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Home My WebLink About197-1501 ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ~~~~~~ a ~ ~2~~ + ~ ~ DATE: October 23, 2007 P. I. Supervisor ~ ~ ~:"~ NOV a 6 2D01 FROM: Chuck Scheve, SUBJECT: Surface Abandonment Petroleum Inspector MPU H-14 PTD# 197-150 Tuesday, October 23,2007: I traveled to BPXs MPU H Pad to inspect the casing cut off and abandonment of well H-14. All casing strings were cut off at approximately 4' below original ground level. Cement was found 3' down in the 9 518 casing. This void was filled with cement and a 3/4" thick marker plate was then welded to the conductor casing with the required information bead welded to it. SUMMARY: I inspected the casing cut off depth, and the P&A marker plate on the MPU H-14 well and found all to be in order. Attachments: MPU H-14 marker plate.JPG MPU H-14 cut off.JPG ~APII H-14 Surface Aband®nmet~t Gctober 23, 2007 Photos by AOGCC inspector Chuck Scheve Casing Cut-off 1Vtarker Plate ~: ~~ ~~, ~~ ;., _~ Ir' ~. ~~M, ~~~! rani' I~ IIx!~ ~~,~; ~, „ ~~; unM~~ ~~' ,. ~i _, +~ ~.. -._ iu~d~ . . rea ', ,~ ~ ~. ~~~ ~ ~ ~ ~ ~ ` ~, ,~ ~~ ,~~ .. rte, uIV ~.._ i.a.i ry '~~~ "N ~G'~~itlY~' . . ..uxr .~ `~F~ i ~ ~ ~ r~~^~~ ~:~ 4 ~~ 06/15/07 Schlumberger NO. 4304 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth /01-- /SO r.'-'NEÐ JUN· 2 0 2007 SCI'U1! Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII J b# L D D BL CI CD . e 0 09 escrlptlon ate o or P1-16 11637331 WARMBACKS & SBHPS 05/04/07 1 P1-14 11637332 WARMBACKS & SBHPS 05/05/07 1 01-05 11626486 USIT (CEMENT) 05/13/07 1 01-05 11626486 US IT (CORROSION) 05/13/07 1 MPH-14 11638633 INCLINOMETER-DIRECTION LOG 05/13/07 1 MPS-01A 1159454 MDT OS/28/07 1 11-18 11626097 US IT OS/26/07 1 09-15A 11629015 SCMT 06/01/07 1 12-12A 11695061 CEMENT IMAGE & BOND LOG OS/28/07 1 03-36A 11629014 SCMT 05/31/07 1 S-401 11626492 SCMT 06/11/07 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth // Date Delivered: " It ! r".!\.,.. \ 2 0 Z007 Received by: ~~." ,",.d" 8.. Commi55!O!1i ____ _ __ STATE OF ALASKA ~>? ~'E,C,.,EIVED ALASKA OIL AND GAS CONSERVATION COMMISSION ~~aJUN 1 4 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska (ll & Gas Cons. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions ero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., o band s/ -+D~ 12. Permit to Drill Number 197-150 ' 307-093 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~, 08/15/1997 13. API Number 50-029-22796-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 08/18/1997 14. Well Name and Number: MPH-14 ' 2949 FSL, 4133 FEL, SEC. 34, T13N, R10E, UM Top of Productive Horizon: N/A 8. KB (ft above MSL): 65.70 - Ground (ft MSL): 36.6 15. Field /Pool(s): Milne Point Unit / Schrader Bluff Total Depth: 2853' FSL, 713' FEL, SEC. 34, T13N, R10E, UM 9. Plug Back Depth (MD+TVD) Surface Surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 556511 y- 6010100 Zone- ASP4 10. Total Depth (MD+TVD) 6025 4396 ~ 16. Property Designation: ADL 025906 - TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 559932 y- 6010030 Zone- ASP4 11. SSSV DeN A(MD+TVD) 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD , EMSS, GR/CCL, GRlJB 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MO SETTING DEPTH. ND HOLE AMOUNT WTrPER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# H-40 33' 112' 33' 112' 24" 250 sx Arctic Set A rox. 9-5/8" 40# L-80 32' 6007' 32' 4381' 12-1 /4" 1670 sx PF 'E', 855 sx 'G', 50 sx PF 'C' 23. Open to production or inject ion? ^ Yes ®No 24, . TU91NG RECORD If Yes, IISt each I (MD+TVD of Top & Bottom; Pe nterval Open rforation Slze and Number): SIZE DEPTH SET MD PACKER SET MD None None MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~) ~j(') ~~~~ ~~ Y ~ ~ ~{Jil~ DEPTH INTERVAL MD AMOUNT Ha KIND OF MATERIAL USED 240' - 325' Attempted Cement Squeeze 43 Bbls AS1 1434' Set 1st Plug with 55 Bbls AS1 703' Set 2nd Plug with 55 Bbls AS1 58' Set 3rd Plug with 67 Bbls AS1 26. ~--u••~••-~• 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 PreSS. 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 wired? ^ 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 er 0.071. None S B~~ JUN ~ 2 2009 ><t Form 10-407 Revised 02/2007 CQNTINUED ON REVERSE SIDE ~>~~~~~~~1 V 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. TSBF 5498' 3948' None SBF 1 5528' 3974' TSBD 5681' 4105' Will resubmitt 10-407 with Well work Summary and TSBB 5753' 4166' Abandoment Photos once completed. Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr etyma Title Technical Assistant Date `~ ~j° ~} MPH-14 197-150 307-093 Prepared ey Name/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Bryan McLellan, 564-5516 INSTRUCTIONS GeNeRAL: This fonn 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. IreM 4b: TPI (Top of Producing Interval). IreM 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). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional intervaV 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). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ' Tree: Cameron 2 9/16", 5M MPU H-14 PB1 Orig. KB Elev. = 65.7 ' (N 22E) Wellhead: FMC 11" x 11" 5M, Orig. GL Elev. = 36.6' Gen 5 Top of Cement 20` BGL RT To Tbg. Spool = (N 22E) DAMAGED CSG 130' & 252` 20" 91.1 ppf, H-40 112' KOP @ 300' to 3,400' Sidetracked from 9-5/8" Csg 257 Max. hole angle = 66 deg. Hole angle thru' perfs = 30 deg. 15.7 ppg Class G cement 242` - 325' Remnants of EZSV 345' 15.7 ppg AS1 Abandonment 20`-2035' Howco 9 5/8" "ES" Cementer 2270' Cement Plug Casing Leak at ES Cementer Inadvertant sidetrack TD 2038` 9.5 ppg brine 9 5/8" 40 ppf, L-80, BTC production csg. ( ID = 8.835", cap. = 0.0758 bpf ) ' XXXXX Top of Fill 5408 X X X X X Top of Sand 5458' Stimulation Summary 07/31/98 N M# of CL coated with PL Baker 4-1/2" KB Pkr w/ 2-3/8" creens 5520' Exclud r 2000 sand placed behind screens e s 07/29/98 OA 98 M# of PropLok coated set inside 4-1/2" screens. 9-5/8" HES `BWD' perm. Pkr. 5506' 16/20 CarboLite behind pipe w/ JP plug set in seal bore 07/27/98 OB76.8M# of PropLok coated 16/20 CL behind i e - re-frac 4-1 /2" 125 Micron Poroplus 5527' p p screens assembly (61' long; 07/26/98 OB 18.4M# of PropLok coated ' 16/20 CL behind pipe -early shutdowr 9-5/8" HES 'BWD' sump pkr. 5589 Perforation Summary 4-1 /2" XN nipple 3.725" ID 5595' Ref to :S er MWD 8/18/97 w/ lower seals of 2-3/8" sand t i n. screens s ung Size SPF Interval (TVD) ' ** TD fagged during RWO 11-6/05 @ 5782 MD ** 4.5" 4 5530'-5570' 3976'-4010' 7" 4 5686'-5712' ' ' 4110'-4132' ' ' g 5/8' landing collar (PBTD) 5,919' 7" 4 -5780 5760 4171 -4190 9 5/g' float collar 5,963' 9 5/8' float shoe 6,007' DATE EV. BY COMMENTS OI UN 831-97 MDO 9-5/8" Cased Hole Completion 22E MILNE P NT IT 8/04/98 M. Linder Initial com letion 4-ES WELL No : H-14PB1 3ti1g8//D919 B MDO be ESP oompletaone~ Escompletion 4 ES qpl ; 50-029-2279670 12/5/03 Lee Hulme ESP changeout 4ES 6114107 McLeuan P&A Doyon 14 BP EXPLORATION (AK) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 5(8!2007 ~ 00:00 - 03:30 03:30 - 12:00 12:00 - 17:00 17:00 - 18:00 18:00 - 19:30 19:30 - 20:30 20:30 - 21:00 21:00 - 00:00 5/9/2007 00:00 - 01:00 01:00 - 01:30 MPH-14 MPH-14 PLUG+ABANDON DOYON DRILLING jNC. DOYON 14 Start: 5/8/2007 Rig Release: 5!8!2007 Rig Number: #14 Hours~Task ~~ Code NPT I Phase - -- 3.50 MOB P DECOMP 8.50 MOB P DECOMP 5.001 MOB I P I I DECOMP 1.00 WHSUR P DECOMP 1.50 WHSUR P DECOMP 1.001 WHSUR I P I I DECOMP 3.00 BOPSUgP DECOMP 1.00 BOPSUF{P DECOMP 0.50 BOPSU~j P DECOMP 01:30 - 05:00 3.50 BOPSU P DECOMP 05:00 - 05:30 0.50 BOPSU P DECOMP 05:30 - 07:30 2.00 PULL DECOMP 07:30 - 09:00 1.50 PULL P DECOMP 09:00 - 09:30 0.50 PULL P DECOMP 09:30 - 10:00 0.50 PXA P DECOMP 10:00 - 15:30 5.50 PXA P DECOMP 15:30 - 16:00 0.50 PXA P DECOMP 16:00 - 17:00 1.00 PXA P DECOMP 17:00 - 20:00 3.00 PXA P DECOMP 20:00 - 23:30 I 3.501 PXA I P I I DECOMP Page 1 of 5 Spud Date: 8/15/1997 End: Description of Operations PJSM -Blow down rig -Disconnect all lines -Skid rig floor from drlg position to move position -PJSM -Pull rig off MPF-99i - Move rig from MPF Pad to MPH Pad -Spot rig over MPH-14 - Shim rig -Skid rig floor from move position to drlg position -Rig up floor -Spot / Berm rock washer (Accept rig @ 12:00 hrs) -Spot 110% tiger tank -Shovel snow from cellar - RU lines from annulus to choke on tiger tank - RU lines from pump to tubing -Test lines with air checking for leaks -Annulus and tubing pressure 0 -Fill pits with 120 degree seawater -Load pipe shed with 4" DP RU Lubricator -Pull BPV PJSM -Circulate out freeze protection diesel -Pump 25 bbls seawater down tubing taking returns to bleed tank -Let diesel migrate -Pump 25 bbls seawater - 145 gpm @ 240 psi -Flow check -Well static Install TWC with FMC rep - RU lines test equipment -Test from below to 1000 psi - 10 mins -From top 3500 psi 10 mins - Record on chart - RD test equipment /lines ND FMC Tree Install 3' spool - NU BOP's -Riser -Flow line -Choke line - (Take out 1' extension and install 2' extension spool) - MU Test Con't NU BOP's PJSM - RU test equipment - MU XO to test joint -Screw into hanger Test BOP's -Annular 250 low 3500 high - 5 Mins each test - Top VBR's 2 7/8 X 5" -Choke manifold - HCR choke /Kill - Manual Choke /Kill -Upper /Lower !BOP -Floor Safety valves - Lower VBR's 3 1/2" X 6" 250 low 3500 high 5 mins each test - Perform Accumulator test -Test Blinds 250 low 3500 high 5 mins each test -All test witnessed by WSL -Bob Noble with AOGCC wavied witness of BOP test - RD testing equipment -Close annulus valve -Blow down Choke manifold -Choke /Kill lines -Top Drive Moblize BHA to rig floor -Calibrate and test gas alarms - RU lubricator -Add 6" extension to lubricator -Pull TWC - RD Lubricator -Load out same BOLDS -Pull hanger to rig floor - LD same - LD 2 joints 2 7/8" tubing Install wear ring PJSM - PU 4" DP 1 X 1 -Stand back in derrick Clear rig floor -Change out handling equipment PJSM - MU BHA PJSM - RU -Test lines to tiger tank to 500 psi -Circulate through choke -Tag CIBP @ 105' -Close Annular Drill top of CIBP -GPM 275 - PP 620 - WOM 1 to 5 -Taking returns through choke manifold to tiger tank -Drilled 6" -Weight and pressure dropped off -Shut in well -Check for pressure build up - No pressure -Injected 3 bbls ~ 2 bpm - PP 120 psi - Checked for flow and pressure build up - No Flow No pressure build up -Open Annular (1 hour 45 mins to mill top of CIBP to equalize well) Con't mill up CIBP -Taking returns into pits -GPM 300 - PP Printed: 5/21/2007 9:08:16 AM BP EXPLORATION Page 2 of 5 ' Operations Summary Report Legal Well Name: MPH-14 Common Well Name: MPH-14 Event Name: PLUG+ABANDON Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task~Code NPT 5/9/2007 ~ 20:00 - 23:30 ~ 3.50 ~ PXA ~ P 23:30 - 00:00 0.50 PXA P 5/10/2007 00:00 - 01:00 1.00 PXA P 01:00 - 02:00 ~ 1.00 ~ PXA I P 02:00 - 09:00 I 7.00 I PXA I P 09:00 - 09:30 I 0.501 PXA I P 09:30 - 10:30 I 1.00 I PXA I P 10:30 - 11:30 I 1.00 I PXA I P 11:30 - 12:30 I 1.00 I PXA I P 12:30 - 14:30 2.00 PXA I P 14:30 - 16:00 1.50 PXA P 16:00 - 17:00 I 1.001 PXA I P 17:00 - 18:00 1.00 PXA P 18:00 - 00:00 6.00 PXA P 15/11/2007 00:00 - 00:30 0.50 PXA P 00:30 - 01:00 0.50 PXA P 01:00 - 01:30 0.50 PXA P 01:30 - 02:00 0.50 PXA P 02:00 - 02:30 I 0.50 I PXA I P 02:30 - 06:00 ~ 3.50 ~ PXA ~ P Spud Date: 8/15/1997 Start: 5/8/2007 End: Rig Release: 5/8/2007 .Rig Number: #14 Phase Description of Operations DECOMP 260 -RPM 70 - TQ 0 to 1K - WOM 1 to 5K -Push CIBP From 106' to 345' -CBU 6 X -Massive amount fine sand with gravel size cement over shakers -Well did not clean up -Pump out from 345 to 252' -Attempt to pull w/o pump - Overpull 20K - Break circulation pump out to 220' - POH from 220' with out pump - DECOMP LD BHA DECOMP Blow down kill line -Choke line - Moblize BHA to rig floor and pipe shed DECOMP PJSM - MU BHA -Mill -Bit sub - 3 Flex Dc's -Bumper sub -Oil jars-35"HWDP-XO DECOMP Visc up seawater to 80 vis -Screen up shakers -Load fresh water in pit #4 -Mix 100 bbls of 210 visc. spud mud -Observe well DECOMP RIH -Tag fill at 245' -Circulate 210 visc mud around -Wash & ream f/ 245' - 290' w/ 50 rpm 7 bpm 200 psi DECOMP Pulled up to 240' -Shut down -Clean gravel from troughs and flowline -Build volume DECOMP RIH -Tag fill at 290' w/ no pump -Pull up to 240' -Break circ. w/ 5 bpm -wash down -Tag casing stub at 252' -rotate 2 turns to get in casing -Continue wash down to 305' - Circ. to clean hole -Massive gravel returns -Make connection and continue to wash and ream to 325' (20' above last CIBP depth). DECOMP Circulate hole clean -Spot LCM pill across hole in casing - Stop pumps -Tag fill at 328' -Pull up to 211' DECOMP Wait on hole to heal -RIH tag with 5K Ca2 325' - POH DECOMP Stand back HWDP- DC's -Break mill - MU Mule shoe -RIH Tag up at 315' -Wash down to 320' -CBU - 4 bpm C~ 80 psi DECOMP PJSM -Give to Dowell Pump 2 bbls fresh water Test lines to 2500 psi Pump 43 bbls 15.7 ppg AS1 cement with 2 Ib/bbl cemnet -sxs 251 -yield .96 Pump 2 bbls fresh water DECOMP POH to 100' -Circulate cement out -Close Annular -Attempt to squeeze cement - 2 bpm 80 psi -pumped 3 bbls DECOMP WOC to arrive DECOMP MU Mule shoe -RIH Tagged up 5K @ 174 -Wash from 174 to 230 with 5K -Wash from 230 to 242' 10K DECOMP Circulate out clabbered mud - 5 BPM @ 80 psi DECOMP Rack back 1 stand - PU 1 single - 15' pup -Depth 240' DECOMP PJSM -Give to Schlumberger Pump 2 bbls fresh water Pump 22.5 bbls - 15.7 Class Gcement -Yield .96 - 132 sxs - (75 Ibs of cemnet) Pump 2 bbls fresh water DECOMP LD 1 single - 15' pup -Pull 1 stand - MU T.D. -Circulate out cement -Stand back 2 stands - PU single 15' pup -pump flush cement out - LD same -Flush stack with cement retardant DECOMP Close Blinds -Squeeze 6 bbls cement -Pump 1/2 bbl pressure increased to 100 psi then fell to 40 psi -Pump 1 bbl every 2 to 3 mins -PSI increased to 80 over 6 bbls pumped then dropped to 40 psi -Bleed off pressure -Open Blinds -Flush stack with Printed: 5/21/2007 9:08:16 AM BP EXPLORATION Operations Summary Report Page 3 of 5 ~ Legal Well Name: MPH-14 Common Well Name: MPH-14 Spud Date: 8/15/1997 Event Name: PLUG+ABANDON Start : 5/8/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/8/2007 Rig Name: DOYON 14 Rig Number: #14 Date From - To I .Hours ; Task '~ Code NPT ~ ~ Phase j Description of Operations 5/11/2007 02:30 - 06:00 _ - - 3.50 PXA P DECOMP stack washer -Close Blinds Squeeze cement ~ 1 bbl 50 psi dropped to 40 1 bbl 80 psi dropped to 40 1 bbl 100 psi dropped to 50 1 bbl 150 psi dropped to 100 -then to 40 1 bbl 90 psi dropped to 40 .5 bbl 130 psi dropped to 40 Total bbls squeezed 11.5 bbls 3.5 bbls left in casg 06:00 - 12:00 6.00 PXA P DECOMP W.O.C. -Clear rig floor - LD flex DC's - PU 9-6 1/4" DC's - Stand back in derrick 12:00 - 13:00 1.00 PXA P DECOMP PU BHA - 8 1/2" bit, bumper sub, jars, 3-DC's 13:00 - 13:30 0.50 PXA P DECOMP RIH -Break circulation w/ 4 bpm 50 psi -Taking slight weight at 212' -tag w/ 10k down at 242' -Washing off w/ 10k weight - POH 13:30 - 16:00 2.50 PXA P DECOMP W.O.C. - 16:00 - 16:30 0.50 PXA P DECOMP MU BHA -Bit - BS -Jars - 6 DC's -RIH to 242' 16:30 - 17:30 1.00 PXA P DECOMP Tagged soft cement @ 242 - Drlg /Wash down 5' -GPM 250 - PP60-WOB1tot-RPM60-CBU-2X-Con'tin hole-Tag CIBP @ 345' 17:30 - 20:30 3.00 PXA P DECOMP Con't Drill /Wash from 345 to 589 -GPM 330 - PP 190 -RPM 80 - TO 1 to 2 -Pump sweeps every 500' or as needed -CBU 20:30 - 21:30 1.00 PXA P DECOMP POH from 589 to 183 - PU 1 stand DC's -RIH from 273' to 589' 21:30 - 00:00 I 2.501 PXA I P 5/12/2007 100:00 - 15:30 I 15.501 PXA I P 15:30 - 19:00 I 3.50 i PXA I P 19:00 - 23:30 I 4.501 EVAL I P 23:30 - 00:00 0.50 PXA P 5/13/2007 00:00 - 01:30 1.50 PXA P 01:30 - 02:00 0.50 PXA P 02:00 - 03:30 1.50 PXA P 03:30 - 04:00 I 0.50 I PXA f P 04:00 - 06:00 2.00 PXA P 06:00 - 08:00 2.00 PXA P 08:00 - 09:30 1.50 PXA P 09:30 - 15:00 5.50 PXA P 15:00 - 16:30 I 1.501 PXA I P DECOMP Wash from 514' (tag up on fill) to 589' - Con't Drill wash to bottom from 589' to 800' - WOB 15 to 20 -RPM 85 - TO 1 to 2 -GPM 340 - PP 280 - PU, SO, ROT 80 DECOMP Con't clean out sand /gravel from 800' to 2038' - WOB 20k - RPM 80 - PUW 100k -SOW 90k -Rot Wt - 95k - PP 560 psi at 8.5 bpm - TO 1-5k - ROP slowed - Eratic torque -Pump H.V. sweep DECOMP Blow down T.D. - POH from 2038' to 1756' -Encountered tight hole -Swabbing -Pump out from 1756' to 303' -Stand back DC's -Break bit - 27 bbls over on trip fill DECOMP RU Slick line unit -Run CCUGR Memory locator log to 11' - Hole sticky - POH - RD Slick line unit ~~\ ~~, ~~~ ~~ DECOMP MU Bit - PU Jars -RIH to 230' 1~ DECOMP Condition mud before going into open hole ~~L~ L DECOMP Con't MU BHA ~ ~'~'1 DECOMP RIH to T.D. 2038' -Tight spots 935' 20K - 1700 to 1725' floating work through - 1798' 50K work through - No pumping or washing needed -Tight spot 1948' could not work past -Wash / Ream from 1948' to 2038' -GPM 255 @ 450 psi -RPM 100 - TO 2K DECOMP CBU 2.5 X -Shakers clean -GPM 315 - PP 440 -RPM 80 - TO 2K DECOMP Pump out hole from 2038' to 303' w/ 7.5 bpm 440 psi DECOMP Stand back DC's - LD jars, bumper sub, bit - PU muleshoe DECOMP RIH w/ no issues to 2035' DECOMP Circulate and condition mud for cement job while waiting on approval from AOGCC. -GPM 375 - PP 350 -RPM 75 -Flow check -Well static -Pump dry job DECOMP POH - LD 4" DP from 2035' (Waiting on Schlumberger Wireline Services). Printed: 5/27/2007 9:08:16 AM r ' r BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: MPH-14 Common Well Name: MPH-14 Event Name: PLUG+ABANDON Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date ~ From - To ~ Hours ~ Task Code j NPT L_ 5/13/2007 ~ 16:30 - 20:30 4.00 PXA I P 20:30 - 21:30 1.00 PXA P 21:30 - 23:00 1.50 PXA P 23:00 - 00:00 1.00 PXA P 5/14!2007 00:00 - 00:30 0.50 PXA P 00:30 - 01:00 0.50 PXA P 01:00 - 04:00 I 3.001 PXA I P 04:00 - 05:00 1.00 PXA P 05:00 - 05:30 0.50 PXA P 05:30 - 06:00 I 0.501 PXA I P 06:00 - 06:30 0.50 PXA P 06:30 - 07:30 1.00 PXA P 07:30 - 08:00 0.50 PXA P 08:00 - 09:00 1.00 PXA P 09:00 - 10:30 I 1.50 I PXA ~ P 10:30 - 11:00 0.50 PXA P 11:00 - 11:30 0.50 PXA P 11:30 - 12:00 0.50 PXA P 12:00 - 13:00 1.00 PXA P 13:00 - 14:30 I 1.50 I PXA f P Spud Date: 8/15/i 997 Start: 5/8/2007 End: Rig Release: 5/8/2007 Rig Number: #14 Phase I Description of Operations DECOMP PJSM - RU SWS E-line - RIH to 2030' with GPIT Log - POH - RD SWS equipment DECOMP MU Muleshoe -RIH to 2035' DECOMP CBU -GPM 220 - PP 390 - PU 75 - SO 75 DECOMP Give to Schlumberger Pump 2 bbls fresh water Test lines to 2500 Pump 18 bbls fresh water Pump 55 bbls 15.7 ppg AS1 cement -yield .96 - 320 sxs Pump 3.3 bbs fresh water Displace with 6 bbls mud DECOMP Pull 6 stands slowly - LD single - 10' pup -Depth 1423' DECOMP CBU -GPM 425 - PP 480 - 14 bbls cement back to surface - CBU 2nd time DECOMP POH 5 stands -RIH 3 stands 6 1/2" DC's - 1 Stand 5" HWDP - LD HWDP - DC's DECOMP WOC DECOMP RIH tag cement @ 1,434' w/ 15,0001bs and 2 BPM. CBU. John Crisp, AOGCC Rep, witnessed tagging cement. RU head pin and cementers -CBU -GPM 295 - PP 330 DECOMP Give to Schlumberger: Plug #2 Pump 2 bbls fresh water Test lines to 2500 Pump 18 bbls fresh water Pump 55 bbls 15.7 ppg AS1 cement -yield .96 - 320 sxs Pump 1.7 bbs fresh water Displace with 2.2 bbls mud DECOMP POh slowly to 660' DECOMP CBU x2 - 400 gpm, 240 psi - 10 bbls cement back to surface - Flush BOP's w/ treated water from pill pit. DECOMP POH - LD 21 jts. DP DECOMP PU stack washer -Flush BOP's - PU jars and bumper sub from pipe shed -Break and LD same - PU muleshoe on stand of DP. DECOMP RIH to 570' - LD 18 jts 4" DP - (Cement sample not firm enough for tag) DECOMP RIH wl stands to 600' DECOMP Screw in T.D. -Break Circ. w/ 2 bpm -Obtain parameters - Taking weight at 673' -Wash and set 10k down at 703' DECOMP CBU -PJSM - RU head pin and cementers DECOMP Give to Schlumberger: Plug #3 Pump 2 bbls fresh water Test lines to 2500 Pump 67 bbls 15.7 ppg AS1 cement -yield .96 - 392 sxs (returns slowed to 1/2" stream at 47 bbls away) Pump 1.0 bbs fresh water to clear lines DECOMP LD single -Pull 1 stand to 575' while waiting to hook up bulk truck. Give to Schlumberger: Test lines to 2500 Pump 25 bbls 15.7 ppg AS1 cement -yield .96 - 146 sx -Full returns and cement to surface w/ 10 bbls away -overboard 15 bbls cement. Printed: 5/21/2007 9:08:16 AM ~ ~ ~. ~ BP EXPLORATION Operations Summary Report Page5of5~ Legal Wel{ Name: MPH-14 Common Well Name: MPH-14 Spud Date: 8/15/1997 Event Name: PLUG+ABANDON Start: 5/8/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/8/2007 Rig Name: DOYON 14 Rig Number: #14 Date ~ From - To ~ Hours ~ Task ' Code ~ NP T~ Phase ~~ Description of Operations 5/14/2007 13:00 - 14:30 1.50 PXA P DECOMP Pump 1.0 bbs fresh water to clear lines - CIP at 13:30 POH slowly to surface 14:30 - 15:30 1.00 PXA P DECOMP Pull wear ring - PU stack washer -Wash BOP's 3' below well head & function rams 15:30 - 17:00 1.50 PXA P DECOMP WOC - RIH tag hard cement @ 58' from RKB - 20' below ground level - POH - RD mule shoe 17:00 - 20:30 3.50 PXA P DECOMP ND BOP's -Choke line -Flow line - 3' Spacer spool - NU dry hole tree assy -Install TWC -Test adapter flange and hanger to 5K for 10 mins - Test tree to 1000 psi -Test good 20:30 - 22:30 2.00 PXA P DECOMP PJSM - LD stands from derrick in mouse hole 1 X 1 22:30 - 23:30 1.00 PXA P DECOMP Test double tree valve to 1000 psi 5 mins -Chart -Install BPV 23:30 - 00:00 0.50 PXA P DECOMP Prep rig for release -Secure well -Clean cellar Printed: 5/21/2007 9:08:16 AM . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r¡¿,{( '4t 07 DATE: P. I. Supervisor May 14, 2007 FROM: John Crisp, SUBJECT: Petroleum Inspector Cement Plug Tag MPH-14 PB1 BPX PTD 197-150 Mav 14, 2007: I traveled to BP's MPU H-14 PBI to witness cement plug tag with drill pipe. Doyon 14 inadvertently side tracked out of MPU H-14 while attempting to P&A original wellbore. Cement plug was placed from 2238' MD to 1423' MD. I witnessed hard cement tagged @ 1434' three times with DP. Plug was tagged while circulating 2 bpm. 15K indicator weight seen on plug. /' Summary: Cement plug tag on BP's MPU H-14. Attachments: None. Non Confidential S~ JUN 0 {) 2001 , ".'" "."".::,.~,..~""".'.-""., Cement Plug Tag MPU H-l4 PBl 05-14-07 jc.doc Re: MPH-14 P&A Plan Forward . . Subject: Re: MPH-14 P&A Plan Forward From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 14 May 200708:50:19 -0800 To: "Engel, Harry R" <Harry.Engel@bp.com> CC: "Reem, David C" <ReemDC@BP.com>, "NSU, ADW Drlg Rig 14" <NSUADWDrlgRig14@BP.com>, aogcc -prudhoe _ bay@admin.state.ak.us ,~ .. ......}...." "." ,_ :...,..A'.:', ,,-,-:. ,..,.... .. .. Harry, et aI, One housekeeping item with regard to the survey of the unintentional penetration. The name should be MPH-14 PB1 and the API number should have 70 in the lIth and 12th positions. Thanks for the attention to this detail. Call or message with any questions. Tom Maunder, PE AOGCC Thomas E Maunder wrote, On 5/13/200710:58 AM: SCAJ~NED MAY 1 4 Z007 Please note, if you received an earlier message on this subject it was incomplete. Harry, Your message confirms our conversations. I have contacted Commissioner Foerster and apprised her of the situation. She agrees with the plan forward and by copy of this message you have approval to proceed. Please have the Company Man contact the Inspector so he may witness the placement of the bottom plug. A plan should be made to confirm the top of the deepest plug segment. You are allowing 30% excess, however with the unintentional wellbore section in the permafrost a greater excess may be needed. Confirming the TOC will allow adjustments to the excess factor to be made. It is BP's option as to how best to confirm the TOC. Also, based on the information regarding the original Schrader Bluff penetration, it will not be necessary to attempt to re-enter that portion of the wellbore. I will be available on the cell phone should you need to contact me. Tom Maunder, PE AOGCC ----- Original Message From: "Engel, Harry R" <Harry.Engel@bp.com> Date: Sunday, May 13, 2007 10:05 am Subject: MPH-14 P&A Plan Forward To: Thomas E Maunder <tom maunder@ad~I!:...:~tate. ak. us>, "Reem, David C" <ReemDC@BP.com>, "NSU, ADW Drlg Rig 14" <NSUADWDrlgRig14@BP.com>, "Engel, Harry R" <Harry.Engel@BP.com> Tom.. . This is a follow-up to our telephone calls this morning regarding the plan forward to P&A MPH-14. MPH-l4 is Schrader producer with a BHP in the range of 8.5-8.8 ppg. There is 9.5 ppg brine in the well above a mechanical plug near the screens across the Schrader. The mechanical plug does leak from above. There is gravel and sand on top of the plug. The plan forward to complete the P&A is as follows: - Run a directional survey in the open hole side track from approx. 10f2 5/14/20078:53 AM Re: MPH-14 P&A Plan Forward . . 252'-2238' - Cement the entire open hole with Arctic Set cement, 15.7 ppg with 30 % excess in 3 stages - Cement the entire original well bore to surface with Arctic Set cement15.7 ppg At this point a dry hole tree will be installed and Doyon 14 will be released. Milne Pt. Operations will complete the excavation around the well, remove the tree, cut off the 9-5/8" casing and weld on the P&A plate. Please let me know if you have any questions. We will proceed with the directional survey and wait for your approval to proceed the P&A. A revision to the approved Sundry will be submitted. Thanks for your assistance with this change of operations. Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 office 907-564-5510 fax 2 of2 5/14/2007 8:53 AM . . SARAH PALIN, GOVERNOR AI~ASIU.. OIL AlU) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Schrader Bluff Oil Pool, MPH-14 Sundry Number: 307-093 SCANNED MAR 2 2 Z007 tqry¡G11 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 e:q.closed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 1i day of March, 2007 Enc!. . . RECEIVED MAR 1 6 Z007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 ,Alaska Oil & Gas Cons. Commission Anchorage 1. Type of Request: 181 Abandon o Alter Casing o Change Approved Program o Suspend o Repair Well o Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Re-Enter Suspended Well o Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes ~ No 9. Property Designation: 10. KB Elevation (ft): ADL 025906 KBE = 65.70' 4. Current Well Class: ~ Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 197-150 6. API Number: 50-029-22796-00-00 8. Well Name and Number: MPH-14 11. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 4396 5506 3954 95' en th TVD urst Junk (measured): NIA Colla· se 79' 20" 112' 112' 1490 470 5975' 9-5/8" 6007' 4381' 5750 3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluç: 5530' - 5780' Belwo Pluç: 3976' - 4190' 2-7/8", 6.5# L~80 60' Packers and SSSV Type: Gravel Pack Screen Assembly with 9-5/8" HES BWD Perm Packers and SSSV MD (ft): 5506' - 5595' Packer and a 9-5/8' HES BWD Sump Packer 14. Well Class after proposed work: o Exploratory ~ Development 0 Service 13. Attachments: ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencin 0 erations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Na David Reem Title Drilling Engineer ~ April 25, 2007 Date: 16. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ ~ Abandoned o WDSPL Contact Bryan McLellan, 564-5516 Signature Phone 564-4750 Prepared By Name/Number: Date 3 /5 Þ:¡' Sondra Stewman, 564-4750 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ~Iug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other t-::>~.\.'( T",,~ ~ç."C Ç>~;\-S \ð '"" ~~...'> ~~ ~, \7\.-o~c:, ~~~\d ~Cë O~.\-œ ~ o~c.~.A.o~~~ \ a.. , Sundry Number: 30 ,OCj3 In! Date$·?!-tJr Subsequent Form Required: ~ \) Submit In Duplicate . . ~- MPH-14 Plug & Abandonment Scope of Work: Permanently plug and abandon well MPH-14. Reason for Abandonment: The well has buckled production casing with possible holes from 240' to 300' md. There is no surface casing outside the production casing, so cutting and pulling the damaged production casing is not feasible. The well has been deemed unrepairable. MASP: 1075 psi Well Type: Producer Estimated Start Date: April 2007 Proposed Procedure: 1. MIRU Nabors 4ES. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 2-7/8" circulation string. 3. Mill up CIBP at 90' md and push remnants to bottom. 4. Pump 15 bbls of 15.8 ppg Class G cement on top of fill at 5408' md by the displacement method. 5. Wait on cement to gain compressive strength. Set weight on cement to confirm depth of cement top. 6. Displace well to corrosion inhibited seawater. 7. Set CIBP at 2400' (130' below leaking ES Cementer). Set weight on CIBP to confirm that it is set. 8. Set cement retainer at 2150' md (120' above leaking ES Cementer). Set weight on cement retainer to confirm that it is set. 9. Squeeze 19 bbls of 15.8 ppg Class G cement below cement retainer. 10. Displace fluid above top of cement retainer to corrosion inhibited 9.8 ppg brine. POOH with cementing BHA. 11. Set CIBP in 9-5/8" casing at 375'. Set weight on CIBP to confirm that it is set. 12. Displace well with -28 bbls of 15.8 ppg Arctic Set 1 cement, to 5' below original ground level (34' md below original KB). 13. ND BOPE. NU and test dry hole tree. RDMO Nabors 4ES. 14. Remove wellhead and tree. 15. Excavate around conductor and remove casing 3' below original ground level. c ~ 16. Install well abandonment marker. ~ k -4-"ol.-ì\-ì T~c;ç¡~c.AÐC* O~~r-:\~ \-<D ;;\~:> ~~ '3 /0 l ~ Cameron 2 9/16", 5M Wellhead: FMC 11" xii" 5M, Gen 5 20" 91.1 ppf, H-40 I 112' I KOP @ 300' to 3,400' Max. hole angle = 66 deg. Hole angle thru' perfs = 30 deg. 9 5/8' 40 ppf, L-80, BTC production csg. ( drift 10 = 8.835", cap. = 0.0758 bpf ) Stimulation Summary 07/31/98 N M# of CL coated with PL placed behind screens 07/29/98 OA98 M# of PropLok coated 16/20 CarboLite behind pipe 07/27/98 0876.8M# of PropLok coated 16/20 CL behind pipe - re-frac 07/26/98 08 18.4M# of PropLok coated 16/20 CL behind pipe - early shutdowr Perforation Summary Ref loa:SDerrv MWD 8/18/97 Size SPF Interval (TVD) 4.5" 4 7" 4 7" 4 3976'-4010' 4110'-4132' 4171 '-4190' 5530'-5570' 5686'-5712' 5760'-5780' DATE 8-31-97 8/04/98 2/18/99 3/09/01 12/5/03 11/6/05 EV.BY MDO M. Linder MDO B. Hasebe Lee Hulme Lee Hulme COMMENTS 9-5/8" Cased Hole Completion 22E Initial com letion 4-ES W/L Retrieviable PC completion 4 ES ESP completion 4 ES ESP changeout 4ES ESP changeout 4ES H-14 Proposed Orig. KB Elev. = (N 22E) Orig. GL Elev. = 36.6' RT To Tbg. Spool = (N 22E) OSSIBLE HOLES IN CSG 12461 & 282'1 HES CIBP I 375' I Cement Retainer I 2150' Howco 9 5/8" "ES" Cementer I 2270' þasing Leak at ES Cementer HES CIBP I 2400' Inhibited Seawater !Top of Cement i ! ¡Top of Fill !Top of Sand Baker 4-1/2" KB Pkr wI 2-3/8" Ëxcluder 2000 sand screens set inside 4-1/2" screens. ß-5/8" HES 'BWO' perm. Pkr. I wi JP plug set in seal bore ~-1/2" 125 Micron Poroplus ~creens assembly (61' long: ~-5/8" HES 'BWO' sump pkr. , !4-1/2" XN nipple 3.725" 10 iw/lower seals of 2-318" sand Iscreens stung in. .. TD lagged during RWO 11-6/05@ 5782' MD" ~ 5/8' landing collar (PBTO) 9 5/8' float collar ! 9 5/8' float shoe MILNE POINT UNIT WELL No : H-14 API : 50-029-22796 I 5213' 5408' 5458' 5520' 5506' 5527' 5589' 5595' 5,919' 5,963' 6,007' BP EXPLORATION (AK) · ~ Cameron 2 9/16", 5 Wellhead: FMC 11" x 11" 5M, Gen. 5 w/ 11" x 2-7/8" FMC Tbg. Hnr. w/ NSCT threads top, 2-7/8" 8rd btm. 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 112' I KOP @ 300' to 3,400' Max. hole angle = 66 deg. Hole angle thru' perfs = 30 deg. 2-7/8' 6.5 ppf, L-80 EUE tubing (cap. = 0.00579 bpf, drift = 2.347' 9 5/8' 40 ppf, L-80, BTC production csg. ( drift ID = 8.835", cap. = 0.0758 bpf ) Intake TVD = 3870' PumpMate TVD = 3894' Mid-perf TVD = 4083' Mid-perf MD = 5655' PBTD TVD = 4290' TVD PBTD MD = 5919' Stimulation Summary 07/31/98 N M# of CL coated with PL placed behind screens 07/29/98 OA98 M# of PropLok coated 16/20 CarboLite behind pipe 07/27/98 OB 76.8M# of PropLok coated 16/20 CL behind pipe - re-frac 07/26/98 08 18.4M# of PropLok coated 16/20 CL behind pipe - early shutdow Size SPF Interval (TV D) 4.5" 4 5530' -5570' 3976'-4010' 7" 4 5686'-5712' 4110'-4132' 7" 4 5760'-5780' 4171'-4190' Or Elev. = 65.7 ' (N 22E) Orig. GL Elev. = 36.6' RT To Tbg. Spool = (N 22E 2-7/8" 6.5 ppf, L-80 EUE I 60' 8rd tbg HES CIBP 95' POSSIBLE HOLE IN CSG I 246' Est. top of cmt. Howco 9 5/8" "ES" Cementer Casing Leak at ES Cementer 2204' 2270' Top of Fill I 5408' I xxx XX XXXXX I I Top of Sand 5458' 9 5/8" HES 'BWD' perm. Pkr. I 5506' I w/ JP plug set in seal bore Baker 4-1/2" KB Pkr w/ 2-3/8" I 5520' I Excluder 2000 sand screens set inside 4-1/2" screens. 4-1/2" 125 Micron Poroplus 5527' screens assembly (61' long 9-5/8" HES 'BWD' sump pkr. 5589' 4-1/2" XN nipple 3.725" ID 5595' w/ lower seals of 2-3/8" sand screens stung in. .. TD tagged during RWO 10/2106 @ 5827' MD" 9 5/8' landing collar (PBTD) 5,919' 9 5/8' float collar 5,963' 9 5/8' float shoe 6,007 DATE 8-31-97 8/04198 2/18/99 3/09/01 12/5/03 11/6/05 1 0/02/06 REV. BY MDO M. Linder MDO B. Hasebe Lee Hulme Lee Hulme B. McLella COMMENTS 9-5/8" Cased Hole Completion 22E Initial com letion 4-ES W/L Retrieviable PC completion 4 ES ESP completion 4 ES ESP changeout 4ES ESP changeout 4ES ESP changeout 4ES MILNE POINT UNIT WELL No : H-14 API: 50-029-22796 BP EXPLORATION (AK) RECEIVED Scblumberger OCT 1 6 2006 NO. 3990 Alaska Data & Consulting Services 2525 Gambell StI'eet, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth 10"i--/5Ö -f' ""'NEt' :} J ·~""'{,'1"i""~"';;;';·· State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: ,~Oil & Gas Cons. Commission Anchorage Field: Prudhoe Bay WI( J # L B C e ob og Description Date L Color D 12-29 11072867 INJECTION PROFILE 07/07/05 1 Z-19A 11212887 USIT 09/12/06 1 MPH-14 11414383 LDL 09/21/06 1 Z-23B 40010787 OH EDIT OF MWD/LWD 09/04/04 2 1 P·27 40010459 OH EDIT OF MWD/LWD OS/21/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 10/12/06 . . · 8"\.1- \J 1..1 " 1......, . STATE OF ALASKA.. OCT 0 4 2006 ALAS Oil AND GAS CONSERVATION COM~ION ' , REPORT OF SUNDRY WELL OPERATIONS Alaska Oíl & Gas Cons. Commission Anchorage 1. Operations Performed: o Abandon o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program ~ Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 197-150 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22796-00-00 7. KB Elevation (ft): KBE = 65.70' 9. Well Name and Number: MPH-14 8. Property Designation: 10. Field / Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 6025 feet true vertical 4396 feet Plugs (measured) 95' Effective depth: measured 5506 feet Junk (measured) N/A true vertical 3954 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 112' 112' 1~90 470 Surface Intermediate Production 5975' 9-5/8" 6007' 4381' 5750 3090 Liner 8\ìANNE]) $ Ü Perforation Depth MD (ft): Below Plug: 5530' - 5780' Perforation Depth TVD (ft): Belwo Plug: 3976' - 4190' 2-7/8",6.5# L-80 60' Tubing Size (size, grade, and measured depth): , .... Packers and SSSV (type and measured depth): 9-5/8" Gravel Pack Assembly 5506' - 5595' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft 0 CT i) 4: 2006 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-BbJ Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 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: Contact Bryan McLellan, 564-5516 N/A ~=:$on~~_~ Title Technical Assistant Prepared By Name/Number: Si::7VR~ ,f<t\_ Lj/'ì"}} 0 J~ , Phone 564-4750 Date lc:r03-('j(~ondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ö" (~:. i.\~ l~\ Submit Original Only \, \ ~ Cameron 2 9/16", 5M Wellhead: FMC 11" x 11" 5M, Gen. 5 wi 11" x 2-7/8" FMC Tbg. Hnr. w/ NSCT threads top, 2-7/8" 8rd btm. 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 112' I KOP @ 300' to 3,400' Max. hole angle = 66 deg. Hole angle thru' perfs = 30 deg. 2-7/8' 6.5 ppf, L-80 EUE tubing (cap. = 0.00579 bpf, drift = 2.347" 9 5/8' 40 ppf, L-80, BTC production csg. ( drift ID = 8.835", cap. = 0.0758 bpf ) Intake TVD = 3870' PumpMate TVD = 3894' Mid-perf TVD = 4083' Mid-perf MD = 5655' PBTD TVD = 4290' TVD PBTD MD = 5919' Orig. KB Elev. = Orig. GL Elev. = 3 . ' RT To Tbg. Spool = (N 22E) 2-7/8" 6.5 ppf, L-80 EUE- I 60' 8rd tbg (N 22E) I HES CIBP I 95' I OSSIBLE HOLES IN CSG 246' & 282' Est. top of cmt. Howco 9 5/8" "ES" Cementer Casing Leak at ES Cementer 2204' 2270' Top of Fill I 5408' I xxxxx xxxxx I I Top of Sand 5458' Stimulation Summary Baker 4-1/2" KB Pkr w/2-3/8" I 07/31/98 N M# of CL coated with PL Excluder 2000 sand screens I 5520' placed behind screens set inside 4-1/2" screens. I 07/29/98 OA98 M# of PropLok coated -5/8" HES 'BWD' perm. Pkr. I 5506' 16/20 Carbo Lite behind pipe w/ JP plug set in seal bore 07/27/98 0876.8M# of PropLok coated 4-1/2" 125 Micron Poroplus I 5527' I 16/20 CL behind pipe - re-frac screens assembly (61' long: 07/26/98 08 18.4M# of PropLok coated 9-5/8" HES 'BWD' sump pkr. I 5589' I 16/20 CL behind pipe - early shutdowr I 5595' I 4-1/2" XN nipple 3.725" ID w/lower seals of 2-318" sand screens stung in. Size SPF Interval 4.5" 4 5530'-5570' 3976'-4010' 7" 4 5686'-5712' 4110'-4132' 7" 4 5760'-5780' 4171'-4190' DATE 8-31-97 8/04/98 2/1 B/99 3/09101 12/5/03 11/6/05 Ell. BY MDO M. Linder MDO B. Hasebe Lee Hulme Lee Hulme COMMENTS 9-5/8" Cased Hole Completion 22E Initial com letion 4-ES W/L Retrieviable PC completion 4 ES ESP completion 4 ES ESP changeout 4ES ESP changeout 4ES .. TD tagged during RWO 11-6/05 @ 5782' MD .. 9 5/8' landing collar (PBTD) 5,919' 5,963' 6,007' 9 5/B' float collar 9 5/8' float shoe MILNE POINT UNIT WELL No : H-14 API : 50-029-22796 BP EXPLORATION (AK) ~ . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 9/17/2006 02:00 - 04:30 2.50 RIGD P PRE Rig down off of MPH-04. Disconnect lines and Rig components. Lower and Scope Derrick. 04:30 - 06:00 1.50 MOB P PRE Begin moving all Rig components to MPH-14. 06:00 . 08:00 2.00 MOB P PRE PJSM. Spot rig over well. Raise & scope up derrick. Rig accepted @ 08:00 hrs, 09/17/2006. 