR/RES/DEN/NEU/ACAL) to define slot and blank pipe distribution in lateral. ACAL for appraising wellbore stability/condition. 24. Condition the wellbore and displace the wellbore to VERSAPRO SF prior to running 7" (Slot x Blank) liner. POOH. 25. Run 7" production liner. Note that this string will be a combination of 7" 29# L- 80 slotted pipe and blank for approximately 2000' based on rock quality (logs) and solid 26# L-80 pipe to 150' above the 9-5/8" shoe. 26. RIH with a 9-5/8" RBP to just above the liner top and set and test to 1500 psi. 27. Displace the well above the RBP to 9.7 ppg brine to insure sufficient freeze protection from ~ 200' below surface to below the base of permafrost (diesel above). 28. Run 4-1/2" 12.6# L-80 Kill string to 2070' MD. 29. Land tubing hanger and test. 30. ND BOPE/NU and test tree. 31. Freeze protect w/diesel from 200' TVD to surface. . 32. RDMO. MPS-41 Page 9 23 ~"'.rr.K.24 /I 19 Z PLANT ~ 15'00'00" GRID MPS-43 -~ MPS-41 ~- MPS-39 ^ 37 • ~ I LEG,EdQ ^ 34 psi ~- AS-BUILT CONDUCTOR ^ ~ ( ^ EXISTING CONDUCTOR ~ 29I 26 ^ 27 ^ 28 2s 2a j 2Y ^ 211 ^ 20 ^ 19i ~;; ~ SURVEYOR'S CERTIFICATE ~ 15t I I HEREBY CERTIFY THAT I AM ^ 14 PROPERLY REGISTERED AND LJCENSED ^ 13i TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT j ii THIS AS-BUILT REPRESENTS A SURVEY ^ 1o I MADE BY ME OR UNDER MY DIRECT ^ at SUPERVISION AND THAT ALL ^ 6 ~ CORREC~NAS OD 01THER D2 TOASLS ARE ^ 7i 4 1 ^ sa-o4 ^ I I ~ I L J~ ~ I ~ ~~ ~ ~ L_J u 26 25 30 "' 29 35 36 ~, 32 2 1 6 T 3 AREA 11 12 8 9 1 VICINITY MAP N.T.S. OF ,~~ q~ ~Pooo,o,ooo .oe.o.o,oooee,.oooooo,o.,.o>., .o.,aoooo,o<voooooooooaooo>.e. `~, Leonard J. O'Hanley ~011386 0 ,o~ °o "'N'ESS 1014P~- ~ 1. DATE OF SURVEY: JULY 1, 2008. a~ 2. REFERENCE FIELD BOOK: MP08-03, PAGES 17-19. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 / e _ _ _ _ _ _ I NAD-27. it / - - - 4. GEODETIC COORDINATES ARE NAD-27. ' 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. MPU S-PAD 6. HORIZONTAL CONTROL IS BASED ON BPX MPU S-PAD OPERATOR MONUMENTS S-EAST S-MID AND S-WEST. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. i nre-r~n luinaiN piznraecTFn cFC ~~ T 19 N R 1n F_ t1MIAT MFRInIAN_ AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC ELLAR BO SEC110N N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS MPS 39 Y=5,999,896.46 N= 2,237.09 70'24'36.598" 70.4101661' 37 78' 3,232' FSL - X= 565 522.28 E= 6 384.91 149'27'59.307" 149.4664742' 489' FEL Y=5,999,888.58 N= 2,236.98 70'24'36.523" 70.4101453' 37 79 3,224' FSL MPS-41 X= 565,493.29 E= 6 354.86 149'28'00.159" 149.4667108' ' 518' FEL MPS 43 Y=5,999,880.83 N= 2,236.94 70'24~36.449~ 70.4101247' 37 12' 3,217' FSL - X= 565 464.52 E= 6 325.06 149'28 01.005 149.4669458' 547' FEL onrtnn.+n ~ CHEpCED: ~W P 0 ~ DATE: Fl2808 MPS 01-00 ~~T' °RA"~"`~ MILNE POINT UNIT S-PAD ^ ~~S~O~o Boa na AS-BUILT CONDUCTORS 0 2 o issum FoR INFOIWA710N iFD .rzw °'°'~ "° ""° •""`~ scA~E: 1 ov 1 °~ •„ ,~ ,,,,E 1•= 160, WELL 5-39, S-41 & S-43 ND. DA1E REN510N BY ()9f ~ ~" •~ ~~ ,~~~I~ " BPXA ~ - ~-. ~. _. MPS-41 Test Well for Logging, MDT and Cased-hole DST Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 _106' 48" Welded/Isulated 11" 5K Saud Mud MWD/GR/RES None Test Csg to NeulDen w/ACA 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casing 415 Bbls, 606 sx 9-5/8" 10.7 ppg-3.65 ft3/sx 47 1bs/ft DeepCrete t 50 % Excess L-80, In Permafrost BTC-M 40 % below PF Int. Yield 6870 psi Collaspse 4750 psi Tail Cement 69 bbls, 173 sx 12.5 ppg-2.24 ft3/sx TUZC 4,095' 3,473' DeepCrete Casing Point 4,138' 3,493' 61.9° 12-1/4" USIT € ES Cementer LSND Mud M87S 4,430' 3,652' at 4288' Run 1 MDT M87F (Ugnu Ma) 4,534' 3,719' 49° Run 2 M80T 4,585' 3,752' Prod.. Casing Test Csg to MWD/GR/RES NGT/PEX/ECS / 7° 3000 psi Neu/Den w/ACA AIT M80_1 Rflood 4,674' 3,811 49° 26 Ibs/ft Tail Cement MRIUGABI L-80, 44 bbls, 210 sx Run 3 BTC-M 15.8 ppg-1.16 ft3/sx Sonic Scanner M-80S 4,793' 3,889 PBTD-M80S Int. Yield 7240 psi FMI Collaspse 6600 psi Run 4 M70S/SBF2-Top N 4,851' 3,927 SWCs Top NB (f/ MPS-11) 4,975' 4,008' 49° CH DST MSOL & MBOU TD 5,073' 4,073' 49° 8-1/2" 10/3/2008 MPS-41 Well Plan Schematic.xls p ~~ ~ ~ MPS-41 P & A Schematic Field: Milne Point ENG: P. Hanson UGNU HEAVY OIL TEST WELL on 14 RIG: Do Pad: S-Pad y RKB: 72.5 ft DIR / LWO OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 _106, 48" Welded/Isulated 11" 5K Spud Mud MWD/GR/RES None Test Csg to eu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casino 415 Bbls, 606 sx 9-5/8" 10.7 ppg-3.85 ft3/s 47 1bs/ft DeepCrete 150 % Excess L-80, In Permafrost BTC-M 40% belowPF Int. Yield 6870 psi Collaspse 4750 psi Tail Cement 69 bbls, 173 sx TOC (pre ST) 4038' Casing Point 4,138' 3,493' 61.9° 12-1/4" Casing Cut 4,238' 15.8 Class G ES Cementer at 4288' M87S 4,430' 3,652' M87F (Ugnu Ma) 4,534' 3,719' 15.8 Class G Actual M8U I 4,585' 3, /52' Prod.. Casing Position of retainer plugs defined by logs. MWD/GR/RES M80L Perf int. 7~~ Neu/Den w/ACA M80_1 Rflood 4,674' 3,811 15.8 Class G 26 Ibs/ft MRIUGABI L-80, M80L Perf int. 15.8 Class G BTC-M M-80S 4,793' 3,889 Int. Yield 7240 psi Collaspse 6600 psi M70S/SBF2-Top N 4,851' 3,927 Top NB (f/ MPS-11 ) 4,975' 4,008' 49° TD 5,073' 4,073' 49° 8-1/2" 10/3/2008 MPS-41 P and A Schematic.xls ~~ MPS-41A Horizontal Producer Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost ~. 91.1-Ib/ft H-40 FMC Gen 5 -106' ~ m 48" Welded/Insulated 11" 5K 200' ~ Saud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' -2,000' 4-1/2" Kill String lead Cement Surface. Casing 415 Bbls, 606 sx 9.7 ppg 9-5/8" 10.7 ppg-3.65 ft3/sx NaCI 471bs/ft DeepCrete 150% Excess -2° TCT L-80, In Permafrost BTC-M 40 % below PF RBP -3400' Int. Yield 6870 psi Collaspse 4750 psi Tail Cement Liner Top 3,988' 3,41 B' 69 bbls, 173 sx VERSAPRO -150' Liner lap 12.5 ppg-2.24 ft3/sx TUZC 4,095' 3,473' SF DeepCrete Casing Point 4,138' 3,493' 61.9° 12-1/4" Rheliant MOBM will be used to drill the M87S 4,543' 3,652' 72° UGNU horizontal Prod. Liner MWDlGR/RES 7" MW=9.0to 9.3 ppg Neu/Den w/ACA M87F 4,774' 3,714 77° 29 Ibs/ft ABI L-80, VERSAPRO SF BTC-M MOBM will be M-SOT 44,946' 3,746 82° Slotted with 2" long, complete to drill the 0.125^ width UGNU horizontal staggered slots - 32 M80_1 Rflood 6,224' 3,805 88° spf and blank pipe throughout horizontal. 7" 26# will cover the the curve and the lap TD 7,542' 3,855' 88° 8-1/2" 10/3/2008 MPS-41A Well Plan Schematic.xls COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amoco u-ordin ate (N. F) Rcfercnce: Well Centre: Plan MPS-41 -Zcd, True North epth Fm Depth To Surv ylPlan Tool Plan: Plan MPS-4I Wpl4 (Plan MPS-41 - Zed /Plan MPS-41 A) ~?1~ Vcnical (TVD) Retbrcncc: RKB 72.50 7350 Iculation Method: Minimum Curvature Section (VS) Reference: Slot - (QOUN.O.UOE) 137.70 754258 Plan ned: Plan MPS~I Wp l4 V7 M WDi IFR i M5 Creatd B S Drilling y' P~nY Da tc: 9i23/2008 Error System: ISCW'SA MeasuraJ Depth Reference: RKB 72.50 72511 Scan Me[hod: Trav Cylinder North Calculaliun MethoJ: Minimum Curvatu re ' Error SurlLm: Elliptical i Caving WELL DE fA1LS CASING DETAILS Namc iN~-S i Er-W Northing Fasting Latitude Longitude Slot No. TVD MD Namc Size Plan MPS -0I -Zcd -81.86 -852.55 5999888.58 565493.29 7U°24' 36.523N 149`28'00. U9N' NiA I 3855.00 7542.57 7" 7A00 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +Ei-W DLcg TFacc VSec Target HALLIBURTON I 4137.78 6,.90 133.11 3493.35 -1548.33 830.27 (1.00 8.00 1520.40 2 4608.16 73.70 123.83 3671.14 -1817.28 1171.16 3.10 -37.95 1951.77 3 464 L49 73.70 123.83 3680.48 -1835.06 1197.70 0.00 UA0 1983.70 IiPI Orilli~ S6f V~C9~ 4 9198.38 88A0 114.00 3769.03 -2099.04 1677.60 3.IU -35.07 2530.71 P Y g ~ ~ '~~ - ~ ' ' ~ ~ '~ 5 5498.38 88.00 114.00 377950 -22211.99 1951.50 0.00 0.00 2827.81 MPS-41 T1.. ' I i ' j I ~. - 6 5529.90 SS.UO 114.110 3780.60 -2233.80 19811.27 0.00 OAO 2859.02 -- - _. ~. ~ : 7 5570.87 88.34 112.82 3781.91 -2250.07 3017.89 3.00 -73.76 2899.53 ,500 ', 8 9747A5 8834 112.82 3782113 -2318.72 218LU0 UA0 OA0 3074.41 , --- - - ~ '~ i - -- - 9 5839.37 87.80 110.13 3790.10 -2352.16 2266.02 3.00 -101.49 316431 MPS-41 T2.. : _.. _- _ -_ __. _. _ _. _. 10 6959.61 87.83 88.63 3817.70 -2468.11 29118.03 3.OU -90.32 3822.39 ~__ _-. _-_ _ _ -_ k ~ - I I 7542.58 87.83 88.63 3855.00 -2444.47 _ ,, 3954.01 -_ . 0.(10 0.00 4648.61 MPS-41 T3.. ,I_ -, _ _T. - - - _ ~ 3000 I ~' ~ ' ~ Start Dir 3.1'"10( ' :4(37.7 MD, 349335'7 D ' ~ ~ ~ - - ~ _ , ~ ~ ~- "-'-~ -- . t - - - - End Dir :4608.1KM Stan Dir 3.1?/100' .367L14 TVD :4641.45' MD, 36 80.48'7 D. ..... ~ ~ '. End Dir :6555. 61' D. 3817.7 TVD ~i t _" . -- `_ f.... _' . End Dir :5 19838' ~ S D. 3769.U3'TVD art Dir 371 100' : 5534. 9' M , 37 80.6'TV b i , - -- - c 350( End Dir . 5_7(1.87 ` MD, 78L 91' TVD { + ~ ~ _ o u ~ _- ._ ; .. ~' ;..., ,.° n°. .. ~ Stan Dir 3?/ 100' 9747 .95' MD , 3787.02'7 ~ _ _ .-4. 11 _ - -- I ' - : _ - - - a q _ .. - - - M8 M8 c ~. F M80T °° I - °O ~ - ~ ~ i - _ ~. .. _ ~ - - _ i - ~ oml epth 542.98' MD, 3 99' TVD -,._ 5000- - - MPS-4171.. tt4 PS-4l' .. Iv188 IRflo od i MPS-4 1 i)61t _ ~~ - ~ .. i ~, " ~ ~ ! 7(780. MPS-4 1 T3.. > . : _. - ~ _ _ :. ,. 7" Pl M 41 PS i I i an - F ( ~ '. _.. -- ;- ~ - I ~. j _ PIanM PS -41 ]4 ~ _ _. . _- _. ~ ~ ~~ 1 -._ _.. Plan MPS- _, I - Zr,d. Plan MPS ' ( -41 ) -I ~ - - - ~ ~ - - _ - _ : p , ~. - FORMA"PION TOP DETAILS i _ _ _ ~ I I I L No. TVDPath MDPath Formation I I _ I I I I 1, I 58 M87S 1 3651 50 4541 . . 2 3713.50 4772.12 M87F ! ' - - ' ' ' ~ I 3 3745.50 4943.23 M8UT I _ - 1 4 3804.50 6311.92 M80 I Rflood ~ .. - _-[_ - _- -- - ._ _ - I i _ i i } TARGET DETAILS ~ - _ ~ _ I I ~ ~ I Namc TVD +N;'-S +E/-W Northing Fasting S hape ~ I i ~ ~ ~ _ -_ MPS-41 Fault 150".. rcvl 3378.50 -1257.19 734.79 5998638.00 566"'39.00 Polygon - ' ' MPS-41 Fauh 3 50'% mvl 3652.50 -2184.88 3309.00 5997733.00 56882 L00 Polygon MPS-41 Fault 2 50% rcvl 3745.50 -1716.66 3747.16 5998205.011 569255.00 PUlygon ~ ~ ~ ~ - ~ ~ ~ - ~ ' MPS-41 TI.. 3779.50 -222(1.99 195150 5997685A0 567464.00 Point MPS-41 T2.. 3790.10 -2352.16 2266.02 5997556.60 567779.63 Point MPS-41 DD 8U'% 3855.011 -2444.48 3954.(10 5997479.10 569468.20 Polygon T -r - T r -~ 1~ MPS-41 Gco Poly 3855.00 -2444.47 3954.01 5997479.10 569468?U Polygon 3000 3900 4000 4900 't' t n MPS-4l T3.. 3855.00 -2444.47 3954.01 5997479.10 569468.20 Point Vertical Section at 121.73° [90Uft/iu] COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM k3P Anwcu m ate (N. E) Reference: Well Ccmre: Plan MPS-41 -Zed, True N Depth Fm Depth Tu Suncy~Plan Tuul Plan: Plan MPS-41 Wp141Plnn MPS -M1I -Zed/Plan MPS-41A) ic al (TVD) Reference RKB 72.>U 72.50 Calculation Mcihod: Minimum Curvature ection 1 VS) Reference: Slot - (QUON,UAOE) 4137.70 7542.58 Planned: Plan MPS-41 Wp14 V7 MWD i IFR ~ MS GeateJ By: Spcny Drilling Dnte: 9i23i2008 Ertor System: ISCWSA un;d Depth Rc fcrancc: RKB 7250 72.80 Scan Mcihod: Tmv Cylinder North ('alculution Method: Minimum C urvature Em,r Surfncc Elliptical i Casing WELL DETAILS Wuming Meihud: Rules Based Name W,-S ~ i L- -W Northing Fasting Lmitudc Longitude Slut H /~ ^ ~ p ~ ~ ~~ R ^ i~1L~L~ G ~ V ~ ~~ Plan MPS-41 -Zed 81.%6 -853.55 59998%858 565493.?9 70'243( 5?3N 149°7g'UO.I59W NiA I TARGET DETAILS Sperry Drilling Bervicals ~ ~ I ~ ~ ~ i ~ ~ ', ~ Name "fVD +N/-S +E/-W Northing Eusting Shape UOU r_ ~~ '~~~ ~~ .„ i` ~~") ~ ~- __- _ MPS 41 Fault 150 -", rcvl 337x SU -1257.19 734.79 599x63x.(Ill 566239 UO Polygon ISUU ~ ~ MPS 41 Fault 3 50/ rcvl 3652.50 -2184.xx 3309.00 5997733.00 ~6xx21 U(1 Polygon I ~ MPS 41 Fault _ SO.~~ rcvl 37455(1 1716 66 3747.1 G 599x205 (10 569255A0 Polygon '~ ~ -~ _- ~ ... _.. - - MPS 4I TI 377950 -22'_0 99 1951.50 $9976x5 O(1 567464 011 Point f I I _ i ^ _. '"r' - ~ - MPS 41 "f 2. 3790 10 -2352 16 2266.02 j99755G 60 567779 G3 Point ' I ' ~ '- ~ ~ MPS-41 DD xll% 3855 110 -2444.4x 3954.