08:00 - 12:30 4.50 KILL P DECOMP PJSM. Prep to kill well. Take on heated seawater, rig up tiger tank, test lines to 3500 psi, OK. P/U lubricator, pull BPV. SITP = 120 psi, SICP = 550 psi. 12:30 - 17:00 4.50 KILL P DECOMP Line up thru choke & bleed tbg down to 40 psi. Line up & circulate heated seawater down tubing @ 5 bpm / 850 psi, taking returns thru choke to tiger tank. Gas & thick oil in returns after pumping 100 bbls. Pumped 550 bbls, no seawater returns, heavy thick oil. Bullhead 80 bbls to loosen things up @ 5 bpm, 1100 psi. Circulate @ 5 bpm down tubing @ 850 psi, taking returns thru choke to tiger tank. Pump 225 bbls, shut down & monitor well. Tbg dropped from SITP of 90 psi to 0 psi in 30 minutes, itA @ 120 psi. 17:00 - 20:00 3.00 KILL P DECOMP Wait on vac trucks to deliver more seawater to continue cleaning up/killing well. Monitor well continuously. The tubing pressure is at 0 psi and the IA is at 90 psi. Pre-tour safety meeting with night crew. 20:00 - 22:00 2.00 KILL P DECOMP Seawater on location. Begin taking seawater into Pits. 22:00 - 23:00 1.00 KILL P DECOMP Pressures on the well are 0 psi on the Tubing and 90 psi on the IA. Open the choke and bleed gas off of the well. Tbg pressure = vac and IA = 50 psi. Break circulation with seawater at 4 bpm. Caught fluid at 5 bbls away (925'). Circulating pressure of 4 bpm /500 psi. After 50 bbls away, getting thick crude oil to surface. Continue to circulate with hot seawater. Pumped a total of 225 bbls. 23:00 - 23:30 0.50 KILL P DECOMP Close the choke and have 20 psi on the tubing and IA. Line up to circulate taking returns into the Pits to monitor. Break circulation at a rate of 3 bpm / 300 psi with 0 psi on the IA. Monitor returns and have traces of oil sheen on the seawater. Observe 10 minute loss, lost 5 bbls = 30 bph. 23:30 - 00:00 0.50 KILL P DECOMP Shut down the pump and monitor the well dead - both the tubing and IA are on a vacuum. Monitor for 30 mins. 9/18/2006 00:00 - 01 :00 1.00 WHSUR P DECOMP Set TWC with FMC representative. Test TWC from above to 3,500 psi for 10 mins - charted. Attempt to test from below by injecting at a rate of 6 bpm / 800 psi for 10 mins - charted. Injected a total of 35 bbls. 01 :00 - 02:00 1.00 WHSUR P DECOMP PJSM. ND Tree and Adapter Flange. 02:00 - 05:00 3.00 BOPSU P DECOMP PJSM. NU Double-Studded Adapter and Test Spool. NU 13 5/8" BOPE. 05:00 . 06:00 1.00 BOPSU DECOMP RU Test Equipment in preperation for BOPE Test. Open IA and still on a vac. 06:00 - 09:30 3.50 BOPSU DECOMP PJSM. Test BOPE and all associated components @ 250 psi low, 3500 psi high, 5 minutes each test, charted, no failures. Witnessing of test waived by State AOGCC rep Chuck Sheve. Test witnessed by Nabors Tool Pusher & BP Company Man. Conducted drawdown test of accumulator, OK. 09:30 - 10:30 1.00 BOPSU DECOMP PJSM. Pull two way check valve. 10:30 - 12:00 1.50 PULL DECOMP PJSM. P/U landing joint, screw into hanger, BOLDs, pull hanger to floor w/ 50K up wt. Hanger looks good. Pull cables Printed: 101212006 10:55:34 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 9118/2006 10:30 . 12:00 12:00 . 20:00 1.50 PULL P 8.00 PULL P DECOMP DECOMP 20:00 - 00:00 4.00 PULL P DECOMP 9/19/2006 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 01 :30 1.00 CLEAN P CLEAN 01 :30 - 04:00 2.50 CLEAN P CLEAN 04:00 . 05:00 1.00 CLEAN P CLEAN 05:00 - 06:00 1.00 CLEAN P CLEAN 06:00 - 11 :00 5.00 CLEAN P CLEAN 11 :00 - 16:30 5.50 CLEAN P CLEAN over sheeve & prep to pull heat trace & ESP completion. POOH w/2 7/8" EUE 8 rnd tubing & ESP I Heat trace completion. At 18:30 hrs, all Heat Trace out of the hole. Pull over Sheave and RD Heat Trace handling equipment. Continue POOH with ESP Completion. The last stand (3 jts) of 2 7/8" Tubing had scale on the outside. The pump was full of sand and scale. Break down ESP Assembly with Centrilift reps and lay down in Pipe Shed. Place components into boxes. Clear and clean Rig Floor. Continue cleaning Rig Floor and RD Elephant Trunk Hose. PU and MU BHA #1 as follows: Bull Nose Guide, XO. XO, Jet Valve, XC, 3.7" Drift, XO, XC. OAL = 9.59'. TIH with BHA #1 on 2 7/8" PAC DP. PU 25 Jts of PAC DP 1 x 1 from Pipe Shed. Continue TIH with 2 7/8" EUE 8rd Tubing Joints from Derrick. Take weight 3' in on Joint #154. stack 10K. PU and run back in and stack 10K again. Third time slid right in. The depth is 5.610'....suspect XN Nipple (15' deeper than schematic). Continue RIH. Tag fill 3' from bottom of Joint #158 = 5,761'. Hard tag repeated to verify top of fill. MU Headpin and line up to circulate the long way to fill the hole up. Close the Bag and line up to reverse circulate. Fill the annulus up. PJSM. Establish parameters. Up wt 45K down wt 35K. Wash down circulating the long way @ 3 1/2 bpm, 525 psi, to 5799'. Line up & close bag & reverse out to clean retums, plugged pipe a couple of times & circulated the long way to unplug. Reverse circulate @ 5 bpm I 550 psi. Loss rate = approximately 1 bbl for every 3 bbls pumped. After clean returns back, make a connection & wash down to 5827'. Tag @ 5800'. set down hard a couple of times & broke thru, OK. Wash down to 5827' & turn it around & reverse out @ 5 bpm I 550 psi to clean returns. Make another connection & set down 10 -15K several times, attempt to pick up and observe over pull of 10 - 15K. Mix (20 bbls 3 Ibs/bbl of duo vis) Hi vis sweep & reverse circulate to clean hole @ 5 bpm I 550 psi. With sweep coming around nozzle attempt to free up pipe. Pulled to 90K. (45K over up wt), and observed pipe movement with 10 -20K overpulling for a few feet to 5823'. Pulled free at that point with no drag. Finish reverse circulating sweep around to clean retums. PJSM. UD (7) joints to 5638' & drop ball to close bottom port on jetting sub & divert all fluid to side ports. Circulate ball down & observe it hit with new circulating pressure of 5112 bpm I 1200 psi. Begin screen cleaning operation by pulling up slowly while circulating @ 5 1/2 bpm, (80'), & dropping slowly back down to 5638'. Repeat process twice more for a total of (6) passes, 3 up & 3 down. Lay down (1) joint and do it again from 5609',3 up & 3 down as before, circulating @ 5 bpm 11200 psi. Repeat again after laying down another joint of tbg and continue in this fashion to a final depth of 5449'. Mix another (20 bbls. 31bs/bbl dou vis) Hi vis sweep & circulate this all the way around @ 5 bpm 11200 psi to clean returns. (NOTE) Printed: 101212006 10:55:34 AM Legal Well Name; Common Well Name: Event Name; Contractor Name: Rig Name; MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date; 8/15/1997 End: 10/2/2006 Never saw any more overpulling during this cleanout operation. Suspect junk down there @ 5827'. POOH & stand back 55 stands of 2 7/9" tubing + 1 stand of 2 7/8" PAC DP. POOH & UD 21 jts of 2 7/8" PAC DP. P/U & M/U Mule shoe wI 3.8" gauge ring on 2 7/8" PAC DP. R/U tools to RIH. BHA #2 : Mule Shoe wI 3.8" GR, XO, 4 Jts 27/8" PAC DP = 127.60' RIH wI 55 stands of 2 7/8" tubing. Con't to single in hole w/2 7/8" tubing. Tagged up on top of packer @ 5514'. 57 stands of tbg + 4 jts of PAC DP + 4'. Attempt to enter top of packer several times wlo success. Rotated tubing 1/2 turn & slacked off wi 7k & fell thru. P/U wI 8k overpull & pull up above packer. M/U circulating pin & break circulation, 4 BPM @ 400 psi. RIH & attempted to go thru packer several more times before falling thru w/1 1/4 turns. CLEAN Con't to circulate & wash. took weight @ 5520' & 5533'. Wash down thru screen section & had to work thru @ 5548'. con't in hole & located "XN" Nipple @ 5602'. Slacked off w/14K & lost returns. Pressure increased 300 psi to 700 psi. P/U w/15K overpull & retagged. P/U wlo overpull. POOH to above packer. RIH & tag packer. Slowly rotate & work thru top of packer. Con't to RIH thru screens, drift & retag "XN" Nipple. wI no circulation. No tight spots. CLEAN UD 6 singles & stand back 56 stands of tubing. UD 4 jts of 2 7/8" PAC DP. UD muleshoe wI GR. RUNCMP PJSM. M/U screen assembly as per Baker hand. RUNCMP PJSM. RIH wI screen I packer assembly on 2 718" EUE 8 rnd tubing, 56 stands. RUNCMP PJSM. P/U jt #169 & tag top of packer 12' in @ 5513'. P/U & rotate wi chain tongs while slacking off, popped through, OK. Pick up (2) more joints & make up a 10' pup. Locate out in XIN Nipple @ 5602' wI 6' in on pup. 42K up wt, 28K down wt. Set down 8 - 9K on packer & set same, pick up to 55K to verify, OK. Set back to down wt of 28K & line up to test 9 5/8" x 27/8" annulus. Close annular preventor & attempt to test 9 5/8" x 2 718" annulus to 500 psi, 6 bbls to achieve pressure of 500 psi, should have been about 3/4 bbl. Observe pressure bleed off rapidly. Double check valve alignment & rig up lines below pipe rams on 9 5/8" annulus. Open bag & close pipe rams & attempt to pressure 9 5/8" x 2 7/8" annulus to 500 psi, took almost 7 bbls to achieve test pressure & bled off rapidly as before. Place plastic bag over tubing wi circulating valve on tubing open & repressure 9 5/8" x 2 7/8" annulus to 500 psi, observe tubing on a slight vacuum indicating no apparent communication to tubing. Suspect casing patch leak in 95/8" around 2250'. Consult town & drop 5/8" ball & shear off Baker 3.70" Compression Set Straddle Packer wi 3500 psi on tubing. NOTE: Approximate leak off rate while attempting to get a 500 psi test on said annulus was 2 bpm @ 250 - 300 psi. Top of packer @ 5523'. RUNCMP PJSM. POOH w/2 7/8" EUE 8 rnd tubing & packer running tool. 9/19/2006 11:00 -16:30 5.50 CLEAN P CLEAN 16:30 - 19:30 3.00 CLEAN P CLEAN 19:30 - 20:00 0.50 CLEAN P CLEAN 20:00 - 20:30 0.50 CLEAN P CLEAN 20:30 - 22:30 2.00 CLEAN P CLEAN 22:30 - 23:00 0.50 CLEAN P CLEAN 23:00 - 00:00 1.00 CLEAN P CLEAN 9/20/2006 00:00 - 02:00 2.00 CLEAN P 02:00 - 04:30 2.50 CLEAN P 04:30 - 06:00 06:00 - 10:30 10:30 - 13:00 13:00 - 16:30 3.50 RUNCO Printed: 101212006 10:55:34 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Spud Date: 8/15/1997 End: 10/2/2006 Start: Rig Release: Rig Number: 9/17/2006 10/2/2006 Clearl clean rig floor. Rig up to run 3 1/2" DP. Prep to test rams on 3 1/2" DP. 17:30 - 18:00 DFAL INTERV RlU to P/U 3 1/2" DP. RlU test equip. 18:00 - 21 :00 DFAL INTERV Wait on 31/2" DP, test plug & wear bushing. 21 :00 - 21 :30 DFAL INTERV Begin loading & strapping 31/2" DP. Set test plug. Run in 4 lock down screws. 21 :30 - 23:30 DFAL INTERV Fill stack. RlU test equip. Attempt to test 2 7/8" x 5 " VBRs w/3 1/2" test jt. Test failed. pressure leaked off 200 psi in 3 min. UD test jt. Drain BOP stack. 23:30 - 00:00 DFAL INTERV Change out 2 7/8" x 5" VBRs. 9/21/2006 00:00 - 00:30 DFAL INTERV Finish changing 2 7/8" x 5" VBRs to 3 1/2" x 6" VBRs. 00:30 - 01 :00 DFAL INTERV Fill stack. Pressure test VBRs. LP 250 psi, HP 3500 psi. Rams tested good. Charted same. 01 :00 - 02:00 DFAL INTERV Drain BOP stack. RID test equip. Pull test plug. Install 9" ID Wear Bushing. Run in 2 lock down screws. 02:00 - 08:00 DFAL INTERV P/U Halliburton "JP" plug & setting tool. M/U on 3 1/2" DP. P/U 3 1/2" DP 1x1 from pipe shed & RIH. 08:00 - 09:00 DFAL INTERV PJSM. 175 jts DP in the hole. 85K up wt, 41K down wt. M/U 20' 3 1/2" DP pup & tag top of packer & J into same wI JP plug 2' in on pup @ 5511 '. Pick up to 95K to verify, OK. Set down, turn pipe to the left & release from packer, OK. Close annular preventor, line up & reverse circulate until fluid returns up DP. Line up & circulate the long way to fluid returns, well bore fluid packed, OK. Close in well & attempt to pressure test, pumping away seawater @ 2 bpm I 250 psi, 3 bpm, 550 psi & 4 bpm I 700 psi. Shut down pump & pressure bled off immediately. Rig down circulating head. 09:00 - 13:00 DFAL INTERV PJSM. POOH w/3 1/2" DP & plug running tool. 13:00 - 15:00 DFAL fNTERV PJSM. Clear I clean rig floor, rig up shooting flange. 15:00 - 21 :00 DFAL INTERV PJSM. Rig up Schlumberger E line, shooting flange & BOPE. Pressure up & test lubricator to 500 psi, test Ok. 21 :00 - 00:00 DFAL fNTERV Fill hole wi 20 bbls. Pump 40 bblsfor temperature correlation. Begin running in hole. 9/22/2006 00:00 - 03:00 DFAL INTERV Con't to Run in hole wI Spinner Survey Tools. Establish injection rate, 2 1/2 BPM @ 400 psi. Log well from 5500 to surface'. Found leak @ 2264'. Located leak @ 2263'. Pumped total of 606 bbls. Bled back 13 bbls. Monitor well, well dead. 03:00 . 04:30 DFAL INTERV RID E-line tools & lubricator. Clear & clean rig floor. 04:30 - 05:30 DFAL INTERV N/D shooting flange. N/U flow nipple. 05:30 - 06:00 DFAL INTERV M/U mule shoe on 3 1/2" DP & RIH to dump sand on "JP" Plug. 06:00 - 09:00 3.00 DFAL INTERV PJSM. RIH wI mule shoe on 3 1/2' DP, tag top of packer @ 5511 '. POOH up to 5400'. 09:00 - 11 :00 DFAL INTERV PJSM. Dump 2500# of 20 40 river sand on "JP" plug in packer @ 5511'. Circulate DP clean & tag top of sand @ 5458'. 11 :00 - 14:30 DFAL fNTERV PJSM. POOH w/3 1/2" DP & muleshoe. 14:30 - 17:00 DFAL INTERV PJSM. Load pipe shed w/6 1/4" DCs & strap same. Load & M/U BHA. 17:00 - 18:00 DFAL fNTERV Load, tally & M/U BHA as follows: 73/8" Tapered Mill, XO, XO, 8.5" String Mill, XO, 2 . Boot Baskets, XO, String Magnet, Oil Jars, XO. TL = 51.23'. 18:00 - 19:00 DFAL INTERV P/U 4 3/4" Dcs & RIH. Tagged up @ 134'. Took weight. Work pipe & went thru tite spot. POH & check string. Magnet had Printed: 101212006 10:55:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 lots of scale on it. Con't to P/U 4 3/4" DCs & RIH. Tagged up & took weight @ 217'. Work pipe would not go deeper. P/U kelly & break circulation. 6 BPM @ 150 psi. Work & rotate pipe 0-5K. Went to 228'. Con't to work & rotate for 10 min no progress. Notified town engineer of problems. Plan to run caliper on Slick Line. 20:00 - 21 :00 DFAL INTERV Set back kelly. POOH & stand back DCs. 21 :00 - 22:30 DFAL INTERV Break out & UD BHA. inspect mills, clean magnet & empty boot baskets. The tapered 7 3/8" mill showed wear. The 8.5" string mill had no wear. Recovered 1 gal of scale & millings from boot baskets. 22:30 - 00:00 DFAL INTERV Wait on Slickline truck & Caliper. Clean & maintain rig. 9/23/2006 00:00 - 01 :00 DFAL INTERV Con't to wait on Slickline equip & Caliper. Clean & maintain rig. N/D Flow Nipple & N/U Shooting Nipple. 01 :00 - 02:30 DFAL INTERV Spot in Slickline Unit. Unload tools. 02:30 - 04:30 DFAL INTERV RIU Slick line Equip & lubricator. Pressure test lubricator to 500 psi, Ok. 04:30 - 06:00 DFAL INTERV RIH wI 6" LIB & drift csg to 3500', no problems. POOH & UD LIB.. 06:00 - 08:00 DFAL INTERV P/U 40 finger caliper & RIH on Slickline. RIH to 2300' & log up. 08:00 - 09:30 DFAL INTERV Evaluate caliper log. Tight spot, (248'), 8.3" ID for about 5'. At 300', JD = 8.5". No other significant ID anomolies, however, after sending data to Houston, rep there advised that further interpretation indicates significant buckling of 9 518" casing from 248' down that is, no doubt, contributing to problems getting 8 1/2" milling assembly down. 09:30 - 12:00 2.50 CASRE DFAL INTERV PJSM. Rig down E line, rig down shooting flange, nipple up flow nipple. Order out 8.125" swedge & 8 3/8" swage. 12:00 - 13:30 1.50 CASRE DFAL INTERV PJSM. Clear I clean rig floor, wait on swages due to rig move in Deadhorse area. 13:30 - 14:30 1.00 CASRE DFAL INTERV PJSM. M/U 8.125" swaging BHA. 14:30 - 16:30 2.00 CASRE DFAL INTERV PJSM. RIH wi 8.125" swaging BHA. Encounter resistance @ 248', took 5K to work thru, see tight spot agina @ 300', see weight fluctuating to 900' & then fell free to area around 2272'. Took up to 15K to work thru this area, (this is casing patch). Work thru OK. Worked pipe up & down thru all tight spots. @ 2300', 45K down wt, 55K up wt. 16:30 - 17:30 1.00 CASRE DFAL INTERV PJSM. Mix & circulate 30 bbls seawater wI (1) EP mud lube down & back up to within 100' of surface. 17:30 - 19:00 1.50 CASRE DFAL INTERV PJSM. POOH w/3121" DP. 19:00 - 21:00 2.00 CASRE DFAL INTERV Stand back 3 stands of 61/4" DCs. UD 8.125" swage. Pick up 8.375" swage assy. RIH wI 6 1/4" DCs. Con't to RIH had 5K drag from 240 to 300'. 21 :00 - 22:00 1.00 CASRE DFAL INTERV Con't to RIH & tag csg patch @ 2248'. Con't in hole & bottomed out @ 2277, (bottom area of patch). 22:00 - 23:00 1.00 CASRE DFAL INTERV POOH & stand back 3 1/2" DP. 23:00 - 00:00 1.00 CASRE DFAL INTERV POH & stand back 3 stands of 61/4" DCs. 9/24/2006 00:00 - 00:30 0.50 CASRE DFAL INTERV UD swage assy. Clear & clean rig floor. 00:30 - 02:30 2.00 CASRE DFAL INTERV P/U & M/U 8 1/2" Mill Assy as follows: Bull Nose, String Mill, XO, 2 * Boot Baskets, XO, String Magnet, Oil Jar, XO, 9 * 6 1/4" DCs XO. TL = 316.73 02:30 - 04:30 DFAL INTERV RIH, Tagged up @ 244',270' & 300'. Mill & work pipe thru tight spots several times. Con't to RIH. P/U 30K, SIO 30K, Rot Wt = Printed: 10/212006 10:55:34 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 1 0/2/2006 30K. 60 RPMs, Torq = 0-3500 ft-Ibs, 3 BPM @ 40 psi. WOB 0-3K. Set back kelly & UD 2 singles. RIH wI 3 stand of DCs. RIH wI stands of DP. No more tight spots. PJSM. Service rig & RIH wI DP to 2219'. NOTE: Recent PDS log indicates casing patch is 2253' - 2283' DPM. Kelly up & establish parameters. 54K up wt, 50K down wt, 53K rotating wt. Bring on pump @ 6 bpm I 375 psi. Drop on down, make a connection & tag @ 2262'. Rotate @ 90 - 100 RPM, off bottom torque = 2500 ftllbs. Mill off ID of casing patch by observing torque increase of 500 - 1000 ftllbs and milling off until torque smooths out @ around 2500 ftllbs to keep cuttings fine. Stalled @ 2273' wI 7000 ftllbs of torque. Pick up & ream down, OK. Mill on down & drop out of patch @ 2275'. Ream down to 2300' & pick up thru to 2245', no overpulls. DFAL INTERV PJSM. Circulate 40 bbls Hi Vis sweep of seawater wI 3 Ibs I bbl duovis around @ 5 bpm I 250 psi to clean returns. No significant amounts of metal across shaker. (Magnet sub in drill string). 23 bbls total losses during milling ops & circulation. PJSM. Stand back kelly & POOH wI milling assembly. PJSM. UD milling assembly & pick up 9 5/8" casing scraper. Inspect mill, in guage, 8 1/2" OD, not very much wear. Magnet sub is loaded wI shavings. P/U . MIU Casing Scraper Assy as follows: Bull Nose, XO, 9 5/8" Csg Scraper, XO, String Magnet, Bumper Sub, Jars, XO, 9 ·61/4" DCs, XO. TL = 310.63". RIH wI same. RIH on 3 1/2" DP & scrape casing. Entered csg patch & lost 5K weight. Had 2 bobbles while going thru patch @ 2255' & 226'. Con't to scrape casing to 2499'. P/U Wt = 52K, SIO Wt = 48K. POOH wI Csg Scraper & stand back 31/2" DP. Pulled 13 stands. Cut & slip 84' of drilling line. Inspect & adjust brakes. Con't to POOH & satand back 31/2" DP. Stand back 6 1/4" DCs. Break out & UD casing scraper assy. Clean string magnet. Much cuttings & E-P lube.. Recovered 1/2 gal of cuttings & E-P Lube. Clear & clean rig floor. Had E-P Mud Lube all over floor from BHA. P/U running tool & set test plug. RILDS. RIU test equip. Prep to test BOPE. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Lou Grimaldi wI AOGCC. Perform drawdown test on accumulator. Test witnessed by Nabors Tourpusher & BP Company Man. PJSM. M/U Halliburton RTTS. PJSM. Set RTTS in 9 5/8" casing @ 2188' DPM. 50K up wt, 43K down Line up & test from RTTS to surface @ 1000 psi I 5 minutes, zero bleed off, increase pressure to 1500 psi f/30 minutes, charted, no bleed off, good test. PJSM. Release RTTS & RIH thru milled out patch & set RTTS @ 2411'. 