(10 5997479.111 56946x.2(1 Polygon ~ 200 i ~ -- ~~ ~ MPS-41 Ga, Puly 3x55.11(1 -2444.47 3954.(11 iy97479. 111 56946x30 Polygon -431 __ _L _ __~_ __ _ _ - - ~ ~ I i MPS-41 T3.. _.. _ ~ 3x55.0(1 -2444.47 3954.01 5997479.10 56946x.20 Poim I I I i I I I -x61 ~ ' ' - r I _ ~ - T _ i i _._ ! - - - _ f I ... t { I - - 1 { I i 3 _- U _ _~ I . f ~ .. 1.._ ` ~ -. ~..: , ~ _ ~ . _ ~ ~ ~ , i ° I M P 41 Fault I SU% r ~ -1292 __ L _ _ _ J s o _ _ +. _ . . _~. ,... _ ~ -- r ~ ' ~ I i ~ ... _ _. . - _ - ~~ ~ ~ ' ' ' ' V ~ _ , ~ - ~ ~ r - ' - ~ -~ '~. ~ Start Dir 3. k ?r1 0U :-0137 MD,3493.35 T D ~ _ _ _ I ~ 1 . ~ , FORMATION TOP DETAILS 3 5 ~!I ~ I 1 __ I _ ' f I I . MPS 41 Fault 50 /, rcv l f i i I Nu. TVDPath MDPath Format on I I I ~ ~ i ~ ! En Dir • 4608.16' MD , 3671. 4' TVD _ ~ - ~ - j ' l 3651.50 4541.58 Mx7S I , ~ I ~ tart Du 3.1'', 100' : 4641.4 MD, 36x0.48'TVD ~ C I 2 3713.50 4772.12 Mx7F ~ i i ~ ~ 3 3745.80 4943.23 MxOT ' ' _ ~ __ , ~~ 4 3x04.50 6211.52 Mx(1 IRllood _ End Dir : S19x.3x' MD, 69.03' TVD ! i ~ I ~ ~ _ _ PS- 4I Zcd(Plan MPS -4l) i : 4000 ~ ~ Start it 3'?i 100' :5529.9' MD 3 x0.6'TVD - ~ i ~ ~ - - ~ I ~, I ~ 1 ~. CASING DETAILS ~ ~ - ~ ~ • . En Dir : 557U.xT MD, 3781. I'TVD ~ ~ '~ No TVD MD Namc Sizc . ~ ~ MP 41 F 3 l 50% l ' " ~ ~ - ~' Start Dir3'?ll )' :5747.95' MD, 37x7.02' VD t au . . rcW . I 335590 7542.57 7 7.0(1(1 I M I.. SECTION DET AILS ' MPS-41 T2.. I i Sec MD Inc Azi N D i Ni-S i Eo-W DLeg TFace VSec Target I ~ _ ~ End Dir : '6555,61' D, 3 I7.T TVD ~ ~ MPS- 1 4137.70 61.9(1 133.11 3493.35 -04833 83 7671 14 -I%I7?8 2 4611% 16 73 70 123 R3U.27 1171 16 090 O.UO 95 3 IU -37 1520.411 1951 77 i, ~ ~ ~ ~ ~ ~ ~ ! ~ - - - - ~ - - - __ ' . . . . %3 36%0 48 -I%35 06 3 3641 45 73 70 123 . 1197 70 . . 0 00 QUO . 19%3 70 i , . . . . . 4 5198.3% 88.00 114.00 3769.03 -209994 . 167260 . 3.10 -35.07 . 2530.71 ~ ~ Pl 41 W l MPS 5 54983% 88.110 11400 377950 -22?0.99 195150 090 O.W 283781 MPS-11 TL. a n - p 6 5529.90 88.00 114.00 37%Q(U -?23380 198Q27 QI70 O.UU 2%59.02 Plan MPS-4 IA 7 5570.%7 %%.34 II?.%? 37819 1 ?250.07 2017.85 3.011 -73.76 2%99.53 M PS-41 DD xO%~ 8 5747.95 88.34 112.82 378202 -2318.8 21%L00 U.OU 090 3074.41 9 583937 %7.%0 110.13 379QI U 352.16 ?266.02 3.UU -101.49 3164.31 MPS-01 T2.. 7 22 21 53 25x3 311 14 34 44 3x 75 10 G555b1 87.83 8K 63 3%17.7 0 -?468.11 396%.03 3.00 -90.32 3%22.39 I I 754258 87.83 88.63 3%SS.W -2444.47 395491 0.00 0.OD 4648.61 MPS-0I T3.. • S err -Sun P Y BP Planning Report Company: BP Amoco Date: 9/23/2008 Time: 13:55:23 Fagc: 1 Field: Milne Point Co-ordinate(NE) Reference: WeII: PIan.MPS-41 -Zed; True North :Site: M Pt S Pad Vertical (1'VD) Reference: RK6 72.50 72.5 Well: - Plan MPS-41 -Zed Section (VS) Reference: Well (O.OON,O:OOE,121.73Azi) Wellpath: Plan MPS-41A Survey Calculation Method: Minimum Curvature Dh OraGe Plan: Plan MPS-41 Wp14 Date Composed: 8/27/2008 Version: 7 Principal: Yes Tied-to: From: Definitive Path Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: M Pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-41 -Zed Slot Name: Well Position: +N/-S -81.86 ft Northing: 5999888.58 ft ~ Latitude: 70 24 36.523 N +E/-W -852.55 ft Easting : 565493.29 ft . Longitude: 149 28 0.159 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Dole Size Name ft ; ft in in 7542.57 3855.00 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 4541.58 3651.50 M87S 0.00 0.00 4772.12 3713.50 M87F 0.00 0.00 4943.23 3745.50 M80T 0.00 0.00 6211.52 3804.50 M80 1Rflood 0.00 0.00 Targets Map Map_' <~ Latitude -> <- Longitude => Name bescription TVD +N/-S +E/-W Northing- Fasting Deg Min Sec Deg Min Sec .Dip. Dir. ft ft ft ft ft MPS-41 Fault 1 50% rev1 3378.50 -1257.19 734.79 5998638.00 566239.00 70 24 24.158 N 149 27 38.626 W -Polygon 1 3378.50 -1257.19 734.79 5998638.00 566239.00 70 24 24.158 N 149 27 38.626 W -Polygon 2 3378.50 -1662.18 613.22 5998232.00 566121.00 70 24 20.176 N 149 27 42.190 W MPS-41 Fault 3 50% rev1 3652.50 -2184.88 3309.00 5997733.00 568821.00 70 24 15.028 N 149 26 23.200 W -Polygon 1 3652.50 -2184.88 3309.00 5997733.00 568821.00 70 24 15.028 N 149 26 23.200 W -Polygon 2 3652.50 -2564.46 3368.68 5997354.00 568884.00 70 24 11.295 N 149 26 21.456 W I -Plan out by 2224.37 at 3652.50 -1783.07 1121.22 5998115.58 566629.99 70 24 18.986 N 149 27 27.304 W MPS~1 Fault 2 50% rev1 3745.50 -1716.66 3747.16 5998205.00 569255.00 70 24 19.631 N 149 26 10.354 W -Polygon 1 3745.50 -1716.66 3747.16 5998205.00 569255.00 70 24 19.631 N 149 26 10.354 W -Polygon 2 3745.50 -2549.21 3796.87 5997373.00 569312.00 70 24 11.443 N 149 26 8.910 W -Plan out by 2313.20 at 3745.50 -1987.00 1449.81 5997914.56 566960.33 70 24 16.980 N 149 27 17.676 W ~ MPS-41 T1.. 3779.50 -2220.99 1951.50 5997685.00 567464.00 70 24 14.678 N 149 27 2.977 W MPS-41 T2.. 3790.10 -2352.16 2266.02 5997556.60 567779.63 70 24 13.387 N 149 26 53.763 W MPS-41 DD 80% 3855.00 -2444.48 3954.00 5997479.10 569468.20 70 24 12.472 N 149 26 4.304 W -Polygon 1 3855.00 -2187.37 1638.20 5997715.86 567150.45 70 24 15.009 N 149 27 12.157 W -Polygon 2 3855.00 -2187.81 1639.12 5997715.43 567151.37 70 24 15.005 N 149 27 12.130 W -Polygon 3 3855.00 -2230.99 1729.30 5997673.05 567241.92 70 24 14.580 N 149 27 9.488 W -Polygon 4 3855.00 -2271.92 1820.46 5997632.92 567333.43 70 24 14.177 N 149 27 6.817 W -Polygon 5 3855.00 -2312.41 1910.71 5997593.23 567424.02 70 24 13.779 N 149 27 4.173 W -Polygon 6 3855.00 -2312.86 1911.70 5997592.79 567425.01 70 24 13.774 N 149 27 4.144 W S err -Sun P Y BP Planning Report Company: BP Amoco Date: 9/23/2008 Time: 13:55:23 Page: 2 Field: Milne Point Co-ordinate(NE} leference: W eIL' Plan MPS.-41 -Zed, Tru e North :Site: M Pt S Pad Vertical ('TVD) Reference: RKB 72.50 72:5 .Well: Plan MPS-41 -:Zed Section (VS) )teference: Well {O .OON,O.OOE,121.73Azi ) Wellpath: Plan MPS-41A Survey CalcWatiou Method: M inimum Curvature Db: OraGe Targets Map Map <-= Latitude -> <- Longitude -~ Name Description T~?D +NFS +E/-W Northing ' Easting Deg . Min Sec Deg Min Sec Dip. INr. ft ft ft ft ft -Polygon 7 3855.00 -2327.45 1943.88 5997578.48 567457.32 70 24 13.631 N 149 27 3.201 W -Polygon 8 3855.00 -2354.58 2004.40 5997551.89 567518.07 70 24 13.364 N 149 27 1.428 W -Polygon 9 3855.00 -2388.25 2098.70 5997519.05 567612.65 70 24 13.032 N 149 26 58.665 W -Polygon 10 3855.00 -2401.82 2139.33 5997505.84 567653.39 70 24 12.899 N 149 26 57.475 W -Polygon 11 3855.00 -2421.03 2196.23 5997487.13 567710.45 70 24 12.710 N 149 26 55.808 W -Polygon 12 3855.00 -2434.41 2235.81 5997474.10 567750.15 70 24 12.578 N 149 26 54.648 W -Polygon 13 3855.00 -2454.53 2295.25 5997454.50 567809.75 70 24 12.380 N 149 26 52.907 W -Polygon 14 3855.00 -2485.84 2394.97 5997424.07 567909.74 70 24 12.072 N 149 26 49.985 W -Polygon 15 3855.00 -2505.50 2497.65 5997405.31 568012.57 70 24 11.878 N 149 26 46.977 W -Polygon 16 3855.00 -2525.18 2600.03 5997386.53 568115.11 70 24 11.684 N 149 26 43.978 W -Polygon 17 3855.00 -2545.00 2702.70 5997367.62 568217.94 70 24 11.489 N 149 26 40.969 W -Polygon 18 3855.00 -2548.05 2807.22 5997365.48 568322.48 70 24 11.458 N 149 26 37.907 W -Polygon 19 3855.00 -2549.52 2911.44 5997364.93 568426.69 70 24 11.443 N 149 26 34.853 W -Polygon 20 3855.00 -2550.38 2969.63 5997364.58 568484.88 70 24 11.435 N 149 26 33.148 W -Polygon 21 3855.00 -2550.69 3013.79 5997364.65 568529.04 70 24 11.432 N 149 26 31.854 W -Polygon 22 3855.00 -2550.38 3113.73 5997365.84 568628.97 70 24 11.434 N 149 26 28.926 W -Polygon 23 3855.00 -2547.60 3213.62 5997369.50 568728.82 70 24 11.461 N 149 26 25.999 W -Polygon 24 3855.00 -2544.80 3313.52 5997373.17 568828.68 70 24 11.488 N 149 26 23.072 W -Polygon 25 3855.00 -2542.01 3413.41 5997376.84 568928.53 70 24 11.515 N 149 26 20.145 W -Polygon 26 3855.00 -2539.19 3513.30 5997380.53 569028.38 70 24 11.542 N 149 26 17.219 W -Polygon 27 3855.00 -2533.22 3613.11 5997387.38 569128.13 70 24 11.601 N 149 26 14.294 W -Polygon 28 3855.00 -2526.85 3712.92 5997394.62 569227.87 70 24 11.663 N 149 26 11.369 W -Polygon 29 3855.00 -2520.47 3812.72 5997401.87 569327.60 70 24 11.725 N 149 26 8.445 W -Polygon 30 3855.00 -2514.10 3912.53 5997409.12 569427.34 70 24 11.787 N 149 26 5.521 W -Polygon 31 3855.00 -2511.35 3955.60 5997412.25 569470.38 70 24 11.814 N 149 26 4.259 W -Polygon 32 3855.00 -2380.89 3952.49 5997542.66 569466.13 70 24 13.097 N 149 26 4.348 W -Polygon 33 3855.00 -2378.91 3909.31 5997544.26 569422.94 70 24 13.117 N 149 26 5.613 W -Polygon 34 3855.00 -2374.32 3809.25 5997547.97 569322.85 70 24 13.162 N 149 26 8.545 W -Polygon 35 3855.00 -2369.76 3709.19 5997551.66 569222.76 70 24 13.208 N 149 26 11.476 W -Polygon 36 3855.00 -2367.48 3609.17 5997553.06 569122.74 70 24 13.231 N 149 26 14.407 W -Polygon 37 3855.00 -2370.54 3509.28 5997549.12 569022.89 70 24 13.201 N 149 26 17.334 W -Polygon 38 3855.00 -2373.62 3409.40 5997545.17 568923.05 70 24 13.171 N 149 26 20.260 W -Polygon 39 3855.00 -2376.70 3309.52 5997541.21 568823.21 70 24 13.141 N 149 26 23.187 W -Polygon 40 3855.00 -2377.95 3209.60 5997539.09 568723.31 70 24 13.130 N 149 26 26.115 W -Polygon 41 3855.00 -2378.32 3109.64 5997537.84 568623.37 70 24 13.126 N 149 26 29.044 W -Polygon 42 3855.00 -2378.69 3009.70 5997536.59 568523.44 70 24 13.123 N 149 26 31.972 W -Polygon 43 3855.00 -2378.87 2965.55 5997536.03 568479.30 70 24 13.122 N 149 26 33.266 W -Polygon 44 3855.00 -2379.18 2912.37 5997535.25 568426.13 70 24 13.119 N 149 26 34.824 W -Polygon 45 3855.00 -2373.14 2817.36 5997540.46 568331.08 70 24 13.178 N 149 26 37.608 W -Polygon 46 3855.00 -2367.02 2722.41 5997545.74 568236.09 70 24 13.239 N 149 26 40.390 W -Polygon 47 3855.00 -2360.81 2627.01 5997551.12 568140.65 70 24 13.300 N 149 26 43.185 W -Polygon 48 3855.00 -2338.88 2534.04 5997572.23 568047.50 70 24 13.516 N 149 26 45.909 W -Polygon 49 3855.00 -2310.98 2442.88 5997599.33 567956.11 70 24 13.791 N 149 26 48.580 W -Polygon 50 3855.00 -2283.11 2352.04 5997626.40 567865.03 70 24 14.066 N 149 26 51.242 W -Polygon 51 3855.00 -2266.31 2297.43 5997642.71 567810.28 70 24 14.231 N 149 26 52.842 W -Polygon 52 3855.00 -2254.26 2261.29 5997654.45 567774.04 70 24 14.350 N 149 26 53.900 W -Polygon 53 3855.00 -2232.85 2211.07 5997675.41 567723.64 70 24 14.560 N 149 26 55.372 W -Polygon 54 3855.00 -2215.88 2171.89 5997692.04 567684.32 70 24 14.727 N 149 26 56.519 W -Polygon 55 3855.00 -2176.15 2080.16 5997730.96 567592.25 70 24 15.118 N 149 26 59.207 W -Polygon 56 3855.00 -2149.82 2019.31 5997756.75 567531.18 70 24 15.377 N 149 27 0.990 W -Polygon 57 3855.00 -2137.24 1989.78 5997769.07 567501.54 70 24 15.501 N 149 27 1.855 W -Polygon 58 3855.00 -2136.85 1988.88 5997769.45 567500.64 70 24 15.505 N 149 27 1.881 W -Polygon 59 3855.00 -2097.60 1898.08 5997807.90 567409.51 70 24 15.891 N 149 27 4.542 W -Polygon 60 3855.00 -2057.61 1806.49 5997847.08 567317.58 70 24 16.285 N 149 27 7.225 W -Polygon 61 3855.00 -2015.06 1716.03 5997888.83 567226.76 70 24 16.703 N 149 27 9.876 W -Polygon 62 3855.00 -2014.63 1715.11 5997889.25 567225.83 70 24 16.708 N 149 27 9.903 W -Polygon 63 3855.00 -2187.37 1638.20 5997715.86 567150.45 70 24 15.009 N 149 27 12.157 W MPS-41 Geo Poly 3855.00 -2444.47 3954.01 5997479.10 569468.20 70 24 12.472 N 149 26 4.304 W -Polygon 1 3855.00 -2355.79 3979.59 5997568.00 569493.00 70 24 13.344 N 149 26 3.553 W -Polygon 2 3855.00 -2538.01 4001.99 5997386.00 569517.00 70 24 11.552 N 149 26 2.900 W -Polygon 3 3855.00 -2564.83 3524.69 5997355.00 569040.00 70 24 11.290 N 149 26 16.885 W -Polygon 4 3855.00 -2573.97 3084.55 5997342.00 568600.00 70 24 11.202 N 149 26 29.781 W • S err -Sun P Y BP Planning Report Company: BP Amoco Date: 9/23/2008 Time: 13:55:23: Page::' 3 Field: MIIne Point Co-ordinate(NE) Reference: W eIL' Plan MPS-41 -Zed, True North Site: M Pt S Pad Vertical. (TVD) Reference: RKB'72.50 72.5 Well: Plan. MPS-41 -Zed Section (VS) Reference: Well, (O.OON,O:OOE, 121.73Azi) Wellpath: Plan MPS-41A Survey Calculation Method: ' Minimum Curvature Db: -Oracle Targets Map Map <-- Latitude -a <- ..Longitude -> Name Description TVD +N/-S +E/-W Northing.. Easting Deg: Min "Sec Deg, Mi n. Sec Dip. Dir. ft ft ft ft ft -Polygon 5 3855 .00 -2568.68 2709.55 5997344.00 568225.00 70 24 11.256 N 149 26 40.769 W -Polygon 6 3855 .00 -2503.71 2372.07 5997406.00 567887.00 70 24 11.896 N 149 26 50.656 W -Polygon 7 3855 .00 -2382.56 2015.09 5997524.00 567529.00 70 24 13.088 N 149 27 1.115 W -Polygon 8 3855 .00 -2247.94 1718.23 5997656.00 567231.00 70 24 14.413 N 149 27 9.813 W -Polygon 9 3855 .00 -2158.31 1532.99 5997744.00 567045.00 70 24 15.295 N 149 27 15.240 W -Polygon 10 3855 .00 -1967.37 1656.68 5997936.00 567167.00 70 24 17.173 N 149 27 11.614 W -Polygon 11 3855 .00 -2045.85 1825.02 5997859.00 567336.00 70 24 16.400 N 149 27 6.682 W -Polygon 12 3855 .00 -2238.84 2276.38 5997670.00 567789.00 70 24 14.501 N 149 26 53.458 W -Polygon 13 3855 .00 -2339.72 2603.54 5997572.00 568117.00 70 24 13.508 N 149 26 43.873 W -Polygon 14 3855 .00 -2360.47 2917.40 5997554.00 568431.00 70 24 13.303 N 149 26 34.676 W -Polygon 15 3855 .00 -2356.62 3276.49 5997561.00 568790.00 70 24 13.339 N 149 26 24.155 W -Polygon 16 3855 .00 -2342.79 3638.65 5997578.00 569152.00 70 24 13.473 N 149 26 13.543 W -Polygon 17 3855 .00 -2355.79 3979.59 5997568.00 569493.00 70 24 13.344 N 149 26 3.553 W MPS-41 T3.. 