54K up wt, 50K down wt. PJSM. Line up & test below RTTS from 2411' to top of sand 04:30 - 06:00 DFAL INTERV 06:00 - 07:00 DFAL INTERV 07:00 - 13:30 DFAL INTERV 13:30 - 15:00 15:00 - 16:30 1.50 CASRE DFAL INTERV 16:30 - 18:00 1.50 CASRE DFAL INTERV 18:00 - 19:00 DFAL INTERV 19:00 - 20:30 DFAL INTERV 20:30 - 21 :30 1.00 CASRE DFAL INTERV 21 :30 - 23:30 2.00 CASRE DFAL INTERV 23:30 - 00:00 0.50 CASRE DFAL INTERV 9/25/2006 00:00 - 02:00 2.00 CASRE DFAL INTERV 02:00 - 03:00 1.00 CASRE DFAL INTERV 03:00 - 03:30 0.50 CASRE DFAL INTERV 03:30 - 07:30 4.00 CASRE DFAL INTERV 07:30 - 08:30 1.00 CASRE DFAL INTERV 08:30 - 09:30 1.00 CASRE DFAL INTERV 09:30 - 11 :00 1.50 CASRE DFAL INTERV 11 :00 - 12:00 1.00 CASRE DFAL INTERV 12:00 - 14:00 2.00 CASRE DFAL INTERV Printed: 101212006 10:55:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 plug @ 5458'. Test @ 1000 psi 15 minutes, no bleed off, increase pressure to 1500 psi. Pressure bled 200 psi in 15 minutes, & showed no sign of leveling off. Released RTTS, ran in hole to 2488'. Reverse circulated bottoms up to clean returns, 3 bpm 1250 psi. Set RTTS. Une up & pressure up to 1000 psi, testing from 2488' to top of sand plug @ 5458'. Pressure bled from 1100 psi to 800 psi in 30 minutes, showed no indication of leveling off. Increased pressure to 1700 psi, pressure bled to 1500 psi in 15 minutes & on down to 1300 psi in 30 minutes, test failed. Bleed off all pressure. PJSM. POOH w/3 1/2" DP & UD Halliburton RTTS. PJSM. Set test plug, close blind rams & test against test plug to 1500 psi. Open annulus valve & monitor. Replace seals in annular cap & seals in opening chamber cap. P/U 3 1/2" test jt & test annular. LP 250 psi. HP 3500 psi. Chart same. Pull test plug. Install 9" Wear Bushing. Run in 2 lock down screws. Torq annular cap & jaw screws. Load, drift & tally 7" 26# BTC-M casing. Load ZXP packer wI WLEG assy. Hold PJSM. P/U ZXP packer assy wI WLEG & setting tool. RIH on 31/2" DP. Stopped @ 83' in on 1st stand. Down weight was 15K lost 5K weight. WLEG @ 126' . Pkr 8.4" GR @ 110'. POOH & inspect packer assy. DFAL INTERV Paint GR wI green paint, P/U 3 . 4 3/4" DCs & RIH wI ZXP Packer assy. Stopped @ same depth as before. WLEG @ 126'. ZXP Packer assy appears to be too stiff to go thru buckled 9 5/8" pipe. POOH & inspect ZXP packer assy. Green paint wear shows casing appears to be egged. UD ZXP packer assy. DFAL INTERV Discuss options wI Baker & notify town engineer of problems. Service rig. Perform Pre- Tour inspections. Wait on development of new plan forward. DFAL INTERV UD 1 stand of 43/4" DCs. MIU BHA # 7 as follows: Bull Nose, String Mill, XO, XO, String Mill. XO, 2 . Boot Baskets, XO, Jars, XO, 3·6 1/4" DCs, XO. . DFAL INTERV UD top Drill collar. RIH & tag up @ 131'. P/U kelly. Break circulation. 6 BPM @ 80 psi. Rot 90 RPMs. Ream from 131' to 244' @ l' I min. Stopped making hole. Call town engineers & get go ahead to mill in one spot. P/U Wt = 23K, SIO Wt = 23K, Rot Wt = 23K. Con't to mill on casing, now milling ahead @ 4' I hr. AT 246' brine turned gray & got some cement & gravel back in returns. (hole in casing). Con't to mill. occasional 1-2 spots wI no resistance. Mill to 263' & stuck pipe. P/U to 75K. Pump Hi-Vis sweep. Gravel & sand fell in on top of BHA when picking up prior to making a connection. ) Work pipe & rotate free. Set back kelly. Stand back DCs. POH & inspect BHA. Bottom string mill shows wear on leading edge. Vis up system to 45 vis. No losses noted. Clean out Boot Baskets. Recovered 5 gals of cuttings, sand & gravel. MIU BHA. RIH & Tagged @ 248'. P/U kelly & ream from 248 to 265' Hard 14:00 - 16:00 2.00 CASRE DFAL INTERV 16:00 - 23:00 7.00 CASRE DFAL INTERV 23:00 - 22:30 23.50 CASRE DFAL INTERV 22:30 - 00:00 1.50 CASRE DFAL INTERV 9/26/2006 00:00 - 01 :30 1.50 CASRE DFAL INTERV 01 :30 - 03:00 1.50 CASRE DFAL INTERV 03:00 - 05:00 2.00 CASRE N 05:00 - 09:00 09:00 - 11 :30 11 :30 - 22:00 10.50 CASRE N 22:00 - 00:00 DFAL INTERV 9/27/2006 00:00 - 01 :00 1.00 CASRE DFAL INTERV 01 :00 - 03:00 2.00 CASRE DFAL INTERV Printed: 101212006 10:55:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 03:00 - 04:30 04:30 - 06:00 06:00 - 08:00 1.50 CASRE 2.00 CASRE 08:00 - 10:00 2.00 CASRE 10:00 - 12:00 reaming. WOB 2-4K. Torq =2-3.5K ft-Ibs. 60 RPMs, 6 BPM @ 60 psi. DFAL INTERV Make connection @ 265'. Con't to mill to mill to 297'. Had 1 bad spot from 270 to 280' otherwise no problems on the rest of thew connection. Had to work thru 10' section several times until we could get thru wlo rotation. Still taking 2-4K wt. P/U 30K, SIO 30K, Rot Wt 30K. 5 BPM @ 60psi. WOB 3-4K. 60-70 RPMs. Torq 3K ft-Ibs. DFAL INTERV Make connection @ 297' Con't to mill. No Losses noted. DFAL INTERV Continue to ream and mill 95/8" Casing from 297' - 348'. Fell through from 348'-359'. Discuss pain forward with Anch Eng. DFAL INTERV Short-trip (no rotation) from 359' back to 30' as follows: 359'- 328' 5 Kover-pull, 328' - 297' 4 - 7K over-pull, 297' - 266' free, 266' - 235' free, 235' - 205' free, 205 - 170' a few bobbles, 170- 140' 4K over-pull, 140 - 30' free. DFAL INTERV Continue back in hole to 359'. Same spots the pulled tight... took weight to get trough (no rotation) going in. Continue TIH. Pass through Casing Patch at 2,248 - 2,278' with-out any problems. Found a tight section at 2,923' - 2,989'. Ream and mill through with not much problem. Continue TIH. Tagged-up at 5,326' (sand top target = 5,450'). Wash and rotate. P/U kelly & rotate 90 RPMs. Circulate m5 BPM @ 300 psi. Work pipe slowly down to 5410'. Circulate bottoms up, 5 BPM @ 350 psi. Work pipe & slowly rotate. Set back kelly & POOH. Pulled 8K over @ 2278', bottom of casing patch. Pulled 5K over while pulling last stand. Stood back 3 1/2" DP. Stand back 61/4" DCs. Gauge String Mills. lower mill 1/8" out of gauge. Leading edge on milling flutes severly worn. Top Mill was in gauge. UD mills & Boot Baskets. Clean boot Baskets. Recovered 5 gals of millings, gravel 5 pcs of metal & small amount of cmt. Clear & clean rig floor. P/U new re-dressed mills. Re-make up BHA as follows: Bull nose, 8 1/5" string Mill, XO, XO, 8.5" String Mill, XO, 2 Boot Baskets, XO, Jars, XO. TL = 47.20'. RIH wI BHA Stacked out @ 127' Had 1-2K drag from 110'. Mill & work thru connection (107'-142') Several times very slowly & run on bad spots. After nearfy 3 hrs still had 2-5K drag when going thru interval. P/U, SIO & Rot wts = 25K. WOB 1-2K, 70-90 RPMs, Torq 1-2K. 5 BPM @ 60 psi. 12:00 - 13:30 1.50 CASRE DFAL INTERV 13:30 - 15:30 2.00 CASRE DFAL INTERV 15:30 - 17:00 1.50 CASRE DFAL INTERV 17:00 - 20:30 3.50 CASRE DFAL INTERV 20:30 - 22:00 DFAL INTERV 22:00 - 23:00 1.00 CASRE DFAL INTERV 23:00 - 00:00 1.00 CASRE DFAL INTERV 9/28/2006 00:00 - 03:30 3.50 CASRE N DFAL INTERV 03:30 - 06:00 2.50 CASRE 06:00 - 09:00 3.00 CASRE 09:00 - 10:00 DFAL INTERV Make connection & work thru 137'-172'. Top 10' Taking some weight. Work interval 137 - 150'. DFAL INTERV Continue to attempt to clean-up tight sections of 9 5/8" Casing with tandem 8.50" String Mills down to 205'. All "worked areas" continue to require weight and rotation to pass through and over-pull to come back through. Discuss plan forward with Anch Eng. DFAL INTERV Set-back Kelly. Trip out with BHA #7 and lay down. Both String Mills are in guage. Boot Baskets contained approx 1 gal Printed: 101212006 10:55:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 of metal cuttings. Clear Floor. Make-up BHA #8 as follows: Bull Nose, XO, Lower 8 5/8" string Mill, XO, XO, Upper 8 518" String Mill, Boot Basket, Boot Basket, XO, Oil Jar, XO, Drill Collars, XO DFAL INTERV RIH to first tight spot at 127'. Pick-up Kelly. PUW/SOW = 25K, 40 - 60 rpms, Pump Rate at 4.0 bpm/50 psi. Continue to ream and mill through tight sections in the 9 5/8" Casing with 8.625" tandem String Mills. Working to pass through 250' - 263' area. DFAL INTERV Con't to mill from 262 to 293'. Bad spot @ 262' Work clear. Dropped to 282' no problem. Mill from 282 to 285' Saw increase in gravel returns for a short time. Milled to 290' Bad spot 285-290', work thru several times. P/U, SIO & Rot Wts = 25K. 5 BPM @ 50 psi. 70-90 RPMs, WOB 1-3K. Torq 2-4K. Flushed flow lines periodically, getting gravel & metal shavings. DFAL INTERV Con't to mill from 290 to 291 '. Fell thru to 293'. Work rough area from 285-291' Overpull went from 8K Down to 2K. Make connection @ 289'. Con't to work thru rough area wi upper mill. . Mill down from 293 to 307' wI no problems. Took weight @ 307' Mill & work pipe from 307 to 311'. P/U, SIO Rot Wt = 25K, 5 BPM @ 50 psi, 70-90 RPMs, WOB 1-4K. Torq 2-4K. No losses noted other than to slop tank. DFAL INTERV Continue reaming and milling. PUW = 25K, SOW = 25K, 40 - 80 rpms, WOB = 1 -4K, AMPs and Torque = unstable, 5.75 bpm/100 psi. 311' - 319', 320'-325'. DFAL INTERV Continue reaming and milling from 325' - 348'. Feel through to 355' (same depth with the tandem 8 1/2" String Mill BHA). Set back Kelly. DFAL INTERV RIH on stands carefully. Tagged up @ 2255'. UD stand # 21. DFAL INTERV P/U kelly break circulation. 6 BPM @ 200 psi. Mill thru casing patch. (Casing patch @ 2238-78') Milled from 2250 to 2278' P/U, SIO Rot Wts= 46K. WOB 2-6K. RPMs 60-80, Torq = 3-4.5K ft-Ibs. DFAL INTERV Milling stalled out v@ 2278'. P/U & had 50K overpull from 2258-2254'. P/U to 2250' Re-ream back thru 2250-2278' interval 2 times. No overpull on third time. Con't to mill from 2278 to 2279'. At 2279 able to mill down wI no resistance. Work back thru whole connection. Had up 10K overpull. Mill & work thru until no overpull. Set back kelly & prep to RIH wI stands. P/U, SIO & Rot Wts = 46K, 6 BPM @ 190 psi. Torq = 3-4.8K ft-Ibs. WOB 2-5K. 70-90 RPMs. RIH wI stands of 3 1/2" DP. No problems in 2954 to 2989' interval. Con't to RIH wI stands. Tagged bottom at 5,408'. Circulate bottoms-up at 6.0 bpm/600 psi. Inspect Derrick. Lub Rig. Trip out with 31/2" Drill Pipe and BHA #8. Saw no over-pull or bobbles on the way out. Lay down BHA #8. String Mills were just sightly under-guaged. Empty Boot Baskets. Recovered pieces and slabs of the Casing Patch. Also recovered -6 gals of mill filings and gravel/stones. DFAL INTERV Clear and clean floor. Make-up BHA #9 as follows: Reverse Circulating Junk Basket w/8 .50" Shoe, XO, XO, Lower 8.50" 11 :00 - 18:00 18:00 - 00:00 9/29/2006 00:00 - 06:00 6.00 CASRE N 06:00 - 12:00 12:00 - 15:00 15:00 - 16:00 16:00 - 00:00 1.00 CASRE 8.00 CASRE 9/30/2006 00:00 - 04:00 04:00 - 06:00 2.00 CASRE DFAL INTERV 06:00 - 07:00 1.00 CASRE DFAL INTERV 07:00 - 09:30 2.50 CASRE DFAL INTERV 09:30 - 10:30 1.00 CASRE DFAL INTERV 10:30·11 :30 Printed: 101212006 10:55:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 String Mill, XO, XO, Upper 8.50" String Mill, XO, Boot Basket, Boot Basket, XO, Oil Jar, 3 ea Drill Collars, XO 11 :30 - 12:30 DFAL INTERV Attempt to Trip in and drift Casing for planned Liner Hanger Packer runs. Unable to get passed 130' (top of bad section of casing. Set-down at same spot as all other previous runs). Attempted several times. Set down 5K. Set down 7K and fell through. 5 - 7 K over-pull to pull out. 12:30 - 14:00 DFAL INTERV Discuss plan forward with anch Eng and Supervisor. Lay down BHA #9. Prep to abort program and TA Well. 14:00 - 18:00 DFAL INTERV Rig-up to handle 3 1/2" Drill Pipe and trip in with same. 18:00 - 00:00 DFAL INTERV Prep to POH & UD 3 1/2" DP. DP plugged Work pipe & attempt to clear DP. NJo Success. POOH & UD wet string of 3 1/2" DP. 10/1/2006 00:00 - 00:30 DFAL INTERV Finish POOH & UD 31/2" DP. Found Jt#s 168, 169, 170 Plugged wI sand & rocks. Clean out same. 00:30 - 02:00 1.50 CASRE DFAL INTERV Clear & clean rig floor. 02:00 - 02:30 0.50 BOPSU DFAL INTERV P/U kelly flush out BOP stack. Set back kelly. 02:30 - 03:00 0.50 BOPSU DFAL INTERV P/U retrieving tool. Pull Wear Bushing. UD retrieving tool. 03:00 - 04:00 1.00 BOPSU DFAL INTERV Change out 3 1/2" x 6" VBRs to 2 7/8" x 5" VBRs. 04:00 - 05:00 1.00 BOPSU DFAL INTERV Install test plug. RILDS. Test plug leaking. Pull test plug. Inspect seal. Seal wom & slightly damaged. 05:00 - 06:00 DFAL INTERV Call for new test plug seal & wait on delivery. 06:00 - 07:00 DFAL INTERV Re-bui/t Test Plug. Test Pipe Rams and door seal at 250/3500 psi. Good test. Rig-down test equipment. Pull test equipment. 07:00 - 07:30 DFAL INTERV Trip in with 2 7/8" Tubing from Derrick. 07:30 - 08:00 DFAL INTERV Pull test plug. Lay down running tool. 08:00 - 10:30 DFAL INTERV RIH wi stands of 2 7/8" tubing from derrick. 10:30 - 13:00 DFAL INTERV Rig-up circulating equip. Displace hole to 9.5 ppg clean brine. Pump 5 BPM @ 750 psi. Pumped total of 450 bbls. 13:00 - 14:00 DFAL INTERV Mix 100 bbls of 9.5 ppg brine. Clear & clean rig floor. Flush drip pan. Jet flow lines. 14:00 - 18:00 DFAL INTERV POOH & UD 2 7/8" tubing. 18:00 - 18:30 DFAL INTERV Service rig. Inspect derrick. 18:30 - 19:30 DFAL INTERV Finish POOH & UD 2 7/8" tubing. 19:30 - 20:00 DFAL INTERV RIH w/1 stand of 3 1/2" DP from derrick. POOH & UD same. P/U 2 * 4 3/4" DCs & BP setting tool. RIH & gauge wellbore. POH. 20:00 - 20:30 DFAL INTERV M/U 9 5/8" CIBP on setting tool. RIH to setting depth of 95'. Put 35 RlH revolutions in string. P/U in 15K incements & shear off CIBP wI 65K. (50K Overpull) SIO wI 5K & insure set. (0 WHP when CIBP was set). 20:30 - 21 :00 DFAL INTERV POOH & UD setting tool. RlU test equip. 21 :00 - 21 :30 DFAL INTERV Close in blind rams. Pressure test CIBP to 1500 psi for 15 min. Good test. Charted same. 21 :30 - 22:30 DFAL INTERV RIH wI to 95' . RlU Hot Oilers. Pressure test lines to 1000 psi. Pump 7 bbls of diesel & freeze protect from 95' to surf. RID Hot Oiler. 22:30 - 23:00 DFAL INTERV POOH & UD 4 3/4" DCs. P/U 2 jts of 2 7/8" tubing & RIH. 23:00 - 00:00 DFAL INTERV Install TWC in hanger. MIU hanger on 2 7/8" tubing. Install 2 dummy penetrators. RIH & land hanger. RILDS. UD landing jt. Pressure test TWC from top & bottom wI 1000 psi for 5 min. Charted same. 101212006 00:00 - 02:00 DFAL INTERV N/D BOPE. Install new kill line. Printed: 10/212006 10:55:34 AM .. ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-14 MPH-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/17/2006 Rig Release: 10/2/2006 Rig Number: Spud Date: 8/15/1997 End: 10/2/2006 101212006 02:00 . 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 05:30 05:30 . 06:00 1.50 WHSUR N 1.00 WHSUR N 0.50 WHSUR N 0.50 WHSUR N 0.50 WHSUR N DFAL INTERV DFAL INTERV DFAL INTERV DFAL INTERV DFAL INTERV N/U adapter flange & tree. Pressure test hanger void & tree to 5000 psi. Tested good. P/U lubricator & pull TWC. Install SPY. UD lubricator. Pressure test BPV to 1000 psi for 5 min. Charted same. Clean cellar. Secure well. RELEASE RIG @ 0600 hrs. Printed: 101212006 10:55:34 AM STATE OF ALASKA f<I:::CEIVED ALASKAL AND GAS CONSERVATION C~ISSION DEC 0 5 2005 REPORT OF SUNDRY WELL OPERATION~OiI&GasConl.Commíss¡on Anchorage 1. Operations Performed: Changeout ESP o Abandon o Suspend o Operation Shutdown o Perforate a Other o Alter Casing a Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program a Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit I 0 Drill Number: BP Exploration (Alaska) Inc. a Development o Exploratory Ø!!'f§Q 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22796-00-00 7. KB Elevation (ft): KBE = 65.70' 9. Well Name and Number: MPH-14 8. Property Designation: 10. Field / Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 6025 feet true vertical 4396 feet Plugs (measured) N/A Effective depth: measured 5919 feet Junk (measured) N/A true vertical 4307 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 112' 112' 1490 470 Surface Intermediate Production 5975' 9-5/8" 6007' 4381' 5750 3090 Liner Çjt;ANNE' . ru: f' ~! Ö 2r1O~ "t...- ...-'I:,~ u .L. v '<1 Perforation Depth MD (ft): 5530' - 5780' Perforation Depth TVD (ft): 3976' - 4190' 2-7/8",6.5# L-80 5441' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" Gravel Pack Assembly 5506' - 5595' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): RBDMS I!JFl DEe t! '005 Treatment description including volumes used and final pressure: 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: a Daily Report of Well Operations o Exploratory a Development o Service a Well Schematic Diagram 16. Well Status after proposed work: a Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true ana correct to tne Dest OT my Knowleage. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A Printed Name Sondra Stewman Title Technical Assistant ~ Prepared By Name/Number: i~, )~" ~ ':\ p~?nr 564-4750 Date la 'OZDSSondra Stewman, 564-4750 SI ature ....., ..vv--""':"" . .. I Form 10-404 Revised 04/2004 lJ ~~ \ lJ ¡¡\~ 1-\ L Submit Original Only Tree: Cameron 2 9/16", _ Wellhead: FMC 11" x 11", Gen. 5 w/ 11" x 2-7/8" FMC Tbg. Hnr. w/ NSCT threads top, 2-7/8" 8rd btm. 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 112' I KOP @ 300' to 3,400' Max. hole angle = 66 deg. Hole angle thru' perfs = 30 deg. 2-7/8' 6.5 ppf, L-80 EUE tubing {cap. = 0.00579 bpf, drift = 2.347' 9 5/8' 40 ppf, L-80, BTC production csg. ( drift 10 = 8.835", cap. = 0.0758 bpf) Intake TVO = 3870' PumpMate TVO = 3894' Mid-perf TVO = 4083' Mid-perf MO = 5655' PBTO TVO = 4290' TVO PBTO MO = 5919' Stimulation Summary 07/31/98 N M# of CL coated with PL placed behind screens 07/29/98 OA98 M# of PropLok coated 16/20 CarboLite behind pipe 07/27/98 OB 76.8M# of PropLok coated 16/20 CL behind pipe - re-frac 07/26/98 OB 18.4M# of PropLok coated 16/20 CL behind pipe - early shutdow Perforation Summary Ref loa:Scerrv MWD 8/18/97 Size SPF Interval (TVD) 4.5" 4 7" 4 7" 4 3976' -4010' 4110'-4132' 4171 '-4190' 5530'-5570' 5686'-5712' 5760' -5780' DATE 8-31-97 8/04/98 2/18/99 3/09/01 12/5/03 11/6/05 REV. BY MOO M. Linder MOO B. Hasebe Lee Hulme Lee Hulme COMMENTS 9-5/8" Cased Hole Completion 22E Initial com let ion 4-ES W/L Retrieviable PC completion 4 ES ESP completion 4 ES ESP changeout 4ES ESP changeout 4ES . KB Elev. = 65.7: (N 22E) . GL Elev. = 36.6 RT To Tbg. Spool = {N 22E Camco 2-7/8" x 1" KBMM GLM 1140' Est. top of cmt. Howco 9 5/8" "ES" Cementer 9-5/8" Casina Patch w/ 8.125" drift ID set at 2248'-2278'. 2204' 2270' Centrilift heat trace 3500' Camco 2-7/8" x 1" KBMM GLM I 5232' 2-7/8" XN nipple 2.250" 10 5375' Centrilift ESP 146 Stage 400P6 PM SSD FER 5392' 400 series Gas Separator 5407' GRSFXTßARHG Centrilift Tandem seal section I 5412' 513 series GSB3 DB UT/LT AB/HSN PFSA/FSA CL5 Centrilift KMH Motor 5425' 95 hp, 1330 v / 44 amps. PumpMate and 6 Fin 5435' Centralizer 9-5/8" HES 'BWO' perm. Pkr. 5506' 4-1/2" 125 Micron Poroplus 5527' screens assembly (61' long 9-5/8" HES 'BWD' sump pkr. 5589' 4-1/2" XN nipple 3.725" 10 5595' .. TO tagged during RWO 11-6/05 @ 5782' MD .. 