3855 .00 -2444.47 3954.01 5997479.10 569468.20 70 24 12.472 N 149 26 4.304 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target.. ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 4137.70 61.90 133.11 3493.35 -1548.33 830.27 0.00 0.00 0.00 0.00 4608.16 73.70 123.83 3671.14 -1817.28 1171.16 3.10 2.51 -1.97 -37.95 4641.45 73.70 123.83 3680.48 -1835.06 1197.70 0.00 0.00 0.00 0.00 5198.38 88.00 114.00 3769.03 -2099.04 1677.60 3.10 2.57 -1.76 -35.07 5498.38 88.00 114.00 3779.50 -2220.99 1951.50 0.00 0.00 0.00 0.00 MPS-41 Ti.. 5529.90 88.00 114.00 3780.60 -2233.80 1980.27 0.00 0.00 0.00 0.00 5570.87 88.34 112.82 3781.91 -2250.07 2017.85 3.00 0.84 -2.88 -73.76 5747.95 88.34 112.82 3787.02 -2318.72 2181.00 0.00 0.00 0.00 0.00 5839.37 87.80 110.13 3790.10 -2352.16 2266.02 3.00 -0.60 -2.94 -101.49 MPS-41 T2.. 6555.61 87.83 88.63 3817.70 -2468.11 2968.03 3.00 0.00 -3.00 -90.32 7542.58 87.83 88.63 3855.00 -2444.47 3954.01 0.00 0.00 0.00 0.00 MPS-41 T3.. Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooVCo ft deg deg ft ft ft ft ft degN00ft ft ft 4137.70 61.90 133.11 3493.35 3420.85 1520.40 -1548.33 830.27 0.00 5998347.73 566337.03 Start Dir 3. . 4200.00 63.43 131.78 3521.96 3449.46 1574.77 -1585.68 871.11 3.10 5998310.75 566378.19 MWD+IFR 4300.00 65.91 129.72 3564.74 3492.24 1664.03 -1644.66 939.58 3.10 5998252.38 566447.17 MWD+IFR 4400.00 68.41 127.74 3603.56 3531.06 1755.49 -1702.30 1011.47 3.10 5998195.37 566519.55 MWD+IFR 4500.00 70.94 125.83 3638.29 3565.79 1848.89 -1758.44 1086.57 3.10 5998139.90 566595.13 MWD+IFR 4541.58 72.00 125.05 3651.50 3579.00 1888.23 -1781.30 1118.69 3.10 5998117.32 566627.45 M87S 4544.82 72.08 124.99 3652.50 3580.00 1891.31 -1783.07 1121.22 3.10 5998115.58 566629.99 MPS-41 F u 4600.00 73.49 123.98 3668.83 3596.33 1943.95 -1812.91 1164.66 3.10 5998086.12 566673.69 MWD+IFR 4608.16 73.70 123.83 3671.14 3598.64 1951.77 -1817.28 1171.16 3.10 5998081.81 566680.22 End Dir 4641.45 73.70 123.83 3680.48 3607.98 1983.70 -1835.06 1197.70 0.00 5998064.26 566706.92 Start Dir 3. 4700.00 75.19 122.75 3696.18 3623.68 2040.09 -1866.02 1244.85 3.10 5998033.73 566754.33 MWD+IFR 4772.12 77.03 121.44 3713.50 3641.00 2110.09 -1903.21 1304.16 3.10 5997997.06 566813.96 M87F 4800.00 77.74 120.94 3719.59 3647.09 2137.29 -1917.30 1327.43 3.10 5997983.18 566837.36 MWD+IFR 4900.00 80.30 119.16 3738.63 3666.13 2235.41 -1966.45 1412.40 3.10 5997934.78 566922.74 MWD+IFR 4943.23 81.42 118.41 3745.50 3673.00 2278.04 -1987.00 1449.81 3.10 5997914.56 566960.33 M80T 5000.00 82.88 117.42 3753.26 3680.76 2334.14 -2013.32 1499.50 3.10 5997888.68 567010.24 MWD+IFR 5100.00 85.46 115.69 3763.42 3690.92 2433.21 -2057.78 1588.48 3.10 5997845.00 567099.60 MWD+IFR 5198.38 88.00 114.00 3769.03 3696.53 2530.71 -2099.04 1677.60 3.10 5997804.53 567189.07 End Dir : 1 5200.00 88.00 114.00 3769.09 3696.59 2532.31 -2099.70 1679.08 0.00 5997803.88 567190.56 MWD+IFR 5300.00 88.00 114.00 3772.58 3700.08 2631.35 -2140.35 1770.38 0.00 5997764.04 567282.20 MWD+IFR 5400.00 88.00 114.00 3776.07 3703.57 2730.38 -2181.00 1861.68 0.00 5997724.20 567373.84 MWD+fFR 5498.38 88.00 114.00 3779.50 3707.00 2827.81 -2220.99 1951.50 0.00 5997685.00 567464.00 MPS-41 T1 .. rent S err -Sun P Y BP Planning Report Company:. BP Amoco Date: 9/23/2008 Time: 13:55:23 Page: 4 Field: Milne Point Co-ordinate(NE)Reference: Well: Plan MPS-41 - fed, True North .Site: M Pt S Pad Vertical,(TVD) Reference: RK B 72.50 72.5 Well: Plan MPS-41 -Zed Section(VS)Reference: Well (O.OON,0.OOE,121.73Azi) Wellpath: Plan MPS-4 1A S urveyCalculation Metbod: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN NIapE Tool/Co ft deg deg ft ft ft ft ff deg/100ft "ft ft 5500.00 88.00 114.00 3779.56 3707.06 2829.41 -2221.64 1952.98 0.00 5997684.36 567465.49 MWD+IFR 5529.90 88.00 114.00 3780.60 3708.10 2859.02 -2233.80 1980.27 0.00 5997672.44 567492.89 Start Dir 3. 5570.87 88.34 112.82 3781.91 3709.41 2899.53 -2250.07 2017.85 3.00 5997656.51 567530.60 End Dir 5600.00 88.34 112.82 3782.75 3710.25 2928.30 -2261.36 2044.69 0.00 5997645.45 567557.54 MWD+IFR 5700.00 88.34 112.82 3785.64 3713.14 3027.06 -2300.13 2136.83 0.00 5997607.50 567650.00 MWD+IFR 5747.95 88.34 112.82 3787.02 3714.52 3074.41 -2318.72 2181.00 0.00 5997589.30 567694.33 Start Dir 3. 5800.00 88.03 111.29 3788.67 3716.17 3125.69 -2338.25 2229.22 3.00 5997570.19 567742.72 MWD+IFR 5839.37 87.80 110.13 3790.10 3717.60 3164.31 -2352.16 2266.02 3.00 5997556.60 567779.63 MPS-41 T .. 5900.00 87.79 108.31 3792.43 3719.93 3223.46 -2372.11 2323.23 3.00 5997537.16 567837.01 MWD+IFR 6000.00 87.78 105.31 3796.30 3723.80 3320.00 -2401.00 2418.87 3.00 5997509.11 567932.89 MWD+IFR 6100.00 87.78 102.31 3800.17 3727.67 3415.07 -2424.84 2515.90 3.00 5997486.12 568030.12 MWD+IFR 6200.00 87.78 99.30 3804.05 3731.55 3508.40 -2443.57 2614.04 3.00 5997468.26 568128.41 MWD+IFR 6211.52 87.78 98.96 3804.50 3732.00 3519.02 -2445.40 2625.41 3.00 5997466.53 568139.79 M80_1 Rflo 6300.00 87.79 96.30 3807.92 3735.42 3599.73 -2457.13 2713.03 3.00 5997455.56 568227.50 MWD+IFR 6400.00 87.80 93.30 3811.77 3739.27 3688.81 -2465.49 2812.59 3.00 5997448.08 568327.13 MWD+IFR 6500.00 87.82 90.30 3815.60 3743.10 3775.40 -2468.63 2912.46 3.00 5997445.82 568427.01 MWD+IFR 6555.61 87.83 88.63 3817.70 3745.20 3822.39 -2468.11 2968.03 3.00 5997446.83 568482.56 End Dir 6600.00 87.83 88.63 3819.38 3746.88 3859.55 -2467.04 3012.37 0.00 5997448.28 568526.89 MWD+IFR 6700.00 87.83 88.63 3823.16 3750.66 3943.26 -2464.65 3112.27 0.00 5997451.55 568626.76 MWD+IFR 6800.00 87.83 88.63 3826.94 3754.44 4026.98 -2462.25 3212.17 0.00 5997454.82 568726.62 MWD+IFR 6900.00 87.83 88.63 3830.72 3758.22 4110.69 -2459.86 3312.07 0.00 5997458.09 568826.49 MWD+IFR 7000.00 87.83 88.63 3834.50 3762.00 4194.40 -2457.46 3411.97 0.00 5997461.36 568926.35 MWD+IFR 7100.00 87.83 88.63 3838.28 3765.78 4278.12 -2455.07 3511.87 0.00 5997464.63 569026.22 MWD+IFR 7200.00 87.83 88.63 3842.05 3769.55 4361.83 -2452.68 3611.77 0.00 5997467.90 569126.08 MWD+IFR 7300.00 87.83 88.63 3845.83 3773.33 4445.54 -2450.28 3711.67 0.00 5997471.17 569225.95 MWD+IFR 7400.00 87.83 88.63 3849.61 3777.11 4529.26 -2447.89 3811.57 0.00 5997474.44 569325.82 MWD+IFR 7500.00 87.83 88.63 3853.39 3780.89 4612.97 -2445.49 3911.47 0.00 5997477.71 569425.68 MWD+IFR ' 7542.58 87.83 88.63 3855.00 ~ 3782.50 4648.61 -2444.47 3954.01 0.00 5997479.10 569468.20 MPS-41 T .. lent WeLL ur: r,vts ANTI-COLLISION SETTINGS cuxu':wv ul~ r:vls su leehv rlcuGltAM1f Nance NS ~I:'-W' NnNling I~iiaing LatiNJc Luug~wJe Slot Interpolation Mc[hod:MD Interval: ?S.UO nl'Anux„ Ilcplh Fm U. prh I,i S~rv~yl'lun I u~l flan M1tl'$-JI-/cJ -%I.%(, -%5?55 5444%%%.5% 565443 _'Y 7n'?J:16.5?.iN 1J4'?%'W.154W N':1 Deptll Ran~,e Ert\Ill: a137.7U TU: 7s-~2.JK t'aliulnn„n Mcthi,J: Alinin~unt l'un.~nuc Jli-i.-'ll 'S J?.+x I'I~nixJ: l'I:,n nil'SJI \\~IJ\] n1KU~IFIt-M1lti Maximum Range 95U.79 Reference: Plan: Plun MPS-41 WpIA Itrtnr sp>nnr. Iscusn Scan MCth„J: irev CVlmJcr N„nl~ Lrt„r SUriu.c: I:Ili~0ca1 ~ l'nvn~ 0160 From Colour To MD N'I:LLI'A I II Ufa I AILS rla, M1,rs-tln 1 ~ 750 i'arcnl l4'c111>atll. Ilan MI'1JI .J V 250 500 Le,,.. nun J13770 33 0 s00 750 ec,:uaw~i~ Itlaizzsu ~.>olt 1~ 750 1000 v k n,.n od~~ rn;~n sWn~a_ q' 1000 1250 +n~~ N.-s c/-w tt„~» n u 125 ~ Izso Isoo 131 ]i` .L.q Itn~l 3,?I ~ Isoo nso ~~ 1750 2000 ~ 2000 2250 2250 2500 L101N1 I OO 1 ~,. 2500 2750 nlr5-ui lnu'1-u?l. nl:'i~r enk nlr> 1 Inu 1. u l nl era ~ 2750 3000 - vrs Ivull.M1l, K.L C 3000 3250 vrl Inul _ul nl I %~a - vrl x nu t 1' . v, x,1, __ 3250 3500 ~ xfl'S-nh M1f l'1-0%1'111 1. nL,,,. Hi.1 - nu'1-lolM1lrslu,v.nryl„re;,~ nu's n n'1 1 n n, It~ ~ 75 3500 3750 - . . ~p~r . m - M1u's-171m1'S-3n. nwn,r a..w 3750 4000 - rw~An_.xlrl~nnn_~yi.nlal„reap ' 4000 4250 1'Inn M1II 1~1-/41111 4111-JI). Nlll.eelfel - ' ~~~~ ~ '~ .-`~~' '~ ~ \~ 4250 500 4500 4750 s-J3 l e I. nl:,~,.r K~,I: ren, ~ nu - rl~aM1,lsJl:, - rl:,,nnlan,ru 0 a`' ~ ~~~~'-, 50 s 00 5000 5250 ' /~ i~ A;~~~, ~~' s2 0 5500 I l i ~ l~ 1 $ l /il~ ~Il/ l;, _ P~ ~~~,` 0 270 90 5 ~ j~ ~ "; ~ ' 1 ~\ , ~ ~~~ ~ / l~ 1 ~ . ~ I ' 0 , ~ ~~ ~~ ~V i , ~~ ~ ~ ~, ~~/ /,! ~ i / ~~ /,% ~ ~ ~ ~ :. ~ ~ ~ " 240 ~ ~ ~ ~~= ~~~ ~~~.A \~ , ~, ~ , ~ ~~,~~ 120 ~ ~ ~i . .k j ~~~; - ; -, u 100 ~ ~ ~~` ~~ ~~ ~~ %~ ~~ ~ %; Pre Plans Removed. , ;~ ~ ~ ` ~'% ~h ~ ~ See AC Scan for Plans \~'~~~- \ %-~ ~ Parents Profile @ No Errors 125 \\~~~. `~_: '- ' lti('IIUN DIiI:,IL$ `_ 21 ~~~--~~ 1.. M1fU luc ~ ~ SO i.. nv7]u vl ~nl ~\n I VD x3.11 3443 )c -M-S ~ li'-W ULce 'I F.mc \ Soc ram_ar -liax?~ x3nz~ o.nti ulxl Is_o.Ju 150 .. Jfalx.l6 73.70 JGJI iS ]3]11 J 514%iR %N.11U 1^i.%? 36]1.14 I'_lfti ;6%0-41{ 114.IMI 3]04.ni -1x17_% 1171.10 3.10 -1745 IYSI?~ -1x350fi 1147.711 nlxl 0.1111 14%1. U X041114 10]].fAl 3.10 -ic,0~ 25)0.71 iJ4N i% %%.0U I IJ.UII 1779.111 - 20.44 1451.50 U.INI 11.1X1 ?A ].AI A11'1-JI 11- ' ' 160 6 -5~U,411 %%.W v]LL%7 %%_i4 IIJ.I10 3]lillGU II2.%2 3]%I HI _i1.%U 14%U-_ ] OIMI II.OU 2%5 !11' _'50,11] '111"!-%5 3.1X1 -]3.](. ?%49.53 p 18 0 5]4].45 %%3J 5%34}7 N7%Il II?.%~ 3]%]0? 110.11 1740.10 -?il%]? ~I%I.IN) II.W 0110 3p]4.JI --'_112.16 ?~6GU2 1W -101.44 316111 M1t OS-il l2_ Travelling Cylinder Azimuth (TFO+AZI) [d eg] vs III 6555.61 N]-%3 II ]5J?,5% %'1-x1 Centre to Centre Separation [SOft/in] %x.63 1%1 ]. ]fl %,5-61 3%55xy~ -'_J6%.11 S6%.Ul 1.110 -Wl ~~ 3%~~34 ->JJ4J] 39iJ 111 111X1 111X1 J61%.61 MI'1J1 13. J S err -Sun P Y Anticollision Report Company:. BP Amoco Date: 9/23/2008 Time: 13:51:32 Page: 1 Field: Milne Point Reference Site: M Pt S Pad Co-ordinate(NE) Reference: WeIL• Plan MPS-41 -Zed, True North Reference Well: Plan MPS-41 -Zed Vertical (TVD) Reference: RK672.50 72.5 Reference Wellpath: Plan MPS-41A` Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 4137.70 to 7542.58 ft Scan Method: Trav Cylinder North Maximum Radius: 950.79 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/27/2008 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 34.71 800.00 Planned: Plan MPS-41 Wp 6.0 V32 (2) CB-GYRO-SS Camera based gyro single shots 800.00 4137.70 Planned: Plan MPS-41 Wp 6.0 V32 ( 2) MWD+IFR +MS MWD +IFR + Multi Station 4137.70 7542.58 Planned: Plan MPS-41 Wp14 V7 MWD+IFR +MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft , ft in in 7542.57 3855.00 7.000 8.500 7" Summary <--------- Offset Wellpath. -- --> Reference .Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt S Pad MPS-03 MPS-03 V21 Out of range M Pt S Pad MPS-03 MPS-03L1 V10 Out of range M Pt S Pad MPS-05 MPS-05 V2 4648.33 7925.00 516.69 66.04 450.64 Pass: Major Risk M Pt S Pad MPS-05 MPS-05L1 V2 4652.54 7900.00 454.26 64.73 389.52 Pass: Major Risk M Pt S Pad MPS-08 MPS-08 V10 4255.93 4800.00 364.32 59.07 305.26 Pass: Major Risk M Pt S Pad MPS-08 MPS-08PB1 V9 4255.93 4800.00 364.32 59.07 305.26 Pass: Major Risk M Pt S Pad MPS-10 MPS-10A V4 6346.06 8915.00 391.12 70.70 320.42 Pass: Major Risk M Pt S Pad MPS-11 MPS-11 V5 5857.23 5175.00 210.87 121.42 89.45 Pass: Major Risk M Pt S Pad MPS-37 MPS-37 V7 4140.92 4100.00 648.89 84.37 564.52 Pass: Major Risk M Pt S Pad Plan Anges Plan Anges VO Plan: PI 5384.86 5025.00 443.12 121.01 322.10 Pass: Major Risk M Pt S Pad Plan MPS-41 -Zed Plan MPS-41 V3 Pl an: P 4150.00 4150.00 0.04 0.71 -0.67 FAIL: NOERRORS M Pt S Pad Plan Xenon MPS-43 Xenon V1 Plan: Xenon W 4152.33 3975.00 461.83 88.12 373.72 Pass: Major Risk Site: M Pt S Pad Well: MPS-05 Rule Assigned: Major Risk Wellpath: MPS-05 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-H S Casiog/HSDistance Area ` Deviation Warning ft ft, ft ft ft ft deg deg in ft ft ft 4642.63 3680.81 7075.00 4190.92 11.43 8.35 358.71 234.91 7.625 934.72 78.40 856.32 Pass 4641.86 3680.59 7100.00 4193.61 11.43 8.35 357.68 233.86 7.625 916.32 77.79 838.54 Pass 4640.90 3680.32 7125.00 4195.23 11.42 8.35 356.64 232.82 7.625 897.52 77.18 820.34 Pass 4639.74 3680.00 7150.00 4195.94 11.42 8.36 355.60 231.78 7.625 878.44 76.57 801.87 Pass 4638.39 3679.62 7175.00 4195.86 11.42 8.36 354.56 230.73 7.625 859.16 75.94 783.22 Pass 4636.90 3679.20 7200.00 4195.11 11.41 8.36 353.50 229.67 7.625 839.77 75.30 764.47 Pass 4635.69 3678.86 7225.00 4194.67 11.41 8.36 352.38 228.55 7.625 820.82 74.63 746.20 Pass 4634.84 3678.62 7250.00 4194.64 11.40 8.37 351.18 227.36 7.625 802.41 73.91 728.51 Pass 4633.99 3678.38 7275.00 4194.17 11.40 8.37 349.96 226.13 7.625 784.05 73.17 710.88 Pass 4633.10 3678.13 7300.00 4193.26 11.40 8.37 348.70 224.88 7.625 765.76 72.42 693.34 Pass 4632.17 3677.87 7325.00 4192.42 11.39 8.38 347.38 223.55 7.625 747.91 71.63 676.28 Pass 4631.34 3677.64 7350.00 4191.80 11.39 8.38 345.98 222.15 7.625 730.62 70.80 659.81 Pass 4630.90 3677.51 7375.00 4191.49 11.39 8.39 344.50 220.68 7.625 713.94 69.94 644.00 Pass 4630.71 3677.46 7400.00 4191.24 11.39 8.39 342.96 219.13 7.625 697.74 69.04 628.69 Pass 4630.57 3677.42 7425.00 4190.63 11.39 8.40 341.36 217.53 7.625 681.77 68.13 613.64 Pass 4630.52 3677.41 7450.00 4189.69 11.39 8.41 339.71 215.88 7.625 666.07 67.21 598.85 Pass 4630.58 3677.42 7475.00 4188.44 11.39 8.41 337.99 214.17 7.625 650.66 66.28 584.37 Pass 4631.00 3677.54 7500.00 4187.16 11.39 8.42 336.21 212.38 7.625 635.74 65.35 570.40 Pass 4631.90 3677.80 7525.00 4186.01 11.39 8.43 334.34 210.51 7.625 621.49 64.41 557.08 Pass 4633.09 3678.13 7550.00 4185.03 11.40 8.44 332.38 208.55 7.625 608.01 63.48 544.53 Pass MPU S-41A SPACING EXCEPTION REQUIRED.tXt SPACING EXCEPTION REQUIRED: due to rig schedule, operator requests permission to drill as scheduled. Well will not be completed or put on production until mid-2009. The application for spacing exception will be submitted shortly. SFD 10/27/2008 Page 1 RE: MPS-41 Permit, Sundry for Abandonment, and MPS-41A PTD Page 1 of 2 Maunder, Thomas E (DOA) From: Hanson, Paul [Paul.Hanson1@bp.com] Sent: Monday, October 27, 2008 7:30 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: RE: MPS-41 Permit, Sundry for Abandonment, and MPS-41A PTD Tom, Here are the answers to your questions. 1. The well will indeed be suspended when we leave it. The plan is to return in the summer of'09 and complete the well with (most likely) a 4-1/2" internal slotted liner inside the 7" slotted liner. This liner will have a DTS (distibuted temperature survey) sensor in it to tell where oil is coming from along the length of the lateral. That will be attached in some fashion to the PCP, and a tubinglrod string will be run to surface. The absolute details of the completion are being worked at this time, and the completions for all three MPS-wells will be covered under separate AFEs and Permits. 2. There will be a tie-back sleeve with the option to tie the 7" all the way back to surface. At present, this is not planned, but the option is there. 3. This surface casing will be 9-5/8" 47#, which explains the 8-1/2" hole. The well obviously does not require the heavier casing, but we got a "deal" on this. So, the hole size planned is 8-1/2". Please let me know is you have any additional questions. Best Regards, Paul Hanson ODE-ACT Office: 564-4195 Cell: 360-0388 From: Maunder, Thomas E (DOA) [mailtoaom.maunder@aiaska.gov] Sent: Friday, October 24, 2008 1:26 PM To: Hanson, Paul Cc: Kara, Danny T Subject: RE: MPS-41 Permit, Sundry for Abandonment, and MPS-41A PTD Paul, I am reviewing the permit for MPS-41A and have a couple of questions. 1. I left you a message regarding how the well will be "left" with a deep RBP and kill string. In the regulatory world, this leaves the well suspended. What are the plans for returning to the well to run the completion? 2. Last year the surface casing in MPS-37 was set about the same depth as planned for MPS-41. You are only planning to hang asolid/slot liner in the production interval. Are there any plans to tie-back the 7"? 3. Most BP wells have 8-3/4" hole drilled rather than 8-1/2". Is the planned hole size 8-112"? Thanks in advance. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Tuesday, October 21, 2008 2:56 PM To: Maunder, Thomas E (DOA) Subject: RE: MPS-41 Permit, Sundry for Abandonment, and MPS-41A PTD 10/27/2008 RE: MPS-41 Permit, Sundry for Abandonment, and MPS-41A PTD Page 2 of 2 Tom, I returned from lunch today to find the drilling permit for MPS-41 (the appraisal well). I did not, however find the Sundry for its abandonment or the Drilling Permit for MPS-41A (the horizontal UGNU producer. Am I correct in assuming that these are to follow? Best Regards, Paul Hanson 10/27/2008 MPS-41 plans Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, October 23, 2008 2:02 PM To: 'Hulm, Erik J' Cc: Maunder, Thomas E (DOA); Roby, David S (DOA) Subject: RE: MPS-41 plans Attachments: 081023_MPU_S-41A Location_Map.pdf Eric, The Ugnu sands at Milne Point are not a formally defined pool, so statewide spacing requirements apply. Page 1 of 2 As described below, the proposed testing program indicates that MPS-41 will not require a spacing exception because MPS-41 will not be completed (which is defined in 20 AAC 25.990 (14) as being equipped and conditioned so that it is capable of producing or injecting fluids). However, the planned horizontal section named MPS-41A will require a spacing exception per the statewide rules of 20 AAC 25.055 (a)(3) because the Ugnu-M reservoir section opened by MPS-41A will lie within the same governmental quarter section as existing Ugnu-M perforations in MPS-37 (the SW'/. of Section 7 as I plot the wells -see attached file). The top of MPS-41A's slotted liner may also lie within 1,000 feet of the MPS-37 perforations. Spaang exception application requirements are presented in 20 AAC 25.055 (d}. The spacng exception process takes about 6 weeks from receipt of the application. Please let me know if you have any questions. Thanks, Steve Davies AOGCC 907-793-1224 From: Hulm, Erik J [mailto:Erik.Hulm@bp.com] Sent: Thursday, October 23, 2008 12:04 PM To: Davies, Stephen F (DOA) Subject: MPS-41 plans Steve, As discussed yesterday over the phone, here is the paragrah summarizing our plans for the MPS-41 well at Milne Point. In addition, I've attached a map showing the location of the MPS-37 Ugnu penetration and the Ugnu target zone for the MPS-41 pilot and horizontal well sections. The MPS-41 well consists of a pilot hole and horizotnal section in the Ugnu reservoir. The pilot hole is designed to collect downhole log and fluid data. The fluid data consists of downhole fluid samples captured in pressurized chambers. The collection of downhole fluid samples has proven very difficult in the Ugnu heavy oil reservoirs. The formations are weak and the oil is very viscous. In MPS-41 we are employing multipe approaches to collect downhole PVT oil samples. The first will be an openhole MDT and the second a cased hole drillstem tool. Historically, the MDT has had little success in collecting downhole samples, but with modifications to the tool and standard operating procedures we hope to improve on previous attempts. The cased hole drillstem approach has been more successful and is included in MPS-41 to increase our chances of collecting a downhole PVT oil sample. The drillstem approach involves casing the hole to keep the formation from collapsing, running in with a drillstem tool, perforating the casing, and drawing enough oil into the tubing to collect samples via pressurized chambers in the drillstem tool and via wireline. Total volume of fluid collected downhole in the pressurized chambers will be less than 5 gallons. This is not a production test and the well will not flow to surface. Once we've collected the samples, the pilot hole and assoaated perfs will be abandoned in preparation for the horizontal 10!23/2008 MPS-41 plans section. The horizontal section will b~uspended until 3Q of 2009, when a produ~n test will be conducted. «S-PadPilot.pdf» Take care, Erik Hulm BP Heavy Oil Subsurtace Team Leader phone: (907 564-4095 cell: (90~ 242-7349 email: hulmej dL?bp.com Page 2 of 2 10/23/2008 MPS-41 plans Davies, Stephen F (DOA) From: Hulm, Erik J [Erik.Hulm@bp.com] Sent: Thursday, October 23, 2008 12:04 PM To: Davies, Stephen F (DOA) Subject: MPS-41 plans Attachments: S-PadPilot.pdf Page 1 of 1 Steve, As discussed yesterday over the phone, here is the paragrah summarizing our plans for the MPS-41 well at Milne Point. In addition, I've attached a map showing the location of the MPS-37 Ugnu penetration and the Ugnu target zone for the MPS-41 pilot and horizontal well sections. The MPS-41 well consists of a pilot hole and horzotnal section in the Ugnu reservoir. The pilot hole is designed to collect downhole log and fluid data. The fluid data consists of downhole fluid samples captured in pressurized chambers. The collection of downhole fluid samples has proven very difficult in the Ugnu heavy oil reservoirs. The formations are weak and the oil is very viscous. In MPS-41 we are employing multipe approaches to collect downhole PVT oil samples. The first will be an openhole MDT and the second a cased hole drillstem tool. Historically, the MDT has had little success in collecting downhole samples, but with modifications to the tool and standard operating procedures we hope to improve on previous attempts. The cased hole drillstem approach has been more successful and is included in MPS-41 to increase our chances of collecting a downhole PVT oil sample. The drillstem approach involves casing the hole to keep the formation from collapsing, running in with a drillstem tool, pertorating the casing, and drawing enough oil into the tubing to collect samples via pressurized chambers in the drillstem tool and via wireline. Total volume of fluid collected downhole in the pressurized chambers will be less than 5 gallons. This is not a production test and the well will not flow to surface. Once we've collected the samples, the pilot hole and assoaated perfs will be abandoned in preparation for the horizontal section. The horizontal section will be suspended unti13Q of 2009, when a production test will be conducted. «S-PadPilot.pdfi> Take care, Erik Hulm BP Heavy Oil Subsurtace Team Leader phone: (907) 564-4095 cell: (907) 242-7349 email: hulmej@bp.com 10/23/2008 ~~ \~~ ~1 ~1 ~ ~~' ~ ~ a~i M J ~ ~ . ~ ~ ~ ~_ , ~1~M F. '? ADL390109 ~ T ADL390110 -- __ -- o: ~ ~ ~~ ~ 1-NE N N 6-NW ~ - ~ - - - - 2-NW 2-ivc ~ ~ . ~ , ~~ill ~. ~ r ~ ~ ~ 4 ~ o ~ ~ ~!