9 5/8' landing collar (PBTO) 5,919' 5,963' 6,007 9 5/8' float collar 9 5/8' float shoe MILNE POINT UNIT WELL No: H-14 API: 50-029-22796 BP EXPLORATION (AK) /~ Page 1 of 2 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/4/2005 11/5/2005 MPH-14 MPH-14 WORKOVER Start: 11/2/2005 NABORS ALASKA DRILLING I Rig Release: 11/7/2005 NABORS 4ES Rig Number: 4ES From - To Hours Task !?Od,e I N~T_I P~~se 06:00 - 12:00 6.00 MOB P PRE 12:00 - 13:30 1.50 RIGU P PRE 13:30 - 15:30 2.00 RIGU P PRE 15:30 - 17:30 2.00 RIGU P DECOMP 17:30 - 18:30 18:30 - 19:00 19:00 - 20:30 DECOMP DECOMP DECOMP 1.00 WHSUR P 0.50 KILL 1.50 KILL P 20:30 - 00:00 DECOMP 3.50 KILL P 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:30 02:30 - 05:30 05:30 - 17:00 1.00 KILL P 0.50 WHSUR P 1.00 WHSUR P 3.00 BOPSU P 11.50 BOPSU P DECOMP DECOMP DECOMP DECOMP DECOMP 17:00 - 18:00 1.00 WHSUR P DECOMP 18:00 - 19:00 1.00 WHSUR P DECOMP 19:00 - 20:00 1.00 PULL P DECOMP 20:00 - 00:00 4.00 PULL P DECOMP 11/6/2005 00:00 - 01 :00 1.00 PULL P DECOMP 01 :00 - 01 :30 0.50 PULL P DECOMP 01 :30 - 03:00 1.50 PULL P DECOMP 03:00 - 05:00 2.00 PULL P DECOMP 05:00 - 06:00 1.00 PULL P DECOMP 06:00 - 07:00 1.00 PULL P DECOMP 07:00 - 09:00 2.00 EVAL P DECOMP 09:00 - 10:30 1.50 EVAL P DECOMP 10:30 - 12:30 2.00 EVAL P DECOMP 12:30 - 13:00 0.50 EVAL P DECOMP 13:00 - 14:00 1.00 EVAL P DECOMP 14:00 - 16:00 2.00 RUNCO RUNCMP 16:00 - 18:00 2.00 RUNCO RUNCMP 18:00 - 19:00 1.00 RUNCO RUNCMP Spud Date: 8/15/1997 End: 11/7/2005 Description of Operations __0. . ......____.__._m .--.. Move Rig and Modules from MPK-02 to MPH-14. Spot in sub over well. spot pits, pipe shed & camp. Raise & scope up derrick. Rig up equip to pits R/U lines to tiger tank & wellhead. ACCEPTED RIG @ 1600 hrs. P/U lubricator & pull BPV. UD lubricator. Hold Pre-spud & PJSM. Review kill operation. Take on 120 degree seawater to kill well. Test kill lines to 3500 psi. Open well. SITP = 310 psi. SICP = 410 psi. Circulate & kill well wi 120 degree seawater. Blow down annulus. Pump 5 BPM @ 970 psi. Started to get returns after 100 bbls were pumped. Con't to pump a total of 620 bbls when well cleaned up. SID & open well into pits. Circulated additional 100 bbls. Losses were 42 BPH. Recovered 345 bbls, 95% oil. Finish circulating well. SID & monitor well. Well Dead. Set TWC & test same to 1000 psi, Ok. Bleed void. NID tree & adapter flange. N/U BOPE. Begin to test BOPE. Unable to continue due to a leak somewhere. Inspect BOPE Stack and Choke Manifold valves. Pick-up Lubricator and pull TWC. Inspect TWC and completly re-build. Set TWC. Resume BOP Test. Still have a leak but not as bad. Trouble shoot Test Pump Plumbing. Found two 1/4 turn vavles leaking. Replace valves. Pressures hold OK now. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Chuck Sheve wi AOGCC. P/U lubricator & pull TWC. UD lubricator & TWC. M/U landing jt into hanger. BOLDS. Pull hanger to floor wi 57K. UD landing jt & hanger. Disconnect & cut cables. Pull ESP cable & Heat Trace cables over sheave & attach to spools. POOH 2 7/8" tubing wi Heat Trace Con't to POOH w/2 7/8" tubing wI Heat Trace. Clear & clean rig floor. Recovered 10' pup, 36 stands, 1 GLM & 1 single. Pulled Heat trace cable over spool & wrapped up in reel. Con't To POOH wi ESP & 2 7/8" tubing. Inspect & break down ESP. Clear & clean rig floor. R/U to P/U 2 7/8" PAC DP. Lub rig. Inspect Derrick and Blocks. Make-up 2 7/8" PAC Mule Shoe. Single in with 20 Jt of 2 7/8" PAC Drill Pipe from Pipe shed. Make up XO. RIH with 2 7/8" Tubing from Derrick (164 jts). Tagged top of Fill at 5,782' (-2-ft below bottom Perforation). TOOH and stand back 2 7/8" Tubing in Derrick. Single down the 2 7/8" PAC Drill Pipe in Pipe Shed. Clean and Clean Rig floor. Pick-up inspect and service new ESP Assembly. RIH wi ESP on 2 7/8" tubing to 1800'. Check E-Line & pump thru ESP. Pull Heat Trace over sheave. M/U flat guards for running Heat Printed: 11/11/2005 2.11.05 PM BP EXPLORATION Operations Summary Report Page 2 of 2 Legal Well Name: MPH-14 Common Well Name: MPH-14 Event Name: WORKOVER Start: 11/2/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/7/2005 Rig Name: NABORS 4ES Rig Number: 4ES Date ,~rom - To I H~ur~,:ask Icod~' N~T 1 P_ha,~e I.. Descripti~_n of Op~ration~_, 1116/2005 18:00 - 19:00 1.00 RUNCO RUNCMP Trace.lnstall Flat guards & bands. 19:00 - 00:00 5.00 RUNCO RUNCMP Con't to RIH w/2 7/8" Heat Traced ESP completion. Start HT on Jt. 109. Continue to RIH w/2 7/8" ESP/HT Completion. Pump thru ESP & check cable every 3 stands. Make-up Tubing Hanger. Install ESP and Heat Trace Penetrators. Splice in ESP and Heat Trace Cable Connectors. Check Cables. Finish running 2 7/8" ESP/HT Completion as follows: ESP Assy, 2 Pup Jts, XN-Nipple, 4 Jts Tbg, GLM Assy w/Dummie, 161 Jts Tbg, GLM Assy w/DSOV, 3 Jts Tbg, 2 Pup Jts, Tbg Hanger. Heat Trace -3,500' started on Jt 109. Land Tubing Hanger. RILDS. Test. N/D BOPE. N/U X-mas tree. Test ESP cable & Heat Trace cable. Test Tree to 5000 psi, Ok. P/U lubricator, pull TWC & install BPV. LID lubricator. Clear & clean cellar. Secure well. ...RELEASE RIG @ 1800 hrs.... Spud Date: 8/15/1997 End: 11/7/2005 11/7/2005 00:00 . 10:00 10.00 RUNCMP 10:00 - 10:30 0.50 RUNCMP 10:30 . 13:00 2.50 RUNCMP 13:00 - 14:00 1.00 RUNCMP 14:00 - 15:30 15:30 - 17:00 17:00 . 17:30 17:30 - 18:00 1.50 BOPSU P 1.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP Printed: 11/11/20052.11.05 PM '., RECEIVED 1· STATE OF ALASKA ) ALA~,) OIL AND GAS CONSERVATION COMMI~SION OCT 1 2 Z005 REPORT OF SUNDRY WELL OPERATION§~ska Oil & Gas Cons. Commission 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate 0 Other bhhora 8 Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension"O' g Change Approved Program D Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development :r;?: Exploratory I] 197-1500 3. Address: P.O. Box 196612 Stratigraphic r Service r 6. API Number: Anchorage, AK 99519-6612 50-029-22796-00-00 7. KB Elevation (ft): 9. Well Name and Number: . ~~', ~ 65.7 KB MPH-14 ADL-025518 11. Present Well Condition Summary: 10. Field/Pool(s): MILNE POINT Field/ SCHRADER BLFF OIL Pool 8. Property Designation: Total Depth measured 6025 feet true vertical 4396.37 feet Effective Depth measured 5919 feet true vertical 4306.63 feet Casing Length Size MD Conductor 79 20# 91.1 H-40 33 - 112 Production 5975 9-5/8" 40# L-80 32 - 6007 Plugs (measured) None Junk (measured) None TVD 33 - 112 32 - 4381 .13 Burst 1530 5750 Collapse 520 3090 SCANNEf) INO~ 0 ft 2005 Perforation depth: Measured depth: 5530 - 5570 True Vertical depth: 3975.69 - 4010.16 5686 - 5712 5760 - 5780 4172.33 - 4189.26 4109.45 - 4131.59 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 20 - 5436 Packers and SSSV (type and measured depth) 9-5/8" X 2-7/8" HES BWB Perm Packer & Gravel Pack Assy 5506-5595 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl 0 CT 1 3 2005 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 000 000 15. Well Class after Droposed work: Exploratoryr Development ¡;¡ 16. Well Status after proposed work: Oil R Gas r WAG r Tubing pressure 298 350 13. Service r ~ GINJ r WINJ r 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 Sharmaine Vestal Printed Name Shar~aine ve. S,tal _. J Signat ,~ Title Data Mgmt Engr Phone 564-4424 Date 10/12/2005 " Form 10-404 Revised 04/2004 \..:~' '.¿ ~......"n Submit Original Only ) ') MPH-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 9/17/2005 T/I=300/350. Spear into tbg wi 5 bbls neet meth followed by 9 bbls 7.5% DAD acid. Pump 14 bbls diesel to spot acid on pump. Let soak for 10 minutes. Standby for DSO to run ESP. The ESP will not lift fluid to surface. Possibility of a twisted shaft. The amps wouldn't increase any higher then 23 amps at 50 Hz. Pump 6 bbls diesel to push acid into formation. Fwp=350/350. FLUIDS PUMPED BBLS 9 7.5% DAD Acid 8 Neat Meth 20 Diesel 37 TOTAL (. STATE OF ALASKA t . ALASKA \..IlL AND GAS CONSERVATION COI"""IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver a Other 0 Alter Casing a Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension Chan eout ESP 0 Chanç¡e Approved Proç¡ram a Pull Tubinç¡ 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 1m Development 0 Exploratol) 197-150 3. Address: 0 Stratigraphic Test 0 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22796-00-00 7. KB Elevation (ft): KBE = 65 70' 9. Well Name and Number: , MPH-14 8. Property Designation: 10, Field 1 Pool(s): ADL 025906 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 6025 feet true vertical 4396 feet Plugs (measured) N/A Effective depth: measured 5919 feet Junk (measured) N/A true vertical 4307 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 112' 112' Surface Intermediate Production 5975' 9-5/8" 6007' 4381' 5750 3090 Liner Perforation Depth MD (ft): 5530' - 5780' Perforation Depth TVD (ft): 3976' - 4190' Tubing Size (size. grade, and measured depth): 2-7/8".6.5# L-80 5440' Packers and SSSV (type and measured depth): 9-5/8" Gravel Pack Assembly R E C El";Ë55ö' 12. Stimulation or cement squeeze summary: N/A ] 2004 Intervals treated (measured): JAN. 6 Treatment description including volumes used and final pressure: Alaska Oil & Gas Cons. Commission Anchorage 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 224 86 72 290 Subsequent to operation: 244 11 84 275 14, Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: IDI 0 .1 R rt f W II 0 t' 0 Exploratory iii Development 0 Service IaI al y epo 0 e pera Ions IDI W II S h t" D. 16. Well Status after proposed work: IaI e c ema IC lag ram iii Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: N/A Printed Name Sondra Stewman Title Technical Assistant r I D t .. Ii j Prepared By Name/Number: Sig ture õ. Date - '''t''' ondra Stewman, 564-4750 Form 10-404 Revised 12/2. . -, ß A tJ ') V 160~ ~)GjQ~~~~ft ~~AN ~~ @ 200¿l BfL ,,"'11 ({.r; Tree: Cameron 2 9/16", ~ M P U H 14 of (B Elev. = 65.7 ' (N 22E) Wellhead: FMC 11" x 11" 5M, - Orig. GL Elev. = 36.6' Gen. 5 wi 11" x 2-7/8" FMC Tbg. RT To Tbg. Spool = (N 22E) Hnr. wi NSCT threads top, 2-7/8" 8rd btm. 2.5" CIW H BPV rofile Cameo 2-7/8" x 1" ~ P KBMM GLM 20" 91.1 ppf, H-40 I 112' I I I Est. top of cmt. 2204' KOP @ 300' to 3,400' Howco 9 5/8" liES" Cementer I 2270' I Max. hole angle = 66 deg. 9-5/8" Casina Patch wI Hole angle thru' perfs = 30 deg. 8.125" drift ID set at 2248'-2278'. Centrilift heat trace I 3500' I 2-7/8' 6.5 ppf, L-80 EUE tubing (cap. = 0.00579 bpf, drift = 2.347" 9 5/8' 40 ppf, L-80, BTC production csg. ( drift 10 = 8.835", cap. = 0.0758 bpf ) Cameo 2-7/8" x 1" I 5327' I KBMM GLM 2-7/8" XN nipple 2.205" 10 I 5374' I Intake TVO = 3870' PumpMate TVO = 3894' Mid-perf TVO = 4083' Centrilift double tapered pump I 'I Mid-perf MO = 5655' 159 Stage GC1150 GPMTARM 1:2 5390 PBTO TVO = 4290' TVO 400 ' (' S ' .8om;s :;¡HS opamtor I I PBTO MD = 5919' GHSXTBAHi-H3 5408' Centrilift Tandem seal section I 5413' I 513 series GSB3 DB UT/LT IL H6 AFLAS/HSN Centrilift KMH 562 series, I 5427' I Stimulation Summary 70 hp, 1236 v / 34 amps, 07/31/98 N M# of CL coated with PL . I' I I d b h. d PumpMate and 6 Fin ' S4es.: pace e In screens I 07/29/98 OA98 M# of PropLok coated Centralizer SL.tLlO 16/20 Carbo Lite behind pipe 9-5/8" HES 'BWO' perm. Pkr. I 5506' I 07/27/98 OB:6.8~# of PropLok coated 4-1/2" 125 Micron Poroplus , 16/20 CL behind pipe - re-frac bl (.61' I . I 5527 I screens assem y ong 07/26/98 OB 18.4M# of PropLok coated ' I I 16/20 CL behind pipe - early shutdowr 9-5/8" HES 'BWO' sump pkr. 5589' . 4-1/2" XN nipple 3.725" 10 I 5595' I 4.5" 4 5530'-5570' 3976'-4010' 7" 4 5686'-5712" 4110'-4132' I ' I I 4171' 4190' 9 5/8 landing collar (PBTO) 5 919' 7" 4 5760'-5780' - , 9 5/8' float collar I 5,963' I 9 5/8' float shoe I 6,007' I DATE EV. BY COMMENTS 8-31-97 MDq 9-5/8" Cased Hole Completion 22E MILNE POINT UNIT 8/04/98 M. Linder Initial com letion 4-ES WELL No : H-14 2/18/99 MOO W/L Retrieviable PC completion 4 ES API: 50-029-22796 3/09/01 B. Hasebe ESP completion 4 ES 12/5/03 Lee Hulme ESP changeout 4ES BP EXPLORATION (AK) , ( ( BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: MPH-14 Common Well Name: MPH-14 Spud Date: 8/15/1997 Event Name: WORKOVER Start: 12/2/2003 End: 12/5/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/5/2003 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/2/2003 06:00 - 09:00 3.00 MOB P PRE RDMO from MPH-05. Move Rig and Modules to Well MPH-14. 09:00 - 13:00 4.00 RIGU P PRE Spot Sub Base over Well. Spot Pits, Pipe Shed, Camp. Raise and scope derrick. 13:00 - 14:00 1.00 RIGU P PRE Rig up lines to tree. Lay lines to Tiger Tank. Take on first load of 140 deg F. Sea Water in Rig Pits, Accept Rig at 13:00 hrs. 14:00 - 14:30 0.50 WHSUR P DECOMP M/U lubricator & pull BPV. LID same. 14:30 - 15:30 1,00 RIGU P DECOMP Take on heated seawater. Blow lines. Thaw out cementing line. 15:30 -16:00 0.50 KILL P DECOMP Hold PJSM & Pre-spud meeting wI crew. 16:00 - 18:00 2.00 KILL P DECOMP Test lines to 3500 psi. Kill well. Pumped 3 (+) Tbg Vols had no returns to surface. 18:00 - 20:30 2,50 KILL P DECOMP Con't to bullhead down annulus. 3 BPM @ 900 psi. Pumped a total of 370 Bbls. SID, observe well. SIP 520 psi. Formation supercharged. Bleed off & flow back 43 bbls, Returns are 100% crude wI gas. 20:30 - 23:00 2,50 KILL P DECOMP Circulate well down tubing. 4 BPM @ 500 psi, 3 BPM @ 400 psi, 2 BPM @ 225 psi. Circulate tubing & annulus volume. 23:00 - 00:00 1.00 KILL P DECOMP Wait on heated seawater. Remove ESP sheave. Hang double sheave, elephant trunck & drain line hose. 12/3/2003 00:00 - 01 :00 1.00 KILL P DECOMP Finish hanging sheave & elephant trunk. Hook up drain hose. 01 :00 - 02:00 1.00 KILL P DECOMP Wait on heated seawater. Take on seawater. 02:00 - 04:00 2.00 KILL P DECOMP SITP 0 psi, SI annulus pressure 110 psi. Con't to circulate well, 3 BPM @ 400 psi. Circulated a total of 345 bbls to tiger tank. Fluid cleaning up. Circulate additional 45 bbls into pits. SID & monitor well, well dead. 04:00 - 04:30 0.50 WHSUR P DECOMP Install TWC. RID kill lines. 04:30 - 06:00 1.50 WHSUR P DECOMP NID X-mas tree. 06:00 - 08:00 2.00 BOPSU~ P DECOMP N/U BOPE. 08:00 - 09:00 1.00 BOPSU~ P DECOMP Rig up test equipment. 09:00 - 12:30 3.50 BOPSU~ P DECOMP Perform BOPE Test as per BP/AOGCC requirements. Test at 250/3,00 psi. state's right to witness test waived by J. Jones. 12:30 - 13:00 0.50 BOPSU~ P DECOMP Rig down test equipment. Blow down lines. 13:00 - 13:30 0.50 BOPSU~ P DECOMP Pick-up Lubricator. Pull TWC. Lay down same, 13:30 - 14:30 1.00 PULL P DECOMP Pick-up Landing Joint. BOLDS. Pull Hanger to Floor (50K). No problems. 14:30 - 18:00 3.50 PULL P DECOMP Pull ESP and Heat Trace Cables over Sheaves. Start POOH with 2 7/8" Tbg, ESP/HT Cables, and ESP Assembly. 18:00 - 19:00 1.00 PULL P DECOMP Con't to pull out of hole w/ESP/HT cables to 2950'. Spool up heat Trace. 19:00 - 20:30 1.50 PULL P DECOMP Con't to POOH w/2 7/8" tbg to ESP. Stand back 54 stands of tbg, 20:30 - 22:30 2.00 PULL P DECOMP LID ESP, Had sand packed discharge head & upper pump. 22:30 - 23:30 1.00 PULL P DECOMP Unpack new ESP. Load out old ESP, LID elephant trunck & drain hose. Change out spools. 23:30 - 00:00 0.50 PULL P DECOMP Clear & clean rig floor. 12/4/2003 00:00 - 00:30 0.50 PULL P DECOMP Clear & clean rig floor. 00:30 - 01 :30 1.00 RUNCO~ IP COMP R/U to run new ESP & heat trace. Pull cables over double sheave. 01 :30 - 03:00 1.50 RUNCO~ IP COMP M/U & service new ESP. Test same, 03:00 - 04:30 1.50 RUNCO~ IP COMP RIH wI ESP on 2 7/8" tbg to 1990'. 04:30 - 05:00 0.50 RUNCO~ IP COMP Test ESP cable. R/U to run heat trace. Start Centrilift Heat Trace Cable at - 3,500-ft. 05:00 - 11 :00 6,00 RUNCO~ P COMP Con't to RIH wI ESP & heat trace on 2 7/8" tbg. 11 :00 - 13:30 2.50 RUNCO~ P COMP Stop to make mid-cable splice. Splice was made so that Printed: 12/8/2003 9:00:28 AM . ( ( BP EXPLORATION Page 2 of2 Operations Summary Report Legal Well Name: MPH-14 Common Well Name: MPH-14 Spud Date: 8/15/1997 Event Name: WORKOVER Start: 12/2/2003 End: 12/5/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/5/2003 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/4/2003 11 :00 - 13:30 2.50 RUNCO~ Ip COMP Centrilift could get two "short" Cable Reels out of their invintory. 13:30 - 19:30 6.00 RUNCO~ Ip COMP Continue RIH with ESP Assy, ESP Cable, and Heat Trace Cable on 2 7/8" Tbg. Ran 168 jts, 2 GLMs, "XN" nipple & ESP. P/U wt = 57K, S/O wt = 36K. 19:30 - 20:00 0.50 RUNCO~ Ip COMP M/U landing jt & hanger. Install penetrator in hanger. 20:00 - 22:30 2.50 RUNCO~ Ip COMP M/U heat trace splice, plug into penetrator & test, OK. 22:30 - 00:00 1.50 RUNCO~ (P COMP M/U ESP power cable splice. Plug into penetrator & test, OK. 12/5/2003 00:00 - 00:30 0.50 RUNCO~~ COMP Land 27/8" ESP completion @ 5440', RILDS. P/U wt = 57K, S/O wt = 36K. Top pump @ 5389,86', "XN" nipple @ 5374.40', 27/8" x 1" GLM wI dummy @ 5326.47', 27/8" x 1" GLM wI DVSOV @ 139.93'. 32 LaSalle clamps, 5 protectolizers, 3 Flat Guards, 1742 Flat Bans wi Heat Trace, 551 6' Guards, 284' Guards, 31 2' Guards. 00:30 - 01 :00 0.50 RUNCO~ COMP Set TWC & test to 2500 psi, Ok. Drain BOP stack & Blow down hard lines. 01 :00 - 02:30 1.50 BOPSUF CaMP N/D BOPE. 02:30 - 04:30 2.00 WHSUR COMP N/U adapter flange & tree, Test tree & adapter to 5000 psi for 10 min. Tested good. 04:30 - 05:30 1.00 WHSUR CaMP M/U lubricator. Pull TWC & install BPV. 05:30 - 06:00 0.50 MOB COMP Clean cellar. Secure well. RELEASE RIG @ 0600 hrs. Printed: 12/8/2003 9:00:28 AM STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COM~Vr¢~---~. -SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 65.70' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Maine Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2949' NSL, 4133' WEL, SEC. 34, T13N, R10E, UM MPH-14 At top of productive interval 9. Permit Number / Approval No. 197-150 3030' NSL, 907' WEL, SEC. 34, T13N, R10E, UM 10. APl Number At effective depth 50-029-22796 2890' NSL, 754' WEL, SEC. 34, T13N, R10E, UM 11. Field and Pool At total depth Maine Point Unit / Schrader Bluff 2854' NSL, 713' WEL, SEC. 34, T13N, R10E, UM 12. Present well condition summary Total depth: measured 6025 feet Plugs (measured) true vertical 4396 feet Effective depth: measured 5919 feet Junk (measured) true vertical 4307 feet Casing Length Size Cemented MD TVD Structural Conductor 79' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5975' 9-5/8" 1670 sx PF E, 855 sx G, 50 sx PFC 6007' 4381' Intermediate Production Liner Perforation depth: measured 5530' - 5570', 5686' - 5712', 5760' - 5780' ~ ~, ~__~¢ true vertical 3976'-4010', 4110'-4132', 4171'-4190' ~'PJ~ Tubing (size, grade, and measured depth) 2-7/8"m 6.5#, L-80 to 5436' Alaska Oii & Gas Cons. Comrr~issio.~ Anchorage Packers and SSSV (type and measured depth) 9-5/8" Gravel Pack Assembly 5506' - 5595' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~9~d ra Stew~-'~-_~~~..._._. Title Technical Assistant Date -,.._ ..,.~, _ Prepared By Name/Number'. Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 ¢lpiRIKIAI Submit In Duplicate~ Tree: Cameron29/16", 5M MPU H 14 Orig. KBEIev.=65.7'(N22E) Wellhead: FMC 11" x 11" 5M, " Orig. GL Bev. = 36.6' Gen. 5 w/ 11" x 2-7/8" FMC Tbg. RT To Tbg. Spool = (N 22E) Hnr. w/ NSCT threads top, 2-7/8" 8rd btm. 2.5" CIW H BPV profile j ~ Camco 2-7/8" x 1" I 134' 20" 91.1ppf, H-40 I 112' I KBMMGLM Est. top of cmt. I 2204' KOP@300'to3,400' ~ [i) Howco95/8""ES"Oementer I 2270' Max. hole angle = 66 deg. 9-5/8" Casing Patch w/ Hole angle thru' perfs = 30 deg. 8.125" drift ID set at 2248'-2278'. Raychem heat trace 2300' 2-7/8" 6.5 ppf, L-80 EUE tubing (cap. = 0.00579 bpf, drift = 2.347") 9 5/8" 40 ppf, L-80, BTC production csg. ( drift ID = 8.835", cap. = 0.0758 bpf ) Camco 2-7/8" x 1" I 5,321' KBMM GLM 2-7/8" xn nipple 2.205" ID I 5,369' Centrilift double tapered pump 56 Stage GCl150 5,384' 142 Stage FC950 Intake TVD = 3864' 513 series Tandem Gas PHD 'I'VD = 3889' Separator GRSXTBARH6 Mid-perf TVD = 4083' Centrilift Tandem seal section I 5,410' MId-perf MD = 5655' 513 series GSB3 DB UT/LT IL , PBTD 'I'VD = 4290' TVD AFLAS/HSN PBTD MD = 5919' Centrilift KMH 562 series, I 5,422' Stimulation Summary 114 bp, 2330 v / 30 amps. 07/31/98 N M# of CL coated with PL Standard PHD and 6 Fin behind screens Centralizer 07/29/98 OA 98 M# of PropLok coated 16/20 CarboLite behind pipe ~ ~ 9-5/8" HES 'BWD' perm. Pkr. 07/26/98 OB 18.4M# of PropLok coated=,,,:::: I :~::.-..:.~ screens assembly (61' long) 16/20 CE behind pipe- early shutdown :?:::::::::::?:?::::::: 1~! 9-5/8" HES 'BWD' sump pkr. Perforation Summary ~~ 4-1/2" XN nipple 3.725" ID Ref log:Sperry MWD 8/18/97 Size SPF Interval (TVD) 4.5"7 4 5530'-5570' 3976'-4010' 7" 4 5760'-5780' 4171'-4190' i 9 5/8" landing collar (PBTD) 9 5/8" float collar I 5,963' 9 5/8" float shoe I 6,007' DATE REV. BY COMMENTS MILNE POINT UNIT 8-31-97 MDC 9-5/8" Cased Hole Completion 22E WELL No: H-14 8/04/98 M. Linder Initial completion 4-ES APl: 50-029-22796 2/18/99 MDC W/L Retrieviable PC completion 4 ES 3/09/01 B. Hasebe ESP completion 4 ES BP EXPLORATION (AK) mmarY Report Legal Well Name: MPH-14 Common Well Name: MPH-14 Spud Date: 8/15/1997 Event Name: REPAIR Start: 3/3/2001 End: 3/7/2001 Contractor Name: NABORS Rig Release: 3/7/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: 4 ~ Hours r TasK cSoUdbe ~hase~'~ ;~: i:: ~ ;:: of Operations 3/3/2001 11:00 - 22:00 11.00 RIGU PRE RIG DOWN FROM MPE-08 & MOVE TO MPH-14 & SET IN RIG & RIG UP & SCOPE DERRICK & ALL ACCESSORIES & SAFE OUT. 22:00 - 00:00 2.00 RIGU PRE RIG TIGER TANK & LINES TO TREE & TAKE ON 8.5 PPG. S~WATER. 3M/2001 00:00 - 02:00 2.00 KILL DECOMP RIG LUBRICATOR & PULL ~C 02:00 - 02:30 0.50 KILL DECOMP TEST LINES TO TREE TO 3500 PSI. 02:30 - 11:30 9.00 KILL DECOMP CIRC WELL BORE TO CLN-INFLUX FROM WELL BORE.(CONTINUIOUS ClRC TO GET H~ OIL FROM WELL BORE DUE TO HOT WATER HEATS OIL NEXT TO TBG. AND FLUID FORMS A ANNULUS NEXT TO HOT TBG. AS FRICTION PRESSURE IS LESS WHERE OIL IS H~TED FOR FLUID TO T~VEL UPWARD. 11:30 - 12:00 0.50 WHSUR DECOMP SET~C.& TEST SAME. 12:00- 13:00 1.00 WHSUR DECOMP NIPPLE DOWN TEREE 13:00- 15:00 2.00 BOPSUE DECOMP NIPPLE UP BOP 15:00 - 16:00 1.00 BOPSUE DECOMP BODY TEST BOP TO 250 LOW & 3500 HIGH (TEST WAIVED BY JOHN CRISP WITH AOGC. 16:00 - 17:00 1.00 BOPSUR DECOMP RIG LUBRICATOR & PULL ~C [ 17:00 - 19:00 2.00 PULL DECOMP PULL HANGER TO FLOOR & TEST ESP CABLE & HEAT T~CE AND ~Y DN HANGER (HEAT T~CE TESTED OK.) 19:00 - 00:00 5.00 PULL DECOMP POOH ~YING DN 3.5" 8RD EUE TBG. & REMOVING HEAT T~CE GUARDS ETC. 3/5/2001 00:00 - 07:30 7.50 PULL DECOMP CONTINUE TO ~Y DN ESP COUPLETION LOST APP. - OR 6-BANDS. 13:30 - 16:00 2.50 EVAL 'OTHR COMP RIG UP & RIH WITH 8" TAPERED SWEDGE ON TBG. & WAS UNABLE TO GET PASS 2265' 16:00 - 17:00 1.00 EVAL OTHR COMP POOH & ~Y DN SWEDGE 17:00 - 19:30 2.50 EVAL FILL COMP ~KE UP BHA ~ 2 6" TAPERED MILL +XO +8-1/8" CSG. POLISHING MILL +BUMPER SUB +JARS+3-DC. 19:30 - 21:30 2.00 EVAL FILL COMP RIH WITH BHA ~2 21:30 - 22:30 1.00 EVAL FILL COMP P/U KELLY & POLISH CSG. PATCH F/2263' TO 2291' MADE SERVE~L PASSES WITH POLISHING MILL UNTIL IT WOULD PASS THROUGH PATCH WITH NO RESISTANCE. 22:30- 23:30 1.00 EVAL FILL COMP POOH ~YING DN 3.5" DP. 23:30 - 00:00 0.50 EVAL FILL COMP ~Y DN BHA ~2 3/6/2001 00:00 - 01:00 1.00 EVAL REME COMP ~YDN BHA ~ 3 01:00 - 02:00 1.00 EVAL COMP PICK UP 2-7/8" TBG. & STAND BACK IN DERRICK. 02:00 - 05:00 3.00 EVAL COMP ~KE UP ESP ASSY. 05:00 - 08:00 3.00 EVAL COMP TIH with 2 7/8" ESP Completion to 2,400' 08:00 - 10:00 2.00 EVAL COMP Rig up to Run heat tra~ 10:00 - 21:00 11.00 EVAL COMP Run Jn hole with 2 7/8" ESP - Heat trace completion 21:00 - 22:30 1.50 EVAL COMP 8pa~ out Heat trace P/U landing joint. M/U hanger and test heat tra~ 22:30 - 00:00 1.50 EVAL COMP install penetrator and a~ach field connector and test 3/7/2001 00:00 - 01:00 1.00 RUNOO~ COMP ~ND HANGER & RILDS & SET ~O & TEST TO 3500 PSI. 01:00 - 02:30 1.50 BOPSUF COMP NIPPLE DOWN BOP'S 02:30 - 04:00 1.50 WHSUR COMP NIPPLE UP TREE & TEST TO 5000 PSI. 04:00 - 06:00 2.00 WHSUR COMP PULL ~C & RUN BPV & SECURE TREE AREA & RELEASE RIG ~ 0600 HRS. 3/7/2001 I Printed: 4/12/2001 9:26:14 AM i ummary Report Legal Well Name: MPH-14 Common Well Name: MPH-14 Spud Date: 8/15/1997 Event Name: REPAIR Start: 3/3/2001 End: 3/7/2001 Contractor Name: NABORS Rig Release: 3/7/2001 Group: SLIC Rig Name: NABORS 4ES Rig Number: 4 r :~From- To ~ours ~sk cSoUdbe ~Phase ~ii~: :::::] ~-] ~: ]i~ Description of Operations 3/5/2001 07:30 - 13:30 6.00 CLEAN JUNK COMP RIG HES SLIGKLINE & RUN 8.35" GR/JB TO 2263' AND STACKED OUT. REC. 1-BAND & RE-RUN TO 2263' & STACKED OUT. NO REC. RUN #3 6.055 GPJJ TO 2263' & STACKED OUT NO REC. POOH & LAY DN & RIG DN HES. Printed: 4/12/2001 9:26:14 AM Well Compliance Report File on Left side of folder 197-150-0 MILNE POINT UNIT SB H-14 50- 029-22796-00 BP EXPLORATION (ALASK MD 06025 04396 Completion Date: 8 Completed Status: 1-OIL Current: _ _ _ Microfilm Roll / - Roll 2 / Name D 8773 1 SPERRY MPT/GR/EWR4 OH 11/4/98 L DGR/EWR4-MD ~ 112-6025 ~/i~/c~'~7 OH 11,11,98 L DGR/EWR4-TVD t~~-- 112-4396 q~ OH 11/11/98 L PACKER ~AL 4550-5600 [ /~..,~.~ [~t~ CH 5 9/25/98 L PERF - ~rI~IAL 5000-5850 ).~0~ [ ~q ~ CH 5 8/17/98 L PERF ~x~AL 5625 ~ ~ 3~. ~ ! ~ c~ ? CH 5 9/25/98 L PERF ~I~INAL 5000-5740 o~) ~ ,49 (P) !~ C{ ~') . CH 5 9/25/98 R MMS SRVY d~8~E~i~RY 0-5838. OH 10/5/98 Interval Sent Received 11/4/98 11/12/98 11/12/98 10/22/98 8/20/98 10/22/98 10/22/98 10/5/98 T/C/D R MWD SRVY .L~P~RRY 0-6025. OH 10/5/98 10/5/98 Daily Well Ops .~~~~9 Are Dry Ditch Samples Required? yes (~______.~ And Received? Was the well cored? yes ~ Analysis Description Recei~ . ' Shmple Set~g' .......... Comments: Tuesday, August 01, 2000 Page 1 of 1 ....... . STATE OF ALASKA ALASKA. 3,._ AND GAS CONSERVATION COIv..,,$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Pull Tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Stimulate [] Alter Casing I 4. Location of well at surface 2949' NSL, 4133' WEL, SEC. 34, T13N, R10E, UM At top of productive interval 3030' NSL, 907' WEL, SEC. 34, T13N, R10E, UM At effective depth 2890' NSL, 754' WEL, SEC. 34, T13N, R10E, UM At total depth 2854' NSL, 713' WEL, SEC. 34, T13N, R10E, UM [] Plugging [] Perforate [] Repair Well [] Other Change Out ESP Type of well: [] Development [] Exploratory [] Stratigraphic [~]Service 6. Datum Elevation (DF or KB) KBE = 65.70' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-14 9. Permit Number / Approval No. 97-150 10. APl Number 50-029-22796 1. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 6025 feet true vertical 4396 feet Effective depth: measured 5919 feet true vertical 4307 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 79' 20" 5975' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1670 sx PF E, 855 sx G, 50 sx PFC MD TVD 112' 112' 6007' 4381' Perforation depth: measured true vertical 5530' - 5570', 5686' - 5712', 5760' - 5780' 3976' - 4010', 4110' - 4132', 4171' - 4190' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, NSCT tubing to 5409' Packers and SSSV (type and measured depth) 9-5/8" Gravel Pack Assembly 5506' - 5595' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/'~__ ~ Terrie Hubble , Title Technical Assistant III Prepared By Name/Number: Date 03 '(.~-(~ Terrie Hubble, 564-4628 ~ ~;~ ~n ~)u plicate.~ Form 10-404 Rev. 06/15/88 Facility M Pt H Pad Progress Report Well MPH-14 Page 1 Rig Nabors 4ES Date 08 March 99 Date/Time 05 Feb 99 06 Feb 99 07 Feb 99 08 Feb 99 09 Feb 99 10 Feb 99 11 Feb 99 12 Feb 99 12:00-15:00 15:00-00:00 00:00-04:30 04:30-06:00 06:00-10:00 10:00-11:00 11:00-15:30 15:30-21:00 21:00-22:30 22:30-01:00 01:00-03:00 03:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-11:00 11:00-13:30 13:30-14:30 14:30-15:30 15:30-18:00 18:00-00:30 00:30-03:00 03:00-06:00 06:00-09:00 09:00-11:30 11:30-15:00 15:00-21:00 21:00-22:30 22:30-01:00 01:00-01:30 01:30-06:00 06:00-07:30 07:30-11:30 11:30-13:00 13:00-00:00 00:00-04:00 04:00-06:00 06:00-08:30 08:30-23:00 23:00-01:00 01:00-02:30 02:30-06:00 06:00-08:00 08:00-09:00 09:00-15:00 15:00-03:00 03:00-03:30 03:30-06:00 06:00-08:30 08:30-10:00 10:00-12:00 12:00-16:00 16:00-18:00 Duration 3hr 9hr 4-1/2 hr 1-1/2 hr 4hr i hr 4-1/2 hr 5-1/2 hr 1-1/2 hr 2-1/2 hr 2hr 3hr 2hr lhr lhr lhr 2-1/2 hr lhr lhr 2-1/2 hr 6-1/2 hr 2-1/2 hr 3hr 3hr 2-1/2 hr 3-1/2 hr 6hr 1-1/2 hr 2-1/2 hr 1/2hr 4-1/2 hr 1-1/2 hr 4hr 1-1/2 hr llhr 4hr 2hr 2-1/2 hr 14-1/2 hr 2hr 1-1/2 hr 3-1/2 hr 2hr lhr 6hr 12 hr 1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 2hr 4hr 2hr Activity Rigged down Drillfloor / Derrick Rigged up Drillfloor / Derrick Fill pits with Seawater Filter Seawater Filter Brine Repaired Choke manifold Circulated closed in well at 6000.0 ft Conducted slickline operations on Slickline equipment - Retrival run Removed Xmas tree Installed BOP stack Tested BOP stack Repaired Annular preventor Repaired Annular preventor Tested Annular preventor Worked on BOP - Lubricator Retrieved Tubing hanger Circulated at 6000.0 ft Rigged up Completion string handling equipment Pulled Tubing in stands to 5170.0 ft Repaired Completion string handling equipment Pulled Tubing in stands to 60.0 ft Rigged down sub-surface equipment - ESP Ran Tubing in stands to 2500.0 ft Ran Tubing in stands to 5514.0 ft Reverse circulated at 5690.0 ft Reverse circulated at 5690.0 ft Reverse circulated at 5913.0 ft Reverse circulated at 5913.0 ft Reverse circulated at 5913.0 ft Monitor wellbore pressures Reverse circulated at 5913.0 ft Displace treatment Laid down 5810.0 ft of Tubing Rigged up Completion string handling equipment Installed ESP Ran Tubing to 2395.0 ft (3-1/2in OD) Installed Other sub-surface equipment Installed Other sub-surface equipment Ran Tubing to 5441.0 ft (3-1/2in OD) Installed Tubing hanger Rigged down Tubing hanger Pulled Tubing in stands to 1991.0 ft Pulled Tubing in stands to 2443.0 ft Serviced Block line Rig waited · Equipment Ran Tubing in stands to 5410.0 ft Installed Tubing hanger Installed Other sub-surface equipment Installed Other sub-surface equipment Rigged down BOP stack Installed Xmas tree Freeze protect well - 130.000 bbl of Diesel Installed Hanger plug n Ft I I_1_1 IM G S ~ i:tL/I r" E S WELL LOG TRANSMITFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 11, 1998 MWD Formation Evaluation Logs - MI'H-14, AK-MM-70240 MPH-14: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22796-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22796-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITFAL LETrER TO ~ ATYENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Aa_._.chorag..e 18 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 _ Si 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG R C .IV D Oc I' 0 o' 1. Status of Well Classification of [] Oil [] Gas I-1 Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-150 397-147 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~- -~ 50-029-22796 4. Location of well at surface ?i':ii!.ii¥.-'::.:::?:~"i 'l~,A~" 9. Unit or Lease Name 2949' NSL, 4133' WEL, SEC. 34, T13N, R10E, UM! ' L_~ Milne Point Unit Attop of productive interval i PO~-~- ...... i~ 10. Well Number 3030' NSL' 907' WEL' SEC' 34' T13N' R10E' UM i!~At tota, depth ~'.,~!~!rE~ i ...: · ,.¢-- 11. Field and Pool MPH-14 2854' NSL, 713' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 65.70'I ADL 025906 12. Date Spudded8/15/97 I 13' Date I'D' Reached ! 14' Date C°mp" Susp" °r Aband'l 15' Water depth' if °ffsh°re I16' N°' °f C°mpleti°ns8/18/97 8/3/98 N/A MSL One 17. Total Depth (MD+TVD)6025 4396 ETIj18' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set121' Thickness °f Permafr°st5919 4307 FTI []Yes []No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, EMSS, GR/CCL, GR/JB 23. CASlNG~ LINER AND CEMENTING RECORD CASING SE-FI'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 33' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 32' 6007' 12-1/4" 1670 sx PF 'E', 855 sx Class 'G', 50 sx PF 'C' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" Gun Diameter, 4 spf 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 5352' MD TVD MD TVD Y-Tool assembly 5286'-5350' 5686'-5712' 4109'-4131' 5530'-5570' 3976'-3993' ~6. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 5760'-5780' 4172'-4189' .... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Attachment 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) August 19, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-BBL OIL GRAvITY-APl (CORE) Press. 24-HouR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSBF 5498' 3948' SBF1 5528' 3974' TSBD 5681' 4105' TSBB 5753' 4166' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certiJ~t.J~'l~e foregoin~"is~e and correct, o'''''/ - the best of my knowledge Title Drilling Engineering] Supervisor D Sig 97-150 397-147 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1; Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL NAME: MPH-14 26. (10-407) Attachment- Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Frac, 5760'-5780' Re-Frac, 5760'-5780' Frac, 5686'-5712' Frac, 5530'-5570' ES Cementer Repair, 2270' 2270' Amount & Kind of Material Used Freeze protect with 33 bbls diesel & 135 bbls dead crude 18454# Proplok 16/20 Carbolite behind pipe 76849# Proplok 16/20 Carbolite behind pipe 98000# Proplok 16/20 Carbolite behind pipe 115041# Proplok 16/20 Carbolite behind pipe 520 bbls PF 'E' and 33 bbls PF 'C'; squeezed 13 bbls to 1380 psi Installed casing patch to insure integrity, tested casing to 2500 psi for 30 min. on 7/25/98 Progress Report Facility M Pt H Pad Well MPH- 14 Rig Nabors 4ES Page 1 Date 22 September 98 Date/Time 13 Aug 97 00:00-01:00 01:00-04:30 04:30-06:00 06:00-08:00 08:00-10:30 10:30-12:00 12:00-16:30 16:30-19:00 19:00-22:00 22:00-02:00 14 Aug 97 02:00-06:00 06:00-09:00 09:00-10:30 10:30-11:30 11:30-12:00 12:00-13:00 13:00-16:00 16:00-21:00 21:00-01:00 15 Aug 97 01:00-03:30 03:30-06:00 06:00-06:30 06:30-07:00 07:00-03:00 16 Aug 97 03:00-04:00 04:00-06:00 06:00-07:00 07:00-07:30 07:30-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-22:00 22:00-06:00 17 Aug 97 06:00-09:00 09:00-10:00 10:00-12:00 12:00-13:30 13:30-14:00 14:00-03:00 18 Aug 97 03:00-05:00 05:00-06:00 06:00-07:30 07:30-09:00 09:00-11:00 11:00-11:30 11:30-15:00 15:00-18:00 18:00-19:00 19:00-01:00 19 Aug 97 01:00-03:00 03:00-05:30 05:30-06:00 Duration lhr 3-1/2 hr 1-1/2 hr 2hr 2-1/2 hr 1-1/2 hr 4-1/2 hr 2-1/2 hr 3hr 4hr 4hr 3hr 1-1/2 hr lhr 1/2 hr lhr 3hr 5hr 4hr 2-1/2 hr 2-1/2 hr 1/2hr 1/2 hr 20 hr lhr '2hr lhr 1/2 hr 9hr 1-1/2 hr 1/2 hr lhr lhr 1-1/2 hr 8hr 3hr lhr 2hr 1-1/2 hr 1/2hr 13hr 2hr lhr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 3-1/2 hr 3hr lhr 6hr 2hr 2-1/2 hr 1/2 hr Activity Rig moved 1.00 % Rig moved 10.00 % Rig moved 15.00 % Rig moved 35.00 % Rig moved 55.00 % Rig moved 65.00 % Rig moved 85.00 % Rig moved 100.00 % Fill pits with Water based mud Rigged up Divertor Ran Drillpipe in stands to 29.5 ft Repaired Iron roughneck Installed Divertor Tested Divertor Ran Drillpipe in stands to 1629.5 ft Repaired Drillstring handling equipment Ran Drillpipe to 2779.5 ft (5in OD) Repaired Iron roughneck Ran Drillpipe to 5929.5 ft (5in OD) Ran HWDP in stands to 679.5 ft Made up BHA no. 1 Made up BHA no. 1 Held safety meeting Drilled to 2401.0 ft Circulated at 2401.0 ft Pulled out of hole to 193.0 ft R.I.H. to 2401.0 ft Serviced Top drive Drilled to 3596.0 ft Circulated at 3596.0 ft Pulled out of hole to 2340.0 ft Pumped out of hole to 2034.0 ft Pulled out of hole to 193.0 ft R.I.H. to 2100.0 ft Drilled to 4700.0 ft Drilled to 4885.0 ft Circulated at 4885.0 ft Pulled out of hole to 2125.0 ft R.I.H. to 4885.0 ft Serviced Top drive Drilled to 6025.0 ft Circulated at 6025.0 ft Pulled out of hole to 900.0 ft Pulled out of hole to 900.0 ft R.I.H. to 6025.0 ft Circulated at 6025.0 ft Dropped EMSS survey barrel Pulled out of hole to 924.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 6007.0 ft (9-5/8in OD) Circulated at 6007.0 ft Mixed and pumped slurry - 358.600 bbl Circulated at 6007.0 ft Progress Report Facility M Pt H Pad Well MPH-14 Page 2 Rig Nabors 4ES Date 22 September 98 Date/Time 20 Aug 97 21 Aug 97 22 Aug 97 06:00-08:30 08:30-10:30 10:30-12:30 12:30-14:30 14:30-15:30 15:30-18:30 18:30-22:00 22:00-02:00 02:00-03:00 03:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-10:00 10:00-13:30 13:30-18:00 18:00-20:00 20:00-03:00 03:00-05:00 05:00-06:00 06:00-07:30 07:30-11:00 11:00-12:30 12:30-15:00 15:00-16:00 16:00-16:30 16:30-22:00 22:00-01:15 01:15-06:00 06:00-12:30 12:30-16:00 16:00-17:30 17:30-20:30 20:30-01:00 Duration 2-1/2 hr 2hr 2hr 2hr lhr 3hr 3-1/2 hr 4hr lhr 3hr 1/2 hr lhr 1/2 hr 2hr 3-1/2 hr 4-1/2 hr 2hr 7hr 2hr lhr 1-1/2 hr 3-1/2 hr 1-1/2 hr 2-1/2 hr lhr 1/2 hr 5-1/2 hr 3-1/4 hr 4-3/4 hr 6-1/2 hr 3-1/2 hr 1-1/2 hr 3hr 4-1/2 hr Activity Circulated at 6007.0 ft Mixed and pumped slurry - 471.000 bbl Rigged down Casing handling equipment Rigged down Divertor Rigged up Casing head Rigged up BOP stack Tested BOP stack Ran Drillpipe to 0.0 ft (5in OD) Serviced Top drive Made up BHA no. %s Made up BHA no. 2 (cont...) R.I.H. to 2269.0 ft Drilled installed equipment - DV collar R.I.H. to 5919.0 ft Performed cement integrity test Pulled out of hole to 2230.0 ft Rigged down All functions Rigged up Divertor Pulled out of hole to 944.0 ft Pulled BHA Pulled BHA Checked communication injected between 2275.0 ft and 0.0 ft, Pulled out of hole to 0.0 ft Set packer at 2300.0 ft with 0.0 psi Pulled out of hole to 0.0 ft Removed Bore protector Circulated at 2270.0 ft Mixed and pumped slurry - 553.000 bbl Displaced slurry - 167.000 bbl Held 1380.0 psi pressure on 13.000 bbl squeezed cement Ran Drillpipe in stands to 2120.0 ft Laid down 1900.0 ft of Drillpipe Rigged down Divertor Installed Wellhead primary components Progress Report l- Facility M Pt H Pad Well MPH-14 Page 1 Rig Nabors 4ES Date 22 September 98 Date/Time 21 Jul 98 22 Jul 98 23 Jul 98 24 Jul 98 00:00-06:00 06:00-08:00 08:00-10:30 10:30-11:30 11:30-13:30 13:30-16:30 16:30-18:00 18:00-21:00 21:00-00:00 00:00-03:00 03:00-05:00 05:00-06:00 06:00-07:00 07:00-07:45 07:45-08:30 08:30-09:30 09:30-09:45 09:45-10:30 10:30-11:30 11:30-14:15 14:15-14:30 14:30-19:30 19:30-21:00 21:00-22:30 22:30-23:00 23:00-00:00 00:00-04:30 04:30-06:00 06:00-12:00 12:00-14:30 14:30-15:30 15:30-16:00 16:00-16:30 16:30-17:00 17:00-19:30 19:30-20:00 20:00-21:00 21:00-21:30 21:30-22:15 22:15-22:30 22:30-23:00 23:00-00:00 00:00-01:00 01:00-02:00 02:00-02:30 02:30-02:45 02:45-03:15 03:15-03:30 03:30-04:00 04:00-04:45 04:45-05:00 05:00-05:45 05:45-06:00 06:00-06:15 Duration 6hr 2hr 2-1/2 hr 2hr 3hr 1-1/2 hr 3hr 3hr 3hr 2hr lhr lhr 3/4 hr 3/4 hr lhr 1/4 hr 3/4 hr lhr 2-3/4 hr 1/4 hr 5hr 1-1/2 hr 1-1/2 hr 1/2 hr lhr 4-1/2 hr 1-1/2 hr 6hr 2-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr lhr 1/2 hr 3/4 hr 1/4 hr 1/2 hr lhr lhr lhr 1/2hr 1/4 hr 1/2 hr 1/4 hr 1/2hr 3/4 hr 1/4 hr 3/4 hr 1/4hr 1/4 hr Activity Rig moved 100.00 % Removed Xmas tree Rigged down Casing head Installed Casing head Rigged up BOP stack Tested BOP stack Made up BHA no. 1 Singled in drill pipe to 2164.0 ft Drilled cement to 2278.0 ft Drilled installed equipment - Cement retainer Reverse circulated at 2278.0 ft Set Retrievable packer at 45.0 ft with 3.6 psi Circulated at 500.0 ft Pulled out of hole to 198.0 ft Pulled BHA Rig waited: Equipment Made up BHA no. 2 R.I.H. to 2260.0 ft Serviced Block line Drilled installed equipment - Cement retainer Flow check Singled in drill pipe to 5814.0 ft Drilled cement to 5880.0 ft Pulled out of hole to 2880.0 ft Serviced Casing scraper R.I.H. to 5880.0 ft Rig waited: Other delays Reverse circulated at 5880.0 ft Reverse circulated at 5880.0 ft (cont...) Pulled out of hole to 198.0 ft Pulled BHA Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rig waited: Equipment Made up BHA no. 3 R.I.H. to 2265.0 ft Milled Downhole equipment at 2265.0 ft Pulled out of hole to 98.0 ft Pulled BHA Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Made up BHA no. 4 R.I.H. to 2265.0 ft Milled Downhole equipment at 2265.0 ft Circulated at 2265.0 ft Pulled out of hole to 98.