~o ~.~ ~ ~ ~ ~~~ ~ ~ ~.~~ ~ 2-SEi ~ '1-Sly/ ~ ~ '.1-~E ~ 6-SW ~, ~ 5-S,~V' ~ 5- o s ~ ~ ~ ~~ '~ , <k ~ j , ~` ~ - ~' ~ I I ~_ 1 MPU S PAD I ~,, _„, ~_ ,. s ~~ ~`' ~ '~ r 11-N~ „ ~, t~~~ MPS ~ a ____ _ _ ,~ ~ ~ ~ ,, ~i, _~ Surface ~~,MP5~7 ~ ~~~ - Surface MPS-37 ~ ' Ugnu ~ 7-5W I I I 11-SE ~ 12-SW 12-SE 7,~E T MPS-41 ~ I` - ~------------ PilotUgni.a-- --_.~----------.--_~ 0 i ~ \~ MPS-41 ' ~ ~ orizontal Heel U" - \~ ~~ : o~ ~~ " ~ , Ugnu D ~~ ~ ~,.,`~ ' - BP EXPLORATION (ALASKA) INC. ~~ ~ 13 ` ,18 Q ~~~I - MILNE POINT UNIT ~ ~~ ~ _ - ~ ~ `~~~ ~ S-PAD PILOT ~~ ~ ; ~~ ' ~-~ aa~~~ _ . DATE: SCALE: FIGURE: October 2008 1" =3000' 1 Im15752.tli Alaska Department of Natural Resources Land Administration System Page 1 of j~` ,,~~ .. , . Pl.,is I .,.;~c~~r's Search State Cabins e~~ ~r~es !. 4S ~~sr~ I Case Abstract I Cass Detail I Land Abstract I~~/e: AUL 3801 l0 '~"'~' Search for ~~atus Plat Updates ;~ ~~i IU!Ib/20US Cnstomej°: 000107377 BP EXPLORAIIC?ti' (~~L.~S1~~1) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~~3a~ OlL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV O1L AND GAS Cace Statars: 3 5 ISSUED Status Date: 01 /29/ l 993 TotalAcres: 2437.000 Date Initiated: 08/25/1992 Once of Prlma~y Responsibilih~: DOG DIV OIL AND GAS Last Transaction Date: 03/18/2005 Case Strb~7pe : NORTH SLOPE LastTran,caction: PAXNI PARTICIPATING AREA EXPANDED tleridiu~~.~ l To~ti~nship: 012N R~u~;,~~: (11 1 [_: ti'rciiur~.~ (I=; S~~c~iinn.Icr~~.t.~ 6-~1) ~, ~.~rch ;'~ ~ ats alc~~~i~/r~m: l~ %n~rr~slzr/~: (11~'\ I~un,L~~.~ UI IL Section: 06 .~~~•clr~»r_lc~r~c~~~.~ ~~~ l~~ridrm: l' %~ni~n~thr/~: ~l~'\'~ Ran;~c: U) II Section: 07 ti'c~c~rru~r:!<~r<~~.~ ~~~) :1lrridiu~~.~ ~~ 7nirirship: 012V'~ R~ri~~t~.~ O] 1 F: 5~~~~iron: 08 S'c~cn~»r ~lc~~~~s: G-~O L,e~,al llescrilrtion OS-25-1992 * *SALE NOTICE LEGAL DESCRIPTION*'~` TRACT ?~-110 T. I~N., R. IIE., CMIAT ~IfERIDI,AN, ALASKA SECTIONS, UN.SCRVEYED, AIL, 6;t0 ACRES; ,SECTION 6, UNSURVEYED, ALL, ~ 77 ACRES; SECTION 7, UNSURVEYED, ALL, .580 ACRES; SECTION 8, UNSUR1lEYED, ALG, 6-~0 ACRES'. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=3 8011... 10/16/2008 U TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~t/f~0~-_ .~~f~ PTD# v3 Off- 1.~/ ~Development~ ,_ Service _ Exploratory _ Strati hic Tes ____ Non-Conventional Weq ~p t FIELD: /~/L~Y~ ~o~it/T POOL: L~GNL/• Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) ~~. FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in API number are Permit No. . AP[ No. SO- 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 25.0050, alt c+ecords, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PFD and API number (S~ ---= _) from records, data and logs acquired for well SPACING The permit is approved subject to fiance with ZO AAC EXCEPTION 25.055. Approval to pe and c ii " in' is contingept upon issuance copse anon approving a spacing exception. assumes the liabili of an `-"-' h' y protest to the acing exception that may occ . l~~ ~~. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samptes are first caught and 10' sample intervals i1~rr.....1. M-....a ~____ """-`'"""""`°"$' Please note the following special condition of this permit: Well production or production testing of coal bed mejhane is not allowed for name f weld until after LComnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Comoanv Name} must contact the Commission to obtain advance approval of such water wet! testing nm~mw. R~~: ~n moos WELL PERMIT CHECKLIST Field & Pool_ MILNE POINT, UGNU UNDEFINE OIL - 525160 PTD#:2081610 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Well Name: MILNE PT UNIT UGNU S-41A ___ Program DEV Well bore seg ^ DEV 1 PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ^ Administration 1 Permitfee attached - NA 2 Lease number appropriate- - - _ _ _ - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - _ _ _ Top-prod_interyal and TD in AD_L 380110 _ _ - . - - _ - - .. - _ . - _ - - - _ 3 Unique well name and numbe[ _ _ _ _ _ - _ - - - _ Yes _ _ _ - - - - - ~ 4 Well located in a-deflned_pool. _ _ _ N_o_ _ _ _ _ _ _ MILNE POINT, UGNU UN_DEFINE_OIL-525160. , - _ _ - _ _ _ _ - - - - - - ~' 5 Well located proper distance-from drilling unit_boundary_ - . _ Yes _ - _ Wellbore_is X700'-from-boundary-between MPU and KRU . - 6 Well located proper distance-from other wells- - _ - Yes - SPACING EXCEPTION REQUIRED: Same quarter section as MPU_S_-37, which is currently suspended. 7 Sufficient acreage ayail_able in_drilling unit No_ _ - SPACING EXCEPTION REQUIRED: Productive interval_will lie within same govt quarter section as MPU_5-37_; slo 8 If deviated, is_wellborepfat-included _ - - _ _ _ - - - - - - - - - - - - - Yes _ _ - - _ - _ liner may- also_he within 1000'_of Ugnu. opened-by fvlPU_S-37. - - - _ _ _ _ _ - . - _ _ - - . _ . - _ - - - - - - - - - - - 9 Operator only aff_ecied party- - - - Yes - - - 10 Operator has_appropriate_bond in force - Yes 11 Petmitcanbeissuedwithoutconseruafionorder__------------ ----------- No__ ___--___ --- __-.---_-._----.-_--___------ ------------ --- ------ Appr Date 1 12 Permit_c_anbeissuedwithoutadministraiive_approval------------ --------_-. Yes_ ________.._--_--.__---._---- -------.------ -_-___-.. ' 13 Can permit be approved before 15-day-wait - Yes - - .~Z ~ 14 Well located within area and_strata authorized by_ Injection Order # (put_1O# in_comments)-(For NA- _ NA _ _ _ _ . - _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~b ~ 15 All wells_withtn 1/4 mile area of review identified (For service well only) _ 16 Pre produced infector; duration of pre production less than 3 months_(For service well- only) NA_ 17 Nonconven, gas conforms to AS31,05,030Q.1_.A),Q.2.A-D) - - - - NA- - - - - - ~ 18 Conductor stung-provided - - ---- NA- Conductor set-in MPS-41 (208-159), Engineering X1 19 Surface eosin - rotects altknown_ USDWs - 9p NA_ All aquifers ex_em ted, 40 CFR_147.1 Q2 b)(3). P 20 CMT_voladeguate-tocircul_ate-on conductor-&su_rf_csg---------- - ------ NA-_ ___---Surface casing set in-MPS-41. __ __-.___ __-.-- -_- -.__--_- -----------------. 21 CMT_vofadequate_to be-in long string to surf csg_ - - ------------------ NA_ Single casing well with_casing set into_Ugnu._ 22 CMT_will coyer all know_n_p[oductive horizons- _ . --- No_ Slotted liner com _letion fanned.- p- p 23 Casing designs adequate f_o[ C, T B &-pe[mafr_ost _ NA_ Origin_al well_met design specifications. -NA far slotted liner.~ ~I 24 Adequate tankage_or reserve pit - . Yes Rig. equipped with steel pits, No reserve pit planned.. All waste_to approved disposal well(s). - 25 If_a_re-drill,has_a10-403 for abandonment beenaRRroved_-._ ___- Yes_ __-._308-362------------------- --- - - ------------ ------ --------- 26 Adequate wellbore separation proposed ; - Yes _ Proximity analysis performed, Traveling cylinder path calculated, 27 If_diverter required, does it meet regulations- _ _ _ _ - _ _ _ _ NA_ - _ _ _ _ - - BQP stack_will already_be in place- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid program Schematic & equip list.adequat_e- Yes - - _ Maximum expected f_o[malion pressure 9,0_EMW.- MW planned up t_o 9,3-ppg._ TEM 10!27!2008 29 BOPEs, do they meet regulation _ _ Yes _ _ _ _ _ - - ~30 BOPE-press rating appropriate; test to_(put prig m comments)- . - Yes - MASP calculated at 1305 psi, 3500_psi BOP testplanned, . j31 Choke-manifold complies wlAPl_RP-53 (May 84)_ - _ _ _ _ _ . _ Yes - _ _ _ _ - 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - . -Well will possibly be suspended offer drilling, _ _ _ _ _ _ . _ _ _ _ - - . - - _ _ . - - . - - _ - - - - _ - _ - - - - - 33 Is presence- of H2$ gas- probable _ _ _ NA- _ _ _ _ _ H2S is not reported in Ugnu. -Rig equipped with sensors_and al_arms_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 134 Mechanical condition of wells within AQR verified (Forseruice well only) NA_ _ _ _ _ _ - - --- - _ __ 35 Permit can berssuedwlohydrogen_sulfdemeasureS______-_ ___ 9-- ------- ---- --------- --------- Geology 36 Data_presented on potential overpressure zones- - - - - - - - - - - - - - - - - - -- - .. Yes - - - _ _ - -Maximum expected pressure is 9.0 ppg; will be drilled with-9.0 - 9.3 -ppgoil-base mud. Some intervalsmay-be- - - Appr Date 37 Seismic analysis of shallow gas_zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - - _ _ _ _ untlerpressured. _ _ _ - . - _ _ _ - _ - _ _ - - SFD 10!23/2008 38 Seabed condition survey_(ifoff-shore) - NA- 39 Contact namelphone for weekly_progress reports-[exploratory only] _ - _ _ _ Yes _ _ _ _ - _ _ _ _ _ _ _ - - - - - - - -- - - - - - - - - - _ - Geologic Engineering li SPACING EXCEPTION REQUIRED: due to rig schedule, operator requests permission to drill as scheduled. Well will not be Commissioner: Date: Co missione : Date C toner Date completed or put on production until mid-2009. The application for spacing exception will be submitted shortly. SFD 1012712008 ~~?~~ ~°-Z9-d,8 ~p~L~''4 ~' • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ., ~~ mps-41a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 06 12:17:15 2009 Reel Header Service name .............LISTPE Date . ...................09/02/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................09/02/06 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services scientific Technical services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPS-41A API NUMBER: 500292340101 OPERATOR: BP Exploration Alaska Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 06-FEB-09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 4 JOB NUMBER: Mw0006150038 Mw0006150038 Mw0006150038 LOGGING ENGINEER: A. MUNRO A. MUNRO A. MUNRO OPERATOR WITNESS: J. HABERTHUR J. HABERTHUR J. HABERTHUR MAD RUN 4 JOB NUMBER: Mw0006150038 LOGGING ENGINEER: A. MUNRO OPERATOR WITNESS: J. HABERTHUR SURFACE LOCATION SECTION: 12 TOWNSHIP: 12N RANGE: l0E FNL: FSL: 3224 FEL: 518 FWL: Page 1 ~~-~~ r ~~- ~a~ i ~ mps-41a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 71.53 GROUND LEVEL: 37.79 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4140.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING MPS-41A PB1 AT 5390'MD/3767'TVD. 4. MWD RUNS 1,2,4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), ACOUSTIC CALIPER (ACAL), DRILL STRING DYNAMICS SENSOR (DDS-R),AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 1,4 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (GP). MAD DATA WERE ACQUIRED FROM ABOUT 5395'MD TO ABOUT 4545'MD WHILE POOH AFTER REACHING FINAL TD. THESE DATA ARE PRESENTED SEPARATELY. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO THE SDS MWD GAMMA RAY LOG (DGR) RUN IN MPS-41. THE MPS-41 DGR WAS SHIFTED TO A SCHLUMBERGER OPEN-HOLE GAMMA RAY LOG RUN IN MPS-41 ON 19 NO- VEMBER 2008. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D.DORTCH (SAIC/BP) ON 12 JANUARY 2009, QUOTING AUTHORIZATION FROM ERIC HULM (BP GEOSCIENTIST). THE SHIFTED MPS-41 DGR IS THE PDCL FOR ALL MPS-41A WELLBORES. 6. MWD RUNS 1,2,4 REPRESENT WELL MPS-41A WITH API#: 50-029-23401-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7605'MD/3807'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA Page 2 r ~ mps-41a.tapx SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED HOLE SIZE) . CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). DENSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 8.5" BIT MUD WEIGHT: 9.1 - 9.3 PPG MUD SALINITY: 44,000 PPM CHLORIDES FORMATION WATER SALINITY: 21,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPS PEF RPX DRHO 1 THESE CURVES ARE SMOOTHED FT FOR ALL CURVES. clipped curves; all bit runs merged. .5000 START DEPTH 3905.5 4131.0 4131.0 4131.0 4131.0 4131.0 STOP DEPTH 7601.5 7565.5 7565.5 7528.0 7565.5 7528.0 Page 3 mps-41a.tapx NPHI 4131.0 7514.5 FCNT 4131.0 7514.5 RPM 4131.0 7565.5 RPD 4131.0 7565.5 NCNT 4131.0 7514.5 RHOB 4131.0 7528.0 GALA 4131.0 7517.5 RoP 4142.5 7606.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 3914.5 3918.0 3922.0 3924.0 3935.0 3939.5 3976.0 3978.5 3990.0 3992.0 4049.0 4048.5 4063.0 4064.0 4086.5 4085.5 4099.5 4101.0 4118.0 4117.0 4140.5 4139.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3909.0 4593.0 4593.0 5390.5 5390.5 7605.0 Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 FCNT MWD CP30 4 1 68 8 3 NCNT MWD CP30 4 1 68 12 4 RHOB MWD G/CC 4 1 68 16 5 DRHO MWD G/CC 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD B/E 4 1 68 48 13 Page 4 ~ ~ mps-41a.tapx ROP MWD FPH 4 1 68 52 14 NPHI MWD PU-5 4 1 68 56 15 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3905.5 7606 5755.75 7402 3905.5 7606 CALA MWD IN 7.8 13.87 10.3803 6289 4131 7517.5 FONT MwD CP30 414.89 3295.92 748.451 6767 4131 7514.5 NCNT MWD CP30 91315.7 175253 116302 6768 4131 7514.5 RHOB MwD G/cc 0.715 2.693 2.06063 6795 4131 7528 DRHO MWD G/CC -2.901 0.34 0.0504709 6795 4131 7528 RPD MWD OHMM 3.78 2000 584.911 6870 4131 7565.5 RPM MWD OHMM 3.29 2000 342.274 6870 4131 7565.5 RPS MWD OHMM 3.14 2000 449.678 6870 4131 7565.5 RPX MWD OHMM 2.49 2000 713.603 6869 4131 7565.5 FET MWD HR 0.11 53.43 0.857172 6870 4131 7565.5 GR MWD API 16.7 105.37 46.7245 7393 3905.5 7601.5 PEF MwD B/E 0.26 13.64 1.98521 6795 4131 7528 ROP MWD FPH 2.64 1114.55 190.617 6928 4142.5 7606 NPHI MwD Pu-s 12.16 72.67 41.5881 6768 4131 7514.5 First Reading For Entire File..........3905.5 Last Reading For Entire File...........7606 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Ty e ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FCNT NPHI NCNT CALA and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 4455.0 4455.0 4455.0 4463.0 STOP DEPTH 5303.0 5303.0 5303.0 5285.5 Page 5 PEF DRHO RHOB GR RPM RPS FET RPD RPX RAT MERGED PBU MWD REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 MERGE TOP MERGE BASE 4454.0 7605.0 Name Service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MAD IN 4 1 68 4 2 FCNT MAD CP30 4 1 68 8 3 NCNT MAD CP30 4 1 68 12 4 RHOB MAD G/CC 4 1 68 16 5 DRHO MAD G/CC 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 RPM MAD OHMM 4 1 68 28 8 RPS MAD OHMM 4 1 68 32 9 RPX MAD OHMM 4 1 68 36 10 FET MAD HR 4 1 68 40 11 GR MAD API 4 1 68 44 12 PEF MAD B/E 4 1 68 48 13 RAT MAD FPH 4 1 68 52 14 NPHI MAD PU-S 4 1 68 56 15 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4455 5395.5 4925.25 1882 4455 5395.5 CALA MAD IN 8.7 12.52 9.48776 700 4463 5285.5 FONT MAD CP30 526.5 1260.9 678.971 1697 4455 5303 NCNT MAD CP30 97960.2 134756 110752 1697 4455 5303 RHOB MAD G/CC 1.77 2.712 2.10644 1699 4468 5317 DRHO MAD G/CC -0.054 0.284 0.0336863 1699 4468 5317 RPD MAD OHMM 8.72 1742.15 169.024 1699 4505.5 5354.5 RPM MAD OHMM 6.99 1547.51 125.492 1699 4505.5 5354.5 RPS MAD OHMM 6.51 2000 149.304 1699 4505.5 5354.5 RPX MAD OHMM 6.39 2000 245.803 1699 4505.5 5354.5 Page 6 DATA SOURCE TOOL CODE 4468.0 4468.0 4468.0 4491.5 4505.5 4505.5 4505.5 4505.5 4505.5 4544.0 • mps-41a.tapx 5317.0 5317.0 5317.0 5340.5 5354.5 5354.5 5354.5 5354.5 5354.5 5395.5 MAD RUN N0. MAD PASS NO 4 1 mps-41a.tapx • FET MAD HR 82.2183 113.277 91.317 1699 4505.5 5354.5 GR MAD API 22.72 118.89 57.132 1699 4491.5 5340.5 PEF MAD B/E 1.262 6.003 2.0025 1699 4468 5317 RAT MAD FPH 0.61 594.86 182.944 1704 4544 5395.5 NPHI MAD PU-5 25.84 60.98 44.0044 1697 4455 5303 First Reading For Entire File..........4455 Last Reading For Entire File...........5395.5 File Trailer Service name... .......sTSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE SGRC ACAL SEMP SFXE SNP2 SEXP SEDP SC02 SESP SBD2 CTNA CTFA TNPS SROP LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 3909.0 4130.0 4130.0 4130.0 4130.0 4130.0 4130.0 4130.0 4130.0 4130.0 4130.0 4130.0 4130.0 4141.5 SURFACE SOFTWARE VERSION: STOP DEPTH 4538.5 4494.0 4551.0 4551.0 4515.0 4551.0 4551.0 4515.0 4551.0 4515.0 4501.0 4501.0 4501.0 4593.0 Page 7 08-DEC-08 Insite • DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL~(FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD ACAL mps-41a.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Dens Acoustic Caliper BOREHOLE AND CASING DATA U 74.11 Memory 4593.0 4140.0 4593.0 59.7 67.7 TOOL NUMBER 254724 96540 179954 10603721 728188 OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 54.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.5 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MWDO10 IN 4 1 68 4 2 FONT MWDO10 cP30 4 1 68 8 3 Page 8 mps-4 1a.tapx NCNT MwD010 CP30 4 1 68 12 4 RHOS MwD010 G/cc 4 1 68 16 5 DRHO MWDO10 G/CC 4 1 68 20 6 RPD MwD010 OHMM 4 1 68 24 7 RPM MwD010 OHMM 4 1 68 28 8 RPS MwD010 OHMM 4 1 68 32 9 RPX MWDO10 OHMM 4 1 68 36 10 FET MwD010 HR 4 1 68 40 11 GR MwD010 API 4 1 68 44 12 PEF MwD010 B/E 4 1 68 48 13 RoP MwD010 FPH 4 1 68 52 14 NPHI MWDO10 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3909 4593 4251 1369 3909 4593 GALA MWDO10 IN 8.02 13.12 9.26317 729 4130 4494 FCNT MwD010 CP30 414.89 1050.7 683 742 4130 4501 NCNT MWDO10 CP30 91315.7 127570 110859 743 4130 4501 RHOB MWDO10 G/CC 0.715 2.602 2.10823 771 4130 4515 DRHO MWDO10 G/CC -2.901 0.223 -0.0088249 771 4130 4515 RPD MwD010 OHMM 3.78 1930.87 89.4034 843 4130 4551 RPM MwD010 OHMM 3.29 1419.53 57.3305 843 4130 4551 RPS MWDO10 OHMM 3.14 1293.81 50.2352 843 4130 4551 RPX MWDO10 OHMM 2.49 523.93 35.3915 843 4130 4551 FET MwD010 HR 0.11 6.63 1.81988 843 4130 4551 GR MwD010 API 26.32 105.37 58.4997 1260 3909 4538.5 PEF MWDO10 B/E 1.58 13.64 2.43418 771 4130 4515 ROP MWDO10 FPH 3.06 1114.55 229.593 904 4141.5 4593 NPHI MwD010 PU-5 24.07 72.67 42.9594 743 4130 4501 First Reading For Entire File..........3909 Last Reading For Entire File...........4593 File Trailer service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......sT5LI6.003 Comment Record FILE HEADER FILE NUMBER: 4 Page 9 mps-41a.tapx RAW MWD Curves and log header data for ea ch bit run in separate f iles. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ACAL 4494.5 5390.5 TNPS 4501.5 5390.0 CTFA 4501.5 5390.0 CTNA 4501.5 5390.0 SNP2 4515.5 5390.0 SC02 4515.5 5390.0 SBD2 4515.5 5390.0 SGRC 4539.0 5390.0 SEDP 4551.5 5390.0 SFXE 4551.5 5390.0 SEMP 4551.5 5390.0 SESP 4551.5 5390.0 SEXP 4552.0 5390.0 SROP 4593.5 5390.0 LOG HEADER DATA DATE LOGGED: 09-DEC-O8 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5390.0 TOP LOG INTERVAL (FT): 4593.0 BOTTOM LOG INTERVAL (FT): 5390.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.9 MAXIMUM ANGLE: 91.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA R AY 254724 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Li tho-Dens 10603721 ACAL Acoustic Cal iper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 70.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERAT URE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERM PERATURE: .000 96.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O Page 10 mps-41a.tapx NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Di rection ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. .. ..... Datum Specification Block sub-type ...0 • Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GALA MwD020 IN 4 1 68 4 2 FONT MWD020 cP30 4 1 68 8 3 NCNT MWD020 CP30 4 1 68 12 4 RHOB MWD020 G/CC 4 1 68 16 5 DRHO MWD020 G/CC 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 RPM MWD020 OHMM 4 1 68 28 8 RPS MwD020 OHMM 4 1 68 32 9 RPX MWD020 OHMM 4 1 68 36 10 FET MwD020 HR 4 1 68 40 11 GR MwD020 API 4 1 68 44 12 PEF MwD020 B/E 4 1 68 48 13 ROP MwD020 FPH 4 1 68 52 14 NPHI MWD020 PU-S 4 1 68 56 15 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 4494.5 5390.5 4942.5 1793 4494.5 5390.5 GALA MWD020 IN 7.8 13.87 9.38921 1467 4494.5 5390.5 FONT MWD020 CP30 545.04 1859.07 763.251 1778 4501.5 5390 NCNT MWD020 CP30 99562.9 162258 118133 1778 4501.5 5390 RHOB MwD020 G/CC 1.252 2.691 2.00795 1750 4515.5 5390 DRHO MWD020 G/CC -0.04 0.34 0.116651 1750 4515.5 5390 RPD MwD020 OHMM 12.35 2000 197.715 1678 4551.5 5390 RPM MWD020 OHMM 11.21 1096.23 149.524 1678 4551.5 5390 RPS MWD020 OHMM 11.14 2000 177.843 1678 4551.5 5390 RPX MWD020 OHMM 11.25 2000 292.221 1677 4552 5390 FET MwD020 HR 0.16 17.05 1.42414 1678 4551.5 5390 GR MwD020 API 19.25 93.48 52.1489 1703 4539 5390 PEF MWD020 B/E 0.26 4.6 1.92408 1750 4515.5 5390 ROP MWD020 FPH 2.64 910.64 232.342 1594 4593.5 5390 NPHI MWD020 Pu-S 19.53 58.27 41.2511 1778 4501.5 5390 First Reading For Entire File..........4494.5 Last Reading For Entire File...........5390.5 Page 11 mps-41a.tapx File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 5336.0 7600.5 SEXP 5390.5 7564.5 SFXE 5390.5 7564.5 SC02 5390.5 7527.0 SEMP 5390.5 7564.5 SBD2 5390.5 7527.0 SEDP 5390.5 7564.5 SNP2 5390.5 7527.0 CTNA 5390.5 7513.5 SROP 5390.5 7605.0 CTFA 5390.5 7513.5 TNPS 5390.5 7513.5 SESP 5390.5 7564.5 ACAL 5391.0 7516.5 LOG HEADER DATA DATE LOGGED: 12-DEC-08 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7605.0 TOP LOG INTERVAL (FT): 5390.0 BOTTOM LOG INTERVAL (FT): 7605.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.8 MAXIMUM ANGLE: 91.9 Page 12 mps-41a.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUM BER DGR DUAL GAMMA RAY 254724 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Li tho-Dens 10603721 ACAL Acoustic Cal iper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.25 MUD VISCOSITY (S): 78.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3): 1.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ......... .0 Data Specification Block Type.... .0 Logging Direction ................ .Down Optical log depth units.......... .Feet Data Reference Point ............. .undefined Frame Spacing....... ........... .60 .lIN Max frames per record ............ .Undefined Absent value ..................... .-999 Depth units. .. .. .. .... . Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset Chann el DEPT FT 4 1 68 0 1 CALA MwD040 IN 4 1 68 4 2 FONT MwD040 CP30 4 1 68 8 3 NCNT MwD040 CP30 4 1 68 12 4 RHOB MWD040 G/CC 4 1 68 16 5 DRHO MwD040 G/CC 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 RPM MWD040 OHMM 4 1 68 28 8 RPS MWD040 OHMM 4 1 68 32 9 RPX MWD040 OHMM 4 1 68 36 10 FET MwD040 HR 4 1 68 40 11 GR MwD040 API 4 1 68 44 12 Page 13 • mps-41a.tapx PEF MWD040 B/E 4 1 68 48 13 ROP MwD040 FPH 4 1 68 52 14 NPHI MWD040 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5336 7605 6470.5 4539 5336 7605 GALA MwD040 IN 8.46 12.65 10.9345 4093 5391 7516.5 FONT MWD040 cP30 601.34 3295.92 753.691 4247 5390.5 7513.5 NCNT MWD040 CP30 104704 175253 116487 4247 5390.5 7513.5 RHOB MwD040 G/CC 1.867 2.693 2.07362 4274 5390.5 7527 DRHO MWD040 G/CC -0.032 0.227 0.03407 4274 5390.5 7527 RPD MwD040 OHMM 34.59 2000 830.353 4349 5390.5 7564.5 RPM MwD040 OHMM 28.9 2000 471.877 4349 5390.5 7564.5 RPS MWD040 OHMM 28.52 2000 631.989 4349 5390.5 7564.5 RPX MWD040 OHMM 29.44 2000 1007.55 4349 5390.5 7564.5 FET MwD040 HR 0.12 53.43 0.451807 4349 5390.5 7564.5 GR MwD040 API 16.7 84.75 41.0778 4530 5336 7600.5 PEF MwD040 B/E 0.9 5.15 1.92924 4274 5390.5 7527 ROP MWD040 FPH 3.5 551.96 167.65 4430 5390.5 7605 NPHI MWD040 PU-S 12.16 51.12 41.4893 4247 5390.5 7513.5 First Reading For Entire File..........5336 Last Reading For Entire File...........7605 File Trailer service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......sTSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH CTNA 4454.0 STOP DEPTH 5302.0 Page 14 • mps-41a.tapx CTFA 4454.0 5302.0 TNPS 4454.0 5302.0 ACAL 4462.0 5284.5 SNP2 4467.0 5316.0 SBD2 4467.0 5316.0 SC02 4467.0 5316.0 SGRC 4490.5 5339.5 SEDP 4504.5 5353.5 SFXE 4504.5 5353.5 SEMP 4504.5 5353.5 SEXP 4504.5 5353.5 SESP 4504.5 5353.5 SRAT 4543.0 5394.5 LOG HEADER DATA DATE LOGGED: 12-DEC-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5395.0 TOP LOG INTERVAL (FT): 4545.0 BOTTOM LOG INTERVAL (FT): 5395.