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 290.0 ft Held safety meeting Facility M Pt H Pad Progress Report Well MPH- 14 Page Rig Nabors 4ES Date 2 22 September 98 Date/Time 25 Jul 98 26 Jul 98 06:15-06:30 06:30-07:30 07:30-09:30 09:30-10:15 10:15-10:30 10:30-10:45 10:45-11:30 11:30-12:15 12:15-12:30 12:30-14:30 14:30-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-21:30 21:30-22:00 22:00-23:00 23:00-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-10:00 10:00-10:30 10:30-11:30 11:30-14:00 14:00-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15-23:00 23:00-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-03:00 03:00-03:30 03:30-04:30 04:30-04:45 04:45-06:00 06:00-06:30 06:30-11:15 11:15-12:00 12:00-13:00 13:00-17:00 17:00-18:00 18:00-18:15 18:15-18:30 18:30-20:00 20:00-20:30 20:30-21:00 21:00-21:30 21:30-22:00 Duration 1/4 hr lhr 2hr 3/4 hr 1/4 hr 1/4 hr 3/4 hr 3/4 hr 1/4 hr 2hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2hr 1-1/2 hr lhr 1/2 hr 1/2 hr lhr 7hr 1-1/2 hr lhr 1/2 hr lhr 1/2 hr lhr 2-1/2 hr 3hr 1/2 hr 1/2 hr 1/4 hr 4-3/4 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2hr lhr 1/4 hr 1-1/4 hr 1/2 hr 4-3/4 hr 3/4 hr lhr 4hr lhr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr Activity Serviced Drillfloor / Derrick R.I.H. to 2285.0 ft Functioned Packer assembly Pulled out of hole to 10.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 2433.0 ft Pulled out of hole to 10.0 ft Pulled BHA Serviced Other sub-surface equipment Retrieved Wear bushing Serviced Other sub-surface equipment R.I.H. to 2278.0 ft Functioned Other sub-surface equipment Pulled out of hole to 38.0 ft Pulled BHA Installed Wear bushing Made up BHA no. 8 R.I.H. to 2314.0 ft Circulated at 2314.0 ft Circulated at 2314.0 ft (cont...) Tested Other sub-surface equipment - Via annulus and string R.I.H. to 2294.0 ft Pulled out of hole to 66.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 5497.0 ft (3-1/2in OD) Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test - 100.000 bbl injected at 1767.0 psi Monitor pressures FRAC job - 273.000 bbl injected at 3264.0 psi Monitor pressures FRAC job - 91.500 bbl injected at 2836.0 psi Monitor pressures Held safety meeting Rig waited: Materials FRAC job - 404.000 bbl injected at 2800.0 psi Reverse circulated at 5497.0 ft Monitor pressures Bleed down well Held safety meeting Monitor wellbore pressures Bleed down well Reverse circulated at 5794.0 ft Flow check Ran Tubing to 5811.0 ft (3-1/2in OD) Reverse circulated at 5809.0 ft Progress Report Facility M Pt H Pad Well MPH- 14 Rig Nabors 4ES Page 3 Date 22 September 98 Date/Time 22:00-22:30 22:30-23:00 23:00-00:15 27 Jul 98 00:15-00:30 00:30-00:45 00:45-01:00 01:00-03:30 03:30-04:30 04:30-06:00 06:00-10:30 10:30-11:00 11:00-12:30 12:30-13:00 13:00-13:30 13:30-13:45 13:45-15:00 15:00-15:30 15:30-19:15 19:15-19:30 19:30-21:30 21:30-22:00 22:00-22:30 22:30-00:00 28 Jul 98 00:00-02:00 02:00-02:30 02:30-03:30 03:30-04:00 04:00-04:15 04:15-04:30 04:30-04:45 04:45-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-08:00 08:00-08:30 08:30-09:30 09:30-13:30 13:30-16:30 16:30-17:00 17:00-18:30 18:30-19:00 19:00-19:30 19:30-19:45 19:45-21:00 21:00-23:30 23:30-00:00 29 Jul 98 00:00-00:15 00:15-00:45 00:45-01:00 01:00-02:00 02:00-02:15 02:15-02:45 Duration 1/2 hr 1/2 hr 1-1/4 hr 1/4 hr 1/4 hr 1/4 hr 2-1/2 hr lhr 1-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/2hr 3-3/4 hr 1/4 hr 2hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr lhr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/4 hr 1/4hr 1-1/2 hr 1/2 hr lhr 4hr 3hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 2-1/2 hr 1/2 hr 1/4 hr 1/2 hr 1/4 hr lhr 1/4 hr 1/2 hr Activity Flow check Laid down 314.0 ft of Tubing Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test - 123.000 bbl injected at 3100.0 psi Monitor pressures FRAC job - 700.000 bbl injected at 3000.0 psi Monitor pressures Monitor pressures (cont...) Reverse circulated at 5497.0 ft Flow check Singled in drill pipe to 5658.0 ft Reverse circulated at 5648.0 ft Flow check Circulated at 5648.0 ft Flow check Circulated at 5648.0 ft Flow check Pulled Tubing in stands to 0.0 ft Rigged up Drillstring handling equipment Made up BHA no. 9 R.I.H. to 5658.0 ft Reverse circulated at 5740.0 ft Circulated at 5740.0 ft Circulated at 5740.0 ft Reverse circulated at 5730.0 ft Circulated at 5730.0 ft Circulated at 5730.0 ft Reverse circulated at 5725.0 ft Circulated at 5725.0 ft Flow check Pulled out of hole to 4870.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled out of hole to 39.0 ft Pulled BHA Rigged up Logging/braided cable equipment Rig waited: Equipment Conducted electric cable operations Tested Lubricator Perforated Rigged down Logging/braided cable equipment Rigged up Tubing handling equipment Ran Tubing to 0.0 ft (3-1/2in OD) Held safety meeting Ran Tubing in stands to 5430.0 ft Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test- 75.000 bbl injected at 1650.0 psi Monitor pressures Injectivity test - 75.000 bbl injected at 1700.0 psi Monitor pressures Progress Report Facility M Pt H Pad Well MPH- 14 Rig Nabors 4ES Page 4 Date 22 September 98 Date/Time 30 Jul 98 31 Jul 98 02:45-03:15 03:15-04:15 04:15-04:45 04:45-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-22:00 22:00-00:30 00:30-01:00 01:00-01:30 01:30-03:00 03:00-03:15 03:15-03:30 03:30-05:30 05:30-05:45 05:45-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-16:00 16:00-23:00 23:00-23:30 23:30-00:00 00:00-00:15 00:15-00:30 00:30-02:00 02:00-02:30 02:30-04:15 04:15-05:00 05:00-06:00 06:00-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-10:45 10:45-16:30 16:30-17:00 17:00-18:00 18:00-18:15 18:15-18:45 18:45-20:00 Duration 1/2 hr lhr 1/2 hr 1-1/4 hr 1-1/2 hr 1/2 hr 1/2 hr 8hr 1/2 hr 1/2hr 1/2 hr 1/4 hr 3/4 hr lhr 2hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 2hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2hr 3hr 7hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 1/2hr 1-3/4 hr 3/4 hr lhr 3hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 5-3/4 hr 1/2 hr lhr 1/4 hr 1/2 hr 1-1/4 hr Activity FRAC job - 222.000 bbl injected at 3300.0 psi Monitor pressures Injectivity test - 91.000 bbl injected at 1900.0 psi Monitor pressures Monitor pressures (cont...) FRAC job - 750.000 bbl injected at 3700.0 psi Rigged down High pressure lines Monitor pressures Bleed down well Reverse circulated at 5430.0 ft Singled in drill pipe to 5635.0 ft Held safety meeting Reverse circulated at 5650.0 ft Flow check Circulated at 5650.0 ft Flow check Injectivity test - 2.500 bbl injected at 1100.0 psi Laid down 315.0 ft of Tubing Pulled Tubing in stands to 0.0 ft Retrieved Wear bushing Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Removed Bell nipple Installed Well control Rigged up Logging/braided cable equipment Tested Lubricator Perforated Perforated Removed Well control Installed Bell nipple Ran Tubing in stands to 5300.0 ft Rig waited · Service personnel Held safety meeting Tested High pressure lines Injectivity test - 75.000 bbl injected at 1600.0 psi FRAC job - 223.000 bbl injected at 3000.0 psi Monitor pressures FRAC job - 131.000 bbl injected at 3170.0 psi Monitor pressures FRAC job - 731.000 bbl injected at 2900.0 psi Monitor pressures Monitor pressures (cont...) Reverse circulated at 5300.0 ft Singled in drill pipe to 5480.0 ft Reverse circulated at 5480.0 ft Flow check Laid down 5480.0 ft of Tubing Made up BHA no. 10 R.I.H. to 2225.0 ft Held safety meeting Serviced Block line R.I.H. to 5480.0 ft Progress Report Facility M Pt H Pad Well MPH-14 Page 5 Rig Nabors 4ES Date 22 September 98 Date/Time 01 Aug 98 02 Aug 98 03 Aug 98 20:00-06:00 06:00-06:15 06:15-09:30 09:30-11:30 11:30-12:30 12:30-15:00 15:00-15:30 15:30-16:00 16:00-17:00 17:00-18:30 18:30-19:00 19:00-21:00 21:00-00:30 00:30-01:30 01:30-02:15 02:15-03:00 03:00-06:00 06:00-08:00 08:00-08:45 08:45-09:00 09:00-09:30 09:30-12:30 12:30-13:30 13:30-14:00 14:00-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-20:30 20:30-23:30 23:30-23:45 23:45-01:30 01:30-06:00 06:00-06:15 06:15-10:30 10:30-11:15 11:15-12:00 12:00-14:30 14:30-15:15 15:15-15:30 15:30-17:00 17:00-18:00 18:00-18:15 18:15-19:00 19:00-19:30 19:30-20:00 20:00-20:15 20:15-20:30 20:30-21:30 21:30-22:00 Duration 10hr 1/4 hr 3-1/4 hr 2hr lhr 2-1/2 hr 1/2hr 1/2 hr lhr 1-1/2 hr 1/2 hr 2hr 3-1/2 hr lhr 3/4 hr 3/4 hr 3hr 2hr 3/4 hr 1/4 hr 1/2 hr 3hr lhr 1/2 hr lhr lhr 2hr 1/2 hr 2hr 3hr 1/4 hr 1-3/4 hr 4-1/2 hr 1/4 hr 4-1/4 hr 3/4 hr 3/4 hr 2-1/2 hr 3/4 hr 1/4 hr 1-1/2 hr lhr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr lhr 1/2 hr Activity Reverse circulated at 5758.0 ft Held safety meeting Reverse circulated at 5880.0 ft Reverse circulated at 5880.0 ft Flow check Pulled out of hole to 40.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Rigged up sub-surface equipment - Packer assembly Ran Drillpipe in stands to 5506.0 ft Stung into Permanent packer Set packer at 5506.9 ft with 2500.0 psi Tested Permanent packer - Via annulus Laid down 4355.0 ft of 3-1/2in OD drill pipe Laid down 4355.0 ft of 3-1/2in OD drill pipe (cont...) Installed Accessories Tested Accessories Removed VR plug Ran Tubing to 2348.0 ft (2-7/8in OD) Pulled Tubing in stands to 0.0 ft Retrieved Wear bushing Rigged up Completion string handling equipment Serviced Electrical submersible pumps Rigged up sub-surface equipment - Completion string sub-assemblies Held safety meeting Rigged up sub-surface equipment - Completion string sub-assemblies Ran Tubing to 3000.0 ft (2-7/8in OD) Held safety meeting Rigged up sub-surface equipment - Completion string sub-assemblies Ran Tubing in stands to 4228.0 ft Held safety meeting Ran Tubing in stands to 5352.0 ft Space out tubulars Installed Electric cable Installed Electric cable Ran Tubing on landing string to 5352.0 ft Installed Hanger plug Removed BOP stack Installed Xmas tree Held safety meeting Installed Xmas tree Tested Tubing hanger Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Freeze protect well - 33.000 bbl of Diesel Rigged down High pressure lines GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 11515 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 9/25/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPB-03 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-04 JEWELRY LOG 9 8 0 8 2 3 I 1 M P B-10 JEWELRY LOG 9 8 0 8 2 3 1 1 M PB-15 JEWELRY LOG 9 8 0 8 2 5 I 1 M PB-20 JEWELRY LOG 9 8 0 91 1 1 1 MPC-22A TUBING PUNCHER RECORD 9 8 0 8 0 2 I 1 M PE-21 PERFORATING RECORD 9 8 0 9 0 3 I 1 MPE-30 PERFORATING RECORD 9 8 0 9 0 7 I 1 M P H-10 PERFORATING RECORD 9 8 0 8 2 7 1 1 M PH-10 PERFORATING RECORD 9 8 0 8 2 9 1 1 M P H- 10 PERFORATING RECORD 9 8 0 8 31 I 1 M P H- 11 PERFORATION RECORD 9 8 0 8 0 8 I 1 M P H- 14 PERFORATING RECORD 9 8 0 7 2 8 1 1 M PH-14 PERFORATING RECORD 9 8 0 7 3 0 1 1 M PH-14 PACKER SETTING RECORD 9 8 0 8 01 I 1 M PJ-22 PERFORATION RECORD 9 8 0 7 3 0 I 1 MPJ-22 BRIDGE PLUG SET RECORD 9 8 0 813 I 1 MPJ-22 PERFORATION RECORD 9 8 0 817 1 1 MPK-21 f.4 / c.__ JEWELRY LOG 980913 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK ,8~503 /// GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11436 Company: Field: Alaska Oil & Gas Cons Comm Attn: 'Lorl Taylor 3001 Porcupine Drive AnchOrage, AK 99501 MJlne Point (Cased Hole) 8/17/98 Well Job # Log Description Date BL RF Sepia LIS Tape MP'E-24 ..... .. SIDEWALL CORES RECORD . 9, 80317 .... MPG-10 PERFORATING/GR COLLAR LOG 9803 29 MPG-10 PERFORATING RECORD 980330 MPH-14 PERFORATING RECORD 980 725 , · MPU K-02 PACKER SETI1NG RECORD 980510 MPL-37 PERFORATING RECORD 980623 MPL.37 ' TiE IN LOG 980624 MPL-37 JEWELRY LOG 980717 MpL-39 PERFORATING RECORD 980627 , , ,, , , ,, ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED AU6 e0 19'-78 Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received.: b~~ MEMORANDUM TO: David joh~ Chairman¢--" State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 21, 1998 THRU' Blair Wondzeil, ~~ P. I. Supervisor ~~/) FROM' John Spauldin~~.,... SUBJECT: Petroleum I nsp~.~ FILE NO: awplgufe.doc Confidential' Yes No X BOPE Test Nabors 4ES BPX / MPU / H-14 PTD 97-150 July 21, 1998: I traveled to BPX's Milne Point Unit to witness the BOPE Test on Nabors 4ES. The AOGCC BOPE Test Report form is attached for reference. As noted on the test form no failures were observed. The rig was found to be in very good~vith good access. Summary: I witnessed the BOPE Test on; Nabors 4ES. Test time 3.0 hrs., 0 failures Attachments' awplgufe STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: lnitia Workover: X Nabors Rig No. 4ES PTD# 97-150 BPX/Alaska Rep.: H-14 Rig Rep.: Set @ Location: Sec. X Weekly Other DATE: 7/21/98 Rig Ph.# 659-4154 Larry Meyers Gene Sweatt 34 T. 13N R. IOE Meridian Umiat TEST: DATA: VilSC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: ok Well Sign ok Upper Kelly/IBOP Housekeeping: ok (Gen) Drl. Rig ok Lower Kelly / IBOP PTD On Location ok Hazard Sec. ok -- Ball Type ~tanding Order Posted ok -~ Inside BOP BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure I 250/5,000 250/5,000 250/5,000 250/5,000 P/F , P Quan. Test Press. P/F Test f 250/2500 P P ressu re P/F 250/5,000 P f 250/5,000 P f 250/5,000 P f 250/5,000 P I 250/5,000 P 2 250/5,000 P I 250/5,0OO P NA 250/5, 000 CHOKE MANIFOLD: No. Valves 11 No. Flanges 28 Manual Chokes 1 Hydraulic Chokes 1 250/5,000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3, 050 P Pressure After Closure 1,800 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 36 Trip Tank ok ok System Pressure Attained 2 minutes 22 Pit Level Indicators ok ok Blind Switch Covers: Master: X Remote: Flow Indicator ok ok Nitgn. Btl's: 4 ~ 1950 awg. Meth Gas Detector ok ok -~ Psig. H2S Gas Detector ok ok ~ sec. sec. X : : : TEST'RESULTS Number of Failures: o ,Test Time: "-3.~ Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector F1-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: ~lgufe.xls John H. Spaulding MILNE POINT, ALASKA TO: FROM: WELL# Main Category: Sub Category: Operation Date: Bill Hill Matthew Linder H-14 Pumping Freeze protect 814/98 J Objective: Freeze protect wellbore after completion. Operation: Tubing was freeze protected by rig to 2200'. Rigged up HB&R to inner annulus (9-5/8") and freeze protected to 2200' with 135 bbls of dead crude. Conclusion: Finished freeze protecting wellbore using 135 bbls of dead crude down the annulus. The tubing was freeze protected by the rig to 2200' prior to moving. SIWHP: 0 IA:0 OA: Diesel Used I j Methanol Used BP EXPLORATION (ALASKA) INC. Milne Point Unit TO: J Hendrix FROM: J. Spearman DATE: 7-30-98 RE: SERVICE CO'S.: DS, Peak, Howco MP H-14 DATA FRAC AND FRAC PACK (N Sand) :JOB SUMMARY H-14N sand was frac during the initial completion. Below is the wellbore summary before fracture operations began. · 9.2 brine in wellbore · Tubing tail at 5430 · MD perfs 5530-5570 · TVD 4110-4132 ft The treatment began by pumping a 75 bbls water data frac at 10 bpm. The pressure fell to 0 psi within the first 15 minutes of the decline. Next a 150 bbl gel data frac was pumped at 20 bpm. A step rate test was performed, but the wellbore was not full during the Iow rate stages. Since a bottom hole gauge was run, the step rate test was not repeated. After the data was analysis by Anchorage and Mike Smith with NSI, the job was pumped. 119,000 lbs of 16/20 Carbolite was pumped of which 114,000 lbs was placed behind pipe. All proppant was coated with 3/8 gal per 100 lbs of Halliburton's PropLok. A tip screen out occurred during the treatment. Notes: No spills or job problem encountered 10/01/98 4:36 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL TIME~ RATE BPM ANNPi WHP i STAGE PSlG i PSlG i BBL CUM BBL PUIV,, .,~ SUMMARY COMMENTS Water Data Frac Design Rate, Bbls Max Rate, Final ANN, ISIP2, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 10 75 10 723 658 65 0.644 DATA FRAC Bbls Bbls gel to Rate Final Ann, ISIP, psi NWB Treat grad, Pumped Perfs BPM psi friction, psi psi/ft 155(5 bbls 63 20 726 644 80 0.64 water) Gel left on ocation is = FRAC Sand Lead prop Tail prop Design total pumped, behind pipe, behind behind pipe, Liner Sand, Job was M# M# pipe, M# M# M# Tailoff, M# Flush 119,414 11~4~0~) 120,000 4~7 Ft of Estimated Final ISIP, psi ISIP Incr Actual TSO, TSO, sand in sand top Ann, over sand:pad design, min Nolte Pipe psi datafrac ratio Plot 93 5542 900 750 100 Operational problems Comments .. DATE/TIME OPERATIONS SUMMARY 07129198 23:00 Pre-job Safety meeting on 27E 23:50 Pressure Test lines to 7920 psi 23:54 Start Water data frac. 9.2 brine in hole. Pumped 75 bbl seawater. 