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.8 MAXIMUM ANGLE: 91.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 254724 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Litho-Dens 10603721 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.25 MUD VISCOSITY (S): 78.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3): 1.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 15 REMARKS: mps-41a.tapx Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 • Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MAD041 IN 4 1 68 4 2 FONT MAD041 CP30 4 1 68 8 3 NCNT MAD041 CP30 4 1 68 12 4 RHOB MAD041 G/CC 4 1 68 16 5 DRHO MAD041 G/CC 4 1 68 20 6 RPD MAD041 OHMM 4 1 68 24 7 RPM MAD041 OHMM 4 1 68 28 8 RPS MAD041 OHMM 4 1 68 32 9 RPX MAD041 OHMM 4 1 68 36 10 FET MAD041 HR 4 1 68 40 11 GR MAD041 API 4 1 68 44 12 PEF MAD041 B/E 4 1 68 48 13 RAT MAD041 FPH 4 1 68 52 14 NPHI MAD041 Pu-S 4 1 68 56 15 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4454 5394.5 4924.25 1882 4454 5394.5 CALA MAD041 IN 8.7 12.52 9.48776 700 4462 5284.5 FONT MAD041 CP30 526.5 1260.9 678.971 1697 4454 5302 NCNT MAD041 CP30 97960.2 134756 110752 1697 4454 5302 RHOB MAD041 G/CC 1.77 2.712 2.10644 1699 4467 5316 DRHO MAD041 G/CC -0.054 0.284 0.0336863 1699 4467 5316 RPD MAD041 OHMM 8.72 1742.15 169.024 1699 4504.5 5353.5 RPM MAD041 OHMM 6.99 1547.51 125.492 1699 4504.5 5353.5 RPS MAD041 OHMM 6.51 2000 149.304 1699 4504.5 5353.5 RPX MAD041 OHMM 6.39 2000 245.803 1699 4504.5 5353.5 FET MAD041 HR 82.2183 113.277 91.317 1699 4504.5 5353.5 GR MAD041 API 22.72 118.89 57.132 1699 4490.5 5339.5 PEF MAD041 B/E 1.262 6.003 2.0025 1699 4467 5316 RAT MAD041 FPH 0.61 594.86 182.944 1704 4543 5394.5 NPHI MAD041 PU-s 25.84 60.98 44.0044 1697 4454 5302 First Reading For Entire File..........4454 Last Reading For Entire File...........5394 File Trailer Service name... .......sTSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 Page 16 mps-41a.tapx File Ty e ................LO Next Fie Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/02/06 origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date . ...................09/02/06 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File LJ Scientific Technical services scientific Technical services Page 17 mps-4lapbl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Feb 11 11:03:38 2009 Reel Header Service name .............LISTPE Date . ...................09/02/11 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................09/02/11 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 Mw0006150038 A. MUNRO J. HABERTHUR SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FW L ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD r~ ~~ Scientific Technical Services Scientific Technical Services MPS-41A PBl 500292340170 BP Exploration Alaska Inc Sperry Drilling Services 11-FEB-09 MWD RUN 2 MW0006150038 A. MUNRO J. HABERTHUR 12 12N l0E 3224 518 71.53 37.79 Page 1 ~O~s-/Co / l~- loam . i mps-4lapbl.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4140.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A CEMENT PLUG, THE TOP OF WHICH WAS AT THE 9 5/8" CASING SHOE (4140'MD/3477'TVD) IN THE MPS-41 WELLBORE. 4. MWD RUNS 1,2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), ACOUSTIC CALIPER (ACAL), DRILL STRING DYNAMICS SENSOR (DDS-R),AND PRESSURE WHILE DRILLING (PWD). MWD RUN 1 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (G P) . 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO THE SDS MWD GAMMA RAY LOG (DGR) RUN IN MPS-41. THE MPS-41 DGR WAS SHIFTED TO A SCHLUMBERGER OPEN-HOLE GAMMA RAY LOG RUN IN MPS-41 ON 19 NO- VEMBER 2008. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D.DORTCH (SAIC/BP) ON 12 JANUARY 2009, QUOTING AUTHORIZATION FROM ERIC HULM (BP GEOSCIENTIST). THE SHIFTED MPS-41 DGR IS THE PDCL FOR ALL MPS-41A WELLBORES. 6. MWD RUNS 1,2 REPRESENT WELL MPS-41A PBl WITH API#: 50-029-23401-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6055'MD/3790'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. Page 2 mps-4lapbl.tapx TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). DENSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 8.5" BIT MUD WEIGHT: 9.1 - 9.3 PPG MUD SALINITY: 44,000 PPM CHLORIDES FORMATION WATER SALINITY: 21,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3905.5 5991.0 FONT 4130.0 5954.0 PEF 4130.0 5967.5 NCNT 4130.0 5954.0 RPM 4130.0 6005.0 RHOB 4130.0 5967.5 NPHI 4130.0 5954.0 FET 4130.0 6005.0 DRHO 4130.0 5967.5 RPX 4130.0 6005.0 RPD 4130.0 6005.0 RPS 4130.0 6005.0 GALA 4131.0 5957.0 ROP 4142.5 6056.0 Page 3 ~~ mps-4lapbl.tapx BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 3914.5 3918.0 3922.0 3924.0 3935.0 3939.5 3976.0 3978.5 3990.0 3992.0 4049.0 4048.5 4063.0 4064.0 4086.5 4085.5 4099.5 4101.0 4118.0 4117.0 4140.5 4139.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 3909.0 4593.0 MwD 2 4593.0 6055.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .11N Max frames per record .............undefined Absent value ......................-999 Depth units ....................... Datum specification Block sub-type...0 Name service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 FCNT MWD CP30 4 1 68 8 3 NCNT MWD CP30 4 1 68 12 4 RHOB MWD G/CC 4 1 68 16 5 DRHO MWD G/CC 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD B/E 4 1 68 48 13 ROP MWD FPH 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 Name Service Unit Min Max Mean Nsam DEPT FT 3905.5 6056 4980.75 4302 GALA MWD IN 7.8 14.43 9.64006 3130 Page 4 First Reading 3905.5 4131 Last Reading 6056 5957 Y mps-4la pbl.tapx FONT MWD CP30 414.89 1859.07 733.563 3648 4130 5954 NCNT MWD CP30 91315.7 162258 115705 3649 4130 5954 RHOB MWD G/CC 0.715 2.691 1.99451 3676 4130 5967.5 DRHO MWD G/CC -2.901 0.34 0.0772459 3676 4130 5967.5 RPD MWD OHMM 3.78 2000 398.064 3751 4130 6005 RPM MWD OHMM 3.29 1844.86 265.373 3751 4130 6005 RPS MWD OHMM 3.14 2000 359.906 3751 4130 6005 RPX MWD OHMM 2.49 2000 610.578 3750 4130 6005 FET MWD HR 0.11 17.05 1.20218 3751 4130 6005 GR MWD API 18.2 105.37 48.5566 4172 3905.5 5991 PEF MWD B/E 0.26 13.64 1.96104 3676 4130 5967.5 ROP MWD FPH 2.64 1114.55 238.894 3828 4142.5 6056 NPHI MWD PU-5 19.53 72.67 42.1411 3649 4130 5954 First Reading For Entire File..........3905.5 Last Reading For Entire File...........6056 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/11 Maximum Physical Record..65535 File Ty e ................LO Next Fie Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3909.0 4538.5 SESP 4130.0 4551.0 SFXE 4130.0 4551.0 TNPS 4130.0 4501.0 SEXP 4130.0 4551.0 5NP2 4130.0 4515.0 SC02 4130.0 4515.0 ACAL 4130.0 4494.0 SEMP 4130.0 4551.0 CTFA 4130.0 4501.0 SEDP 4130.0 4551.0 CTNA 4130.0 4501.0 Page 5 mps-41apb1.tapx SBD2 4130.0 4515.0 SROP 4141.5 4593.0 LOG HEADER DATA DATE LOGGED: 08-DEC-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4593.0 TOP LOG INTERVAL (FT): 4140.0 BOTTOM LOG INTERVAL (FT): 4593.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.7 MAXIMUM ANGLE: 67.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 254724 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Litho-Dens 10603721 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 54.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): 2•~ RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.5 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ...........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Po~nt ..............undefined Frame spacing ........ ............60 .lIN Max frames per record .............undefined Page 6 mps-4lapbl .tapx Absent va lue .... .......... ........-999 Depth Uni ts. .. . . ...... Datum spe cificat ion Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MWDO10 IN 4 1 68 4 2 FCNT MWDO10 CP30 4 1 68 8 3 NCNT MWDO10 CP30 4 1 68 12 4 RHOB MwD010 G/CC 4 1 68 16 5 DRHO MWDO10 G/CC 4 1 68 20 6 RPD MwD010 OHMM 4 1 68 24 7 RPM MWDO10 OHMM 4 1 68 28 8 RPS MwD010 OHMM 4 1 68 32 9 RPX MWDO10 OHMM 4 1 68 36 10 FET MWDO10 HR 4 1 68 40 11 GR MwD010 API 4 1 68 44 12 PEF MWDO10 B/E 4 1 68 48 13 ROP MWDO10 FPH 4 1 68 52 14 NPHI MWDO10 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3909 4593 4251 1369 3909 4593 GALA MWD010 IN 8.02 13.12 9.26317 729 4130 4494 FCNT MwD010 CP30 414.89 1050.7 683 742 4130 4501 NCNT MWDO10 CP30 91315.7 127570 110859 743 4130 4501 RHOB MwD010 G/cc 0.715 2.602 2.10823 771 4130 4515 DRHO MWDO10 G/CC -2.901 0.223 -0 .0088249 771 4130 4515 RPD MwD010 OHMM 3.78 1930.87 89.4034 843 4130 4551 RPM MwD010 OHMM 3.29 1419.53 57.3305 843 4130 4551 RPS MWDO10 OHMM 3.14 1293.81 50.2352 843 4130 4551 RPX MWDO10 OHMM 2.49 523.93 35.3915 843 4130 4551 FET MwD010 HR 0.11 6.63 1.81988 843 4130 4551 GR MwD010 API 26.32 105.37 58.4997 1260 3909 4538.5 PEF MwD010 B/E 1.58 13.64 2.43418 771 4130 4515 ROP MWDO10 FPH 3.06 1114.55 229.593 904 4141.5 4593 NPHI MwD010 PU-S 24.07 72.67 42.9594 743 4130 4501 First Reading For Entire File..........3909 Last Reading For Entire File...........4593 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number...........1.0.0 Page 7 • mps-4lapbl.tapx Date of Generation.......09/02/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ACAL 4494.5 5956.0 CTNA 4501.5 5953.0 CTFA 4501.5 5953.0 TNPS 4501.5 5953.0 SBD2 4515.5 5966.5 SC02 4515.5 5966.5 SNP2 4515.5 5966.5 SGRC 4539.0 5990.0 SESP 4551.5 6004.0 SEDP 4551.5 6004.0 SFXE 4551.5 6004.0 SEMP 4551.5 6004.0 SEXP 4552.0 6004.0 SROP 4593.5 6055.0 LOG HEADER DATA DATE LOGGED: 09-DEC-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6055.0 TOP LOG INTERVAL (FT): 4593.0 BOTTOM LOG INTERVAL (FT): 6055.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.9 MAXIMUM ANGLE: 91.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 254724 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Litho-Dens 10603721 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 70.0 MUD PH: 9.0 Page 8 • RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: mps-4lapbl.tapx MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 .000 .0 .000 96.0 .000 .0 .000 .0 Name Service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GALA MWD020 IN 4 1 68 4 2 FONT MWD020 CP30 4 1 68 8 3 NCNT MWD020 CP30 4 1 68 12 4 RHOB MWD020 G/CC 4 1 68 16 5 DRHO MWD020 G/CC 4 1 68 20 6 RPD MwD020 OHMM 4 1 68 24 7 RPM MWD020 OHMM 4 1 68 28 8 RPS MwD020 oHMM 4 1 68 32 9 RPX MWD020 OHMM 4 1 68 36 10 FET MWD020 HR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 PEF MwD020 B/E 4 1 68 48 13 ROP MwD020 FPH 4 1 68 52 14 NPHI MWD020 PU-S 4 1 68 56 15 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4494.5 6055 5274.75 3122 4494.5 6055 CALA MWD020 IN 7.8 14.43 9.7545 2401 4494.5 5956 FCNT MWD020 CP30 545.04 1859.07 746.562 2904 4501.5 5953 NCNT MWD020 CP30 99562.9 162258 116949 2904 4501.5 5953 RHOB MWD020 G/CC 1.199 2.691 1.96487 2903 4515.5 5966.5 DRHO MWD020 G/CC -0.057 0.34 0.101305 2903 4515.5 5966.5 RPD MWD020 OHMM 12.35 2000 486.592 2906 4551.5 6004 RPM MwD020 OHMM 11.21 1844.86 325.213 2906 4551.5 6004 RPS MWD020 OHMM 11.14 2000 449.717 2906 4551.5 6004 RPX MWD020 OHMM 11.25 2000 777.87 2905 4552 6004 FET MwD020 HR 0.16 17.05 1.0196 2906 4551.5 6004 Page 9 mps-4lapbl.tapx GR MWD020 API 18.2 93.48 44.228 2903 4539 5990 PEF MwD020 B/E 0.26 4.6 1.8293 2903 4515.5 5966.5 ROP MWD020 FPH 2.64 977.43 241.769 2924 4593.5 6055 NPHI MwD020 Pu-s 19.53 58.27 41.9266 2904 4501.5 5953 First Reading For Entire File..........4494.5 Last Reading For Entire File...........6055 File Trailer service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EoF Tape Trailer Service name .............LISTPE Date . ...................09/02/11 origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library Reel Trailer Service name .............LISTPE Date . ...................09/02/11 Ori gin ...................5T5 Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical services scientific Technical Services Page 10 mps-41apb2.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 06 13:31:24 2009 Reel Header Service name .............LISTPE Date . ...................09/02/06 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................09/02/06 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: scientific Technical Services Scientific Technical Services MPS-41A PB2 500292340171 BP Exploration Alaska Inc Sperry Drilling Services 06-FEB-09 MWD RUN 2 MWD RUN 3 Mw0006150038 Mw0006150038 A. MUNRO A. MUNRO J. HABERTHUR J. HABERTHUR MWD RUN 1 Mw0006150038 A. MUNRO J. HABERTHUR SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD i~C~~~ 12 12N 10E 3224 518 71.53 37.79 Page 1 ~v~s-~~ ~ ` • mps-41apb2.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4140.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING MPS-41A PBl AT 5515'MD/3761'TVD. 4. MWD RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), ACOUSTIC CALIPER (ACAL), DRILL STRING DYNAMICS SENSOR (DDS-R),AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 1,3 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (GP). 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO THE SDS MWD GAMMA RAY LOG (DGR) RUN IN MPS-41. THE MPS-41 DGR WAS SHIFTED TO A SCHLUMBERGER OPEN-HOLE GAMMA RAY LOG RUN IN MPS-41 ON 19 NO- VEMBER 2008. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D.DORTCH (SAIC/BP) ON 12 JANUARY 2009, QUOTING AUTHORIZATION FROM ERIC HOLM (BP GEOSCIENTIST). THE SHIFTED MPS-41 DGR IS THE PDCL FOR ALL MPS-41A WELLBORES. 6. MWD RUNS 1-3 REPRESENT WELL MPS-41A PB2 WITH API#: 50-029-23401-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6147'MD/3775'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED HOLE Page 2 ~ ~ mps-41apb2.tapx SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). DENSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 8.5" BIT MUD WEIGHT: 9.1 - 9.3 PPG MUD SALINITY: 44,000 PPM CHLORIDES FORMATION WATER SALINITY: 21,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3905.5 6140.5 CALA 4131.0 6057.5 FCNT 4131.0 6056.0 NCNT 4131.0 6056.0 PEF 4131.0 6070.5 RHOB 4131.0 6070.5 RPM 4131.0 6108.0 RPD 4131.0 6108.0 FET 4131.0 6108.0 NPHI 4131.0 6056.0 RPX 4131.0 6108.0 RPS 4131.0 6108.0 DRHO 4131.0 6070.5 ROP 4142.5 6148.0 Page 3 mps-41apb2.tapx BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED BASELINE DEPTH GR 3914.5 3918.0 3922.0 3924.0 3935.0 3939.5 3976.0 3978.5 3990.0 3992.0 4049.0 4048.5 4063.0 4064.0 4086.5 4085.5 4099.5 4101.0 4118.0 4117.0 4140.5 4139.5 MERGED DATA SOURCE DEPTH --------- PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 3909.0 4593.0 MWD 2 4593.0 5515.0 MWD 3 5515.5 6147.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 FCNT MWD CP30 4 1 68 8 3 NCNT MWD CP30 4 1 68 12 4 RHOB MWD G/CC 4 1 68 16 5 DRHO MWD G/CC 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD B/E 4 1 68 48 13 ROP MWD FPH 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 3905.5 6148 5026.75 4486 3905.5 CALA MWD IN 7.8 13.91 9.77631 3085 4131 FONT MWD cP30 414.89 1859.07 735.853 3850 4131 Page 4 Last Reading 6148 6057.5 6056 mps-41a pb2.tapx NCNT MWD CP30 91315.7 162258 115679 3851 4131 6056 RHOB MwD G/CC 0.715 2.691 2.02863 3880 4131 6070.5 DRHO MWD G/CC -2.901 0.34 0.0651959 3880 4131 6070.5 RPD MWD OHMM 3.78 2000 477.111 3955 4131 6108 RPM MWD OHMM 3.29 2000 295.134 3955 4131 6108 RPS MWD OHMM 3.14 2000 440.936 3955 4131 6108 RPX MWD OHMM 2.49 2000 599.742 3955 4131 6108 FET MWD HR 0.09 26.66 1.76568 3955 4131 6108 GR MWD API 18.2 105.37 47.58 4471 3905.5 6140.5 PEF MwD B/E 0.26 13.64 1.99066 3880 4131 6070.5 ROP MWD FPH 0.42 1114.55 259.005 3999 4142.5 6148 NPHI MwD PU-5 19.53 72.67 41.8672 3851 4131 6056 First Reading For Entire File..........3905.5 Last Reading For Entire File...........6148 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Ty e ................LO Next F~~e Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......5T5LI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3909.0 4538.5 SNP2 4130.0 4515.0 TNPS 4130.0 4501.0 SFXE 4130.0 4551.0 SCO2 4130.0 4515.0 CTFA 4130.0 4501.0 5E5P 4130.0 4551.0 ACAL 4130.0 4494.0 SEMP 4130.0 4551.0 CTNA 4130.0 4501.0 SEDP 4130.0 4551.0 SEXP 4130.0 4551.0 SBD2 4130.0 4515.0 Page 5 i • mps-41apb2.tapx SROP 4141.5 4593.0 LOG HEADER DATA DATE LOGGED: 08-DEC-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4593.0 TOP LOG INTERVAL (FT): 4140.0 BOTTOM LOG INTERVAL (FT): 4593.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.7 MAXIMUM ANGLE: 67.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 254724 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Litho-Dens 10603721 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 54.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.5 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 6 mps-41a pb2.tapx Depth Uni ts .... .......... ........ Datum Spe cificat ion Block sub-type...0 Name Service Order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWDO10 IN 4 1 68 4 2 FONT MwD010 cP30 4 1 68 8 3 NCNT MwD010 CP30 4 1 68 12 4 RHOB MWDO10 G/CC 4 1 68 16 5 DRHO MWDO10 G/CC 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 RPM MwD010 OHMM 4 1 68 28 8 RPS MwD010 oHMM 4 1 68 32 9 RPX MWDO10 OHMM 4 1 68 36 10 FET MWDO10 HR 4 1 68 40 11 GR MWDO10 API 4 1 68 44 12 PEF MwD010 B/E 4 1 68 48 13 ROP MWDO10 FPH 4 1 68 52 14 NPHI MWD010 Pu-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3909 4593 4251 1369 3909 4593 GALA MwD010 IN 8.02 13.12 9.26317 729 4130 4494 FONT MwD010 CP30 414.89 1050.7 683 742 4130 4501 NCNT MWDO10 CP30 91315.7 127570 110859 743 4130 4501 RHOB MWDO10 G/CC 0.715 2.602 2.10823 771 4130 4515 DRHO MWDO10 G/CC -2.901 0.223 -0.0088249 771 4130 4515 RPD MwD010 OHMM 3.78 1930.87 89.4034 843 4130 4551 RPM MwD010 OHMM 3.29 1419.53 57.3305 843 4130 4551 RPS MWDO10 OHMM 3.14 1293.81 50.2352 843 4130 4551 RPX MWDO10 OHMM 2.49 523.93 35.3915 843 4130 4551 FET MwD010 HR 0.11 6.63 1.81988 843 4130 4551 GR MwD010 API 26.32 105.37 58.4997 1260 3909 4538.5 PEF MwD010 B/E 1.58 13.64 2.43418 771 4130 4515 ROP MWDO10 FPH 3.06 1114.55 229.593 904 4141.5 4593 NPHI MWDO10 PU-S 24.07 72.67 42.9594 743 4130 4501 First Reading For Entire File..........3909 Last Reading For Entire File...........4593 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EoF File Header Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Page 7 • • mps-41apb2.tapx Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL2B.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH ACAL 4494.5 CTNA 4501.5 CTFA 4501.5 TNPS 4501.5 SNP2 4515.5 SBD2 4515.5 SCO2 4515.5 SGRC 4539.0 SFXE 4551.5 SESP 4551.5 SEMP 4551.5 SEDP 4551.5 SEXP 4551.5 SROP 4593.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD ACAL 3 STOP DEPTH 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 5515.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Dens Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): header data for each bit run in separate files. 2 .5000 09-DEC-08 Insite 74.11 Memory 5515.0 4593.0 5515.0 69.9 91.9 TOOL NUMBER 254724 96540 179954 10603721 728188 8.500 4140.0 Mineral oil Base 9.20 70.0 9.0 44000 Page 8 • mps-41apb2.tapx FLUID LOSS (C3): .O RESIST IVITY (oHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRC ULATING TERMPERATURE: .000 96.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Di rection .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MWD020 IN 4 1 68 4 2 FONT MWD020 CP30 4 1 68 8 3 NCNT MwD020 cP30 4 1 68 12 4 RHOB MwD020 G/CC 4 1 68 16 5 DRHO MwD020 G/CC 4 1 68 20 6 RPD MwD020 OHMM 4 1 68 24 7 RPM MwD020 OHMM 4 1 68 28 8 RPS MwD020 OHMM 4 1 68 32 9 RPX MWD020 OHMM 4 1 68 36 10 FET MwD020 HR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 PEF MwD020 B/E 4 1 68 48 13 RoP MwD020 FPH 4 1 68 52 14 NPHI MWD020 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4494.5 5515 5004.75 2042 4494.5 5515 CALA MwD020 IN 7.8 13.87 9.53013 1699 4494.5 5515 FONT MwD020 cP30 545.04 18 59.07 757.651 2028 4501.5 5515 NCNT MwD020 cP30 99562.9 1 62258 117583 2028 4501.5 5515 RHOB MWD020 G/CC 1.247 2.691 1.99805 2000 4515.5 5515 DRHO MWD020 G/CC -0.045 0.34 0.112396 2000 4515.5 5515 RPD MWD020 OHMM 12.35 2000 319.282 1928 4551.5 5515 RPM MWD020 OHMM 11.21 18 44.86 228.772 1928 4551.5 5515 RPS MWD020 OHMM 11.14 2000 325.062 1928 4551.5 5515 RPX MWD020 OHMM 11.25 2000 513.285 1928 4551.5 5515 FET MwD020 HR 0.16 17.04 1.28824 1928 4551.5 5515 GR MWD020 API 18.2 93.48 49.1798 1953 4539 5515 Page 9 • • mps-41apb2.tapx PEF MWD020 B/E 0.26 4.6 1.89699 2000 4515.5 5515 ROP MWD020 FPH 2.64 910.64 259.09 1844 4593.5 5515 NPHI MWD020 PU-S 19.53 58.27 41.4172 2028 4501.5 5515 First Reading For Entire File..........4494.5 Last Reading For Entire File...........5515 File Trailer Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE SGRC SEMP SBD2 SEDP SCO2 SFXE SNP2 CT FA SESP TNPS ACAL SEXP CTNA SROP START DEPTH 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5515.5 5522.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): header data for each bit run in separate files. 3 .5000 STOP DEPTH 6139.5 6107.0 6069.5 6107.0 6069.5 6107.0 6069.5 6055.0 6107.0 6055.0 6056.5 6107.0 6055.0 6147.0 10-DEC-08 Insite 74.11 Memory Page 10 TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD ACAL mps-41apb2.tapx 6147.0 5515.0 6147.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Dens Acoustic Caliper 86.9 90.8 TOOL NUMBER 254724 96540 179954 10603721 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 71.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 49000 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATU RE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMP ERATURE: .000 100.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Loging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MWD030 IN 4 1 68 4 2 FONT MWD030 CP30 4 1 68 8 3 NCNT MwD030 CP30 4 1 68 12 4 RHOB MwD030 G/CC 4 1 68 16 5 Page 11 i i mps-41apb2.tapx DRHO MWD030 G/CC 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 RPM MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MwD030 HR 4 1 68 40 11 GR MWD030 API 4 1 68 44 12 PEF MWD030 B/E 4 1 68 48 13 RoP MWD030 FPH 4 1 68 52 14 NPHI MWD030 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5515.5 6147 5831.25 1264 5515.5 6147 GALA MWD030 IN 8.77 13.91 10.9823 657 5515.5 6056.5 FONT MWD030 cP30 550.65 1322.59 731.236 1080 5515.5 6055 NCNT MWD030 cP30 101354 139922 115420 1080 5515.5 6055 RHOB MwD030 G/CC 1.649 2.373 2.02842 1109 5515.5 6069.5 DRHO MWD030 G/CC -0.019 0.204 0.0315347 1109 5515.5 6069.5 RPD MwD030 OHMM 182.31 2000 1010.16 1184 5515.5 6107 RPM MwD030 OHMM 150.15 2000 572.511 1184 5515.5 6107 RPS MWD030 OHMM 162.59 2000 907.8 1184 5515.5 6107 RPX MWD030 OHMM 198.96 2000 1142.34 1184 5515.5 6107 FET MwD030 HR 0.09 26.66 2.50454 1184 5515.5 6107 GR MWD030 API 20 53.65 34.0254 1249 5515.5 6139.5 PEF MwD030 B/E 1.24 3.48 1.85124 1109 5515.5 6069.5 ROP MWD030 FPH 0.42 707.25 280.134 1251 5522 6147 NPHI MWD030 PU-S 25.55 54.44 41.9609 1080 5515.5 6055 First Reading For Entire File..........5515.5 Last Reading For Entire File...........6147 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EoF Tape Trailer Service name .............LISTPE Date . ...................09/02/06 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................09/02/06 Origin ...................STs scientific Technical services Page 12 mps-41apb2.tapx Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 13