00:01 SD ISIP 658 psi 00:19 Pressure bleed down to 0 psi on annulus. Started Gel Data Frac 00:31 SD ISIP = 644 !02:02 Start Step rate test. Annulus wasn't full. 02:20 SD ISIP 576 04:18 Start Frac 04:55 SD ISIP 750 psi TIME :~ RATE ~ BPM PUMPING SUMMARY ANNPi, WHP i STAGE i CUM i COMMENTS PSIG i PSIG i BBL ! BBL 07/30/98 Water Data Frac DISPLACEMENT = 63. BBLS 23:54 0 Start Water DF 23:55 10 688 1579 8 On Seawater 23:58 10 715 1589 40 00:00 10 723 1602 63 ,, 00:01 0 75 SD ISlP 658 psi DATA FRAC 00:19 Start Data Frac at 20 BPM 00:21 20 699 3122 100 00:22 20 692 2779 138 Pad on perfs 00:23 20 728 2797 158 Good pad on perfs 00:27 20 742 2715 225 Switch to flush 00:28 20 722 2596 250 100 bbls gel through perfs 00:30 20 726 2995 290 150 bbls gel through perfs 00:31 SD ISIP - 644 STEP RATE 00 Start Step Rate 02:04 0.5 0 0.5 bpm 02:06 0.75 0 0.75 bpm 02:08 1.0 0 1.0 bpm PUMPING SUMMARY TIME' RATE ;ANNP! WHP !STAGE i CUM ' COMMENTS ~ BPM ~ PSlG ~ PSIG ! BBL i BBL 02:10 1.5 0 1.5 bpm 02:12 2 0 2 bpm Caught fluid 02:14 3 12 3 bpm 02:16 5 409 5 bpm 02:14 7 471 7 bpm 02:16 10 548 10 bpm 02:18 15 630 15 bpm 02:20 20 669 20 bpm SD ISIP = 576 Frac 04:18 Start Pad 04:19 24 Caught Fluid 04:21 19.8 644 2591 130 63 Pad on pefs 04:22 19.8 700 2614 Good Pad on perfs 04:27 20.1 752 2632 12 193 0.5 ppg on perfs 04:28 20.1 753 2641 35 205 1ppg on perfs 04:29 19.8 752 2683 34 240 2 ppg on perfs 04:31 19.9 739 2788 24 274 3 ppg on perfs 04:32 19.7 739 2843 24 298 4 ppg on perfs 04:34 19.7 742 2893 24 322 5 ppg on perfs 04:35 20.1 752 2870 24 346 6 ppg on perfs Start gel displacement 04:36 20.1 766 2843 35 370 7 ppg on perfs Start source water flush 04:38 20.2 783 2866 47 405 8 ppg on perfs 04:40 19.8 821 2921 71 452 9 ppg on perfs 04:44 20.2 856 3304 190 523 10 ppg on perfs 0 04:55 Start Flush ISIP = 750 psi Page 5 FLUIDS PUMPED Water DF: HEC 75 Bbls DATA FRAC: HEC 150 Bbls FRAC HEC 603 Bbls ****TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WINDOW Set at 09:00 7~30~98 for a 40 hr window (10secs collection rate) IJGel 1 JGel 2 IWater SEA H20 pH 7.5 GEL QUALITY CONTROL CHECK Sea H20 GEL GEL Temp pH VISCOSITY 6.1 138 6.2 140 75 Gel Temp 99 104 XL TIME XL pH L Wellbore Brine Density [ 9.2 ppg J BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: B HilllJ Hendrix FROM: J. Spearman DATE: 7-29-98 RE: SERVICE CO'S.: DS, Peak, Howco MP H-14 DATA FRAC AND FRAC PACK (OA Sand) JOB SUMMARY IJ H-14 OA pre-frac wellbore configuration was: · 9.2 brine in wellbore · Tubing tail at 5430 · MD perfs 5686-5712 · TVD 4110-4132 ft The H-14 OA treatment was started by pumping 75 bbls a seawater data frac at 10 bpm. The water data frac was performed to validate the fluid efficiency of wellbore fluids. The well was shut in for 1 hour. Next a 150 bbls HEC gel data frac was pumped at 20 bpm. Again the well was shut in for 1 hour to collect data. The next step was to pump a step rate test. The data frac and frac design was done by Mike Smith with NSI. A total of 102,000 lbs of 16/20 proppant was pumped of which 98,000 was placed behind pipe. All proppant was coated with 3/8 gallons per 100 lbs of proppant. The job was flushed with 8.4 ppg seawater No spills or job problem encountered Notes: "Since 5S was attempting to frac !-08 and the second frac crew was not experienced with Mflne Point operations, Kirby Walker was on that frac. 4ES is being forced to muddle along with Spearman with this frac." By Kirby Walker 7/28/98 10/01/98 4:40 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: MPU Telex Group Kirby Walker MPH-14(OA) PERF E-Line 7~28~98 Date: I July 29, 1998 II Objective: To perforate the OA sand from 5,686' to 5,712' using Sequence of Events: O4OO 0830 1300 1515 1545 1650 1735 1755 1800 1900 Schlumberger on location R/U Schlumberger RIH wi GR/CCL Log into position POOH - P/U gun assembly RIH w/gun assembly Log onto depth Fire guns - positive indication of firing POOH R/D Schlumberger Results: 4,132"I-VD). Schlumberger successfully perforated the OA sand from 5,686' - 5,712' (4,110' - Tie in log/date 7/28/98 ......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter 5686 II 5712 J[ 7" Jr Shot Density 4 Orientation J L N/A Phasing IL o-18o TIME I RATE ~ANNP'= WHP [STAGE ; CUM i BPM i PSlG i.PSIG i BBL i BBL PUN,. .,~, SUMMARY COMMENTS Water Data Frac Design Rate, Bbls Max Rate, Final ANN, ISIP2, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psilft 10 75 10 881 775 106 0.67 NWFP is annulus pressure ' min before sllut down minus ISIP Water Data Frac Design Rate, Bbls Max Rate, Final ANN, ISIP2, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psilft 10 75 10 830 745 85 0.66 NWFP is annulus pressure ~ min before sltut down minus ISIP ~note~ ~ep 8~4Seawate~Went through: Perfs~ an~nulus~pressue increased by 13 psi. DATA FRAC Bbls Bbls gel to Rate Final Ann, ISIP, psi NWB Treat grad, Pumped Perfs BPM psi friction, psi psi/ft 155(5 bbls 66.8 20 912 837 75 0.68 water) FRAC Sand Lead prop Tail prop Design total pumped, behind pipe, behind behind pipe, Liner Sand, Job was 1~06 M# pipe, M# 0~0 M#/ Tailoff, M# Flush 95,500 I , 2..,~O0 2,500 Ft of Estimated Final ISIP, psi ISIP Incr Actual TSO, TSO, sand in sand top STP, over sand:pad design, min Nolte Pipe psi datafrac ratio Plot 60 844 7 Operational problems Comments DATE/TIME OPERATIONS SUMMARY 07~29~98 00:10 Pre-job Safety meeting on 27E 00:42 Pressure Test lines to 6670 psi 00:50 Start Water data frac. 9.2 brine in hole. Pumped 75 bbl seawater. 00:54 SD ISIP 775 psi 01:54 Start 2® Water Data Frac due to funny looking decline 02:01 SD ISIP = 745 psi 03:01 Start 150 bbl Data Frac 03:13 Shut down Data = 837 psi 04:19 Start Step rate test 04:40 Shut down Step Rate Test Pext = 775 psi 07:20 Start Frac 07:58 Shut down Frac ISIP = 844 psi TIME~ RATE ! BPM PUMPING SUMMARY ;ANNPi WHP ~ STAGE ~ CUM i PSlG I PSlG! BBL BBL COMMENTS 07/29/98 Water Data Frac DISPLACEMENT = 66.8 BBLS 00:47 0 Start Water DF 00:48 10 810 1717 8 8 On Seawater 00:51 10 808 1653 40 ,, 00:53 10 822 1648 65 ,, 10 837 8.4 going through perfs pressure rise is f 10 863 00:54 0 75 SD ISIP 775 psi Water Data Frac 01:54 0 0 Start Water DF 01:55 10 883 1731 8 83.5 On Seawater 01:57 10 824 1698 25 100 ,, 02:00 10 817 1703 65 140 ,, 02:01 10 830 75 150 SD ISlP = 745 DATA FRAC 03:01 859 Start Data Frac at 20 BPM 03:04 20.2 857 208 03:06 921 3365 66 216 Good Gel on perfs 03:07 20.1 938 3346 266 50 bbls gel through perfs 03:10 20.4 919 3264, 316 100 bbls gel through perfs 03:09 19.9 923 3314 300 Switcht to flush PUMPING SUMMARY TIME ' RATE ~ANNP~ WHP ~,STAGEI CUM COMMENTS , BPM i PSlG i PSlG ! BBL ~; BBL 03:12 20.1 916 3222 356 140 bbls gel through perfs 03:12 912 366 5 bbls water on perfs 03:13 372 Shut down ISIP = 837 psi STEP RATE 04:19 Start Step Rate 04:21 0.5 685 372 0.5 bpm 04:23 0.75 709 375 0.75 04:25 1.0 723 377 1.0 04:27 1.5 747 380 1.5 04:29 2 764 384 2 04:31 3 786 390 3 04:33 5 791 400 5 04:35 7 800 414 7 04:37 10 811 434 10 04:39 15 835 464 15 04:40 SD ISIP = 771 Frac 07:20 Start Pad 07:23 48 07:25 19.9 897 3305 24 91 Pad on pefs 07:26 3429 Good Pad on perfs 07:28 20.1 925 72 163 0.5 07:32 20.4 908 3516 72 235 1ppg on perfs 07:36 20.1 899 3694 72 307 2 ppg on perfs 07:39 20.1 888 3786 48 379 3 ppg on perfs 07:42 20.1 881 3800 48 427 4 ppg on perfs 07:44 20.1 879 3694 48 475 5 ppg on perfs 07:47 20.1 879 3630 72 523 6 ppg on perfs Start gel displacement 07:50 20.1 885 3640 96 595 7 ppg on perfs Start source water flush 910 142 691 8 ppg on perfs 57 Start Flush 07:58 SD ISIP = 844 Page 5 Required FLUIDS PUMPED DOWNHOLE THROUGH PEFORATIONS Water DF: HEC 155 Bbls DATA FRAC: HEC 150 Bbls Clean FRAC Fluid HEC 607 Bbls ****TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WINDOW Set at 09:00 7~28~98 for a 40 hr window (10secs collection rate) IIGel 1 IGel 2 [Water SEA H20 1 pH 7.5 GEL QUALITY CONTROL CHECK Sea H20 I GEL GEL Temp pH VISCOSITY 5.7 165 6.2 135 90 Gel Temp 84 102 XL TIME XL pH I Wellbore Brine Density I 9.2 ppg Page I BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: FROM: DATE: RE: SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors Bill Hill Kirby Walker July 26, 1998 H-14 (OB) DataFRAC AND FRAC JOB SUMMARY Rig 4ES ran 5,497' of 3%" 9.3 #/ft was run to pump the frac through. Prior to the job the fluids were tested and found to have less than adequate viscosity required for the job. A vac truck had been ordered to hold extra gel needed for the job. The gel on the truck was tested and passed the specifications. The DataFRAC with water, the main DataFRAC and the step rate test were performed using this gel while extra gel was mixed and brought to location. The frac was started once all the gel was delivered to location. With 404 bbls pumped, almost to the 4 PPA stage, a hole eroded in the 4"x3"x3" Tee at the bottom of the riser on the rig. Treating lines were flushed and the cement line on the rig was used as an alternate route through which to reverse out the tubing. A half barrel of gel was spilled onto the pad and an estimated 7 bbls was contained in the cellar. Plans are to clean out to as far as possible with the sawtooth shoe already on the end of the tubing and attempt another frac. DATA FRAC I (water) Bbls ISIP Closure Closure Time Leakoff NWB Treat grad, Pumped psi Pressure observed friction, psi psilft 100 736 - - - 109 0.64 DATA FRAC II (75# HEC) Bbls ISIP Closure Closure Time Leakoff NWB Treat grad, Pumped psi Pressure observed friction, psi psilft 200 791 - - - 142 0.65 FRAC Sand Prop Prop Proppant Liner Sand, Tresaver pumped, # behind pipe, left in csg, size/type M# rubber left Job was M# M# in hole? Shutdown 27,868 18,454 9,414 16120 NIA NIA early Carbolite Ft of Estimated Final ISIP, psi ISIP Incr % PAD TSO, TSO, sand in sand top STP, over (pad/slurry) design, min Nolte Pipe psi datafrac Plot 5,760 surface 2,806 778 (ann) -13 9.8 11.4 NIA Page 2 Operational problems The rig had a 4" frac string built into the substructure sometime back in 1994-1995 with a 4x3x3 tee on the bottom for which to connect to pump frac jobs. To no one's knowledge has this line been tested since installation nearly 4 years ago. The string was removed from the rig and sent to Dowell's yard where FMC happens to be for the week testing Dowell's treating iron. Here it will be tested. Comments The new specification by Halliburton of having the HEC gel at a pH of 6.0 and 100°, we've learned, is a very conducive atmosphere for the growth of bacteria in the gel. Plans for the rest of the H-14 wells is to have the gel mixed at 100° but leave it at a pH of -9.0 until just before loading onto the trucks for transfer to the wellsite. An effort to minimise the time the gel spends in the tank will also be made. These steps and the already in progress tank cleanings will help reduce the chance of running into this problem again. TIME OPERATIONS SUMMARY 0138 Pressure Test Lines 0139 Start first DataFRAC 0309 DataFRAC 0420 Step Rate Test 1120 FRAC TIME: RATE BPM PUMPING SUMMARY i ANNPi WHP STAGE ~ CUM ! PSlG PSlG i BBL BBL COMMENTS DataFRAC I (water) 0139 10 821 1886 100 - Start injection seawater 0154 10 800 1804 50 Pressure check 0200 0 837 1767 100 Shutdown - monitor for 1 hour ISIP - 736 psi NWBF - 109 psi DATA FRAC II DISPLACEMENT = 63 BBLS 0309 20 996 4029 200 - Start DataFRAC 75# HEC 0312 20 943 2893 50 Pressure check 0315 20 1009 2838 100 Pressure check 0317 20 ~ 971 2825 150 '. Pressure check 0320 20 i 952 2797 73 200 Start Displacement seawater 0324 0 '~ 930 3264 273 ': Shutdown - monitor pressure i ~ ISIP - 791 psi NWBF - 142 psi STEP RATE TEST 0420 0.5 694 751 1 - Start SRT - 0.5 bpm 0422 0.75 713 820 1.5 1 0.75 bpm 0424 1.0 742 815 2 2.5 1.0 bpm 0426 1.5 778 884 3 4.5 1.5 bpm 0428 2.0 806 925 4 7.5 2.0 bpm 0430 3.0 839 1007 6 11.5 3.0 bpm 0432 5.0 859 1209 10 17.5 5.0 bpm P~_g_= 3 0434 139:' 7.0 864 14 27.5 7.0 bpm 0436 10.0 ~ 886 1836 20 41.5 10.0 bpm 0438 15.0 ! 932 2836 30 61.5 15.0 bpm i 91.5 Shut down FRAC 1120 20 965 i 4170 48 - Start Pad 1124 20 905 i 2912 36 48 Start 0.5 PPA 1125 20 896 2687 68 PAD on Zone 1125 20 897 2706 95 84 Start 1.0 PPA 1127 20 936 2783 116 0.5 PPA on Zone 1129 20 936 2774 152 1.0 PPA on Zone 1130 20 930 2774 95 179 Start 2.0 PPA 1132 20 912 2770 247 2.0 PPA on Zone 1135 20 907 2760 72 274 Start 3.0 PPA 1138 20 896 2747 342 3.0 PPA on Zone 1138 20 896 2756 48 346 Start 4.0 PPA 1141 20 832 1666 48 394 Start 5.0 PPA 1141 0 775 142 404 Shutdown -reverse out 18,454# behind pipe FLUIDS PUMPED DOWNHOLE DataFRAC I 100 BBLs DataFRAC II 273 BBLs Step Rate Test 92 BBLs FRAC: 404 BBLs IINONE PETREDAT WINDOW , seawater pH DFIFRAC 7.4 GEL QUALITY CONTROL CHECK HEC [ HEC HEC ~ PIPE TEMP ! pH ~ VISCOSITY~ TIME 88 i 6.0 ,, 145 ~ 3.4 XL XL TIME pH N/A i N/A FLUID ADDITIVES J-134 (breaker) - 2.5 #/1000 gal BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Bill Hill FROM: Kirby Walker DATE: July 26, 1998 Ao RE: H-14 (OB) DataFRAC AND FRAC SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors JOB SUMMARY Rig 4ES cleaned out to 5,811' with the saw tooth on the end of the frac string. The tubing tail was placed again at 5,497' for the second attempt at fracturing the OB sand. A 50 bbl HEC injectivity test was pumped to ensure the ability to pump into the well. Results showed that near wellbore friction actually decreased from the previous job to 79 psi. The frac was pumped as designed by Mike Smith (consultant). Everything went well during the frac. There was a small pressure build of about 40 psi over the span of the treatment. 80,209# of 16/20 Carbolite was pumped and flushed to within 10 bbl of the top perforation. INJECTION TEST (75# HEC) Bbls ISIP Closure Closure Time Leakoff NWB friction, Treat grad, Pumped psi Pressure observed psi psi/ft 50 846 - - - 79 0.66 FRAO Sand Prop Prop Proppant Liner Sand, Tresaver pumped, # behind pipe, left in csg, size/type M# rubber left in Job was M# # hole? flushed 80,209 76,849 3,360 16/20 Carbolite N/A N/A Ft of sand Estimated Final ISIP, psi ISIP Incr % PAD TSO, TSO, in Pipe sand top STP, over datafrac (pad/slurry) design, min Nolte psi Plot 131 5,628 2,219 847 1 8.9 18 - 07/27/98 2:22 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL Page 2 TIME t OPERATIONS SUMMARY 1253 Pressure Test Lines - 6,500 psi 1258 Injection 0344 FRAC PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM BPM PSIG PSIG BBL BBL COMMENTS INJECTION DISPLACEMENT = 63 BBLS 1258 20 907 3713 50 - Start Injection Test 75# HEC 1259 20 874 3342 25 Pressure check 0100 20 861 2760 73 50 Start displacement 0104 123 Shutdown - monitor pressure ISIP - 846 psi NWBF - 79 psi Frac Grad. - 0.66 FRAC 0344 20 958 3516 48 Start pad 0346 20 888 2801 36 48 Start 0.5 PPA stage 0348 20 903 2696 95 84 Start 1.0 PPA stage 0350 20 930 2751 116 Pad on Zone 0351 20 929 2774 136 0.5 PPA on Zone 0353 20 919 2788 95 179 Start 2.0 PPA stage 0354 20 919 2802 202 1.0 PPA on Zone 0358 20 912 2815 72 274 Start 3.0 PPA stage 0359 20 912 2811 297 2.0 PPA on Zone 0402 20 910 2838 48 346 Start 4.0 PPA stage 0404 20 907 I 2925 392 3.0 PPA on Zone 0404 20 907 2925 48 394 Start 5.0 PPA stage 0406 20 907 2980 48 442 Start 6.0 PPA stage 0407 20 903 I 2999 464 4.0 PPA on Zone 0409 20 907 3021 48 490 Start 7.0 PPA stage 0410 20 908 2999 512 5.0 PPA on Zone 0411 20 910 2971 48 538 Start 8.0 PPA stage 0411 20 914 2921 560 6.0 PPA on Zone 0415 20 916 2925 608 7.0 PPA on Zone 0417 20 921 2971 20 642 Start Flush 0417 20 920 2958 656 8.0 PPA on Zone 0417 20 921 2957 38 662 Switch to seawater 0418 15 896 2225 685 Reduce rate 0410 903 2216 700 Shutdown ISIP - 847 psi Grad - 0.66 Page 3 FLUIDS PUMPED DOWNHOLE Injection 50 FRAC: 642 BBLs 75# HEC displaced with seawater (+5 bbl) BBLs 75# HEC - displaced with 20 bbl HEC and 38 bbl seawater (-10 bbl) PETREDAT WIN DOW IINONE GEL QUALITY CONTROL CHECK seawater HEC HEC HEC PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.2 91 6.74 160 3.4 N/A N/A FLUID ADDITIVES J-134 (breaker) - 2.5 #/1000 gal STATE OF ALASKA ALASK~ .,IL AND GAS CONSERVATION COwlMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to Schrader Bluff 2. Name of Operator BP Exploration (Alaska)Inc. 99519-6612 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at Surface 2949' NSL, 4133' WEL, SEC. 34, T13N, R10E, UM At top of productive interval 3002' NSL, 923' WEL, SEC. 34, T13N, R10E, UM At effective depth At total depth 2842' NSL, 720' WEL, SEC. 34, T13N, R10E, UM 12. Present well condition summary Total depth: measured 6025 feet true vertical 4394 feet Effective depth: measured 2120 feet true vertical 1924 feet 5. Type of well: [] Development [] Exploratory [] Stratigraphic [~Service 6. Datum Elevation (DF or KB) Plan RTE - 66.1' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-14 9. Permit Number 97-150 (Secondary Target, Planned) (Secondary Target, Planned) Plugs (measured) Junk (measured) 10. APl Number 50-029-22796 11. Field and Pool Milne Point Unit / Schrader Bluff Approved Casing Structural Conductor Surface Intermediate Production Liner Length Size 112' 20" 6007' 9-5/8" Cemented 250 sx Arcticset I (Approx.) 475 sx PF 'E', 855 sx 'G', 1195 sx PF 'E' 50 sx 'C', 1345 sx PF 'E', 195 sx PF 'C' MD TVD 112' 112' 6007' 4379' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A ORI$1NAL AUG 26 1997 13. Attachments [] Description summary of proposal [] Detailed operations program [-q BOP sketch 14. Estimated date for commencing operation August 23, 1997 16. If proposal was verbally approved Bob Crandall Name of approver 8/22/97 Date approved Contact Engineer Name/Number: James Robertson. 564-5159 15. Status of well classifications as: [] Oil I--I Gas I--] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip AIvord ~,~_~ ~__ ~_..~_A~ Title Senior Drilling Engineer Commission Use Only Date ~/2- 5-/,,,O 7 Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 10- I Approval No~°¢'I - If.],r7 Approved by order of the Commission Form 10-403 Rev. 06/15/88 ,~m Signed By lav'id W. JuJ~lsL0[~ Commissioner Date I Submit ,f~ TFpllc~a~t~e~ (' ~!' H-14 was planned with a Kuparuk target in an untested fault block in the Milne Point Unit. Due the geologic risk of the Kuparuk target a Schrader Bluff back up target was included in the well's directional plan. The well planning for the Kuparuk target called for having 9-5/8" surface casing cemented back to surface set across the Schrader Bluff interval prior to drilling to the Kuparuk sands. After logging the Kuparuk interval a decision would be made to complete the Kuparuk interval or abandon the Kuparuk, plug back and complete the Schrader Bluff zone. After drilling through the 9-5/8" ES cementer and attempting a surface casing test it became evident the cementing stage tool had become damaged and would not hold sufficient pressure to allow drilling ahead to the Kuparuk target. The surface casing cement job was remediated after confirming the stage tool failure and left with a cement plug across the failed stage tool. Pending a decision on the appropriate technique to fix the 9-518" casing the well will be completed as a Schrader Bluff production well. RE€E\V¡iD ÂUG 2. 6 1991 . c::: corom\s" AI...' I;. .Dil& Gas Co. ns. .' . tQsn.a" . ~, ~n,fi . "AnCnor..v. SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/28/97 Si' ~ .... ~UN DRILLING SERVICES PAGE ANOHO DATE OF SURVEY: 081897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70245 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -65.70 177.73 177.73 112.03 268.73 268.71 203.01 362.51 362.42 296.72 453.29 453.03 387.33 0 0 N .00 E .00 .00N .00E .00 0 27 S 82.96 E .26 .09S .71E .61 1 33 S 85.91 E 1.20 .22S 2.30E 1.94 2 47 N 89.08 E 1.34 .27S 5.86E 4.77 4 4 N 82.02 E 1.47 .21N 11.26E 8.70 542.65 542.14 476.44 633.84 632.95 567.25 723.80 722.36 656.66 813.42 811.27 745.57 904.22 901.07 835.37 4 30 N 81.49 E .49 1.17N 17.86E 13.29 5 49 N 77.39 E 1.50 2.71N 25.92E 18.66 6 47 N 75.89 E 1.10 5.00N 35.53E 24.78 7 41 N 77.24 E 1.03 7.62N 46.52E 31.78 9 11 N 77.74 E 1.64 10.50N 59.53E 40.21 996.32 991.59 925.89 1088.33 1081.06 1015.36 1181.13 1170.13 1104.43 1273.13 1256.79 1191.09 1366.83 1342.53 1276.83 12 1 N 77.99 E 3.09 14.06N 76.11E 51.01 14 55 N 78.64 E 3.15 18.39N 97.11E 64.80 17 37 N 80.63 E 2.98 23.03N 122.69E 82.00 21 32 N 76.97 E 4.45 29.11N 152.91E 101.94 26 0 N 71.66 E 5.28 39.45N 189.19E 123.99 1459.83 1423.92 1358.22 1552.72 1502.35 1436.65 1645.10 1578.90 1513.20 1738.00 1653.77 1588.07 1830.80 1725.13 1659.43 31 47 N 70.47 E 6.25 54.07N 231.67E 148.26 32 59 N 70.13 E 1.30 70.85N 278.51E 174.62 35 4 N 71.63 E 2.43 87.76N 327.35E 202.46 37 34 N 77.84 E 4.79 102.15N 380.40E 235.16 41 52 N 79.06 E 4.70 113.99N 438.49E 273.40 1923.53 1793.26 1727.56 2015.58 1859.25 1793.55 2106.06 1922.46 1856.76 2197.75 1985.87 1920.17 2289.33 2047.55 1981.85 2381.85 2106.86 2041.16 2475.45 2164.20 2098.50 2566.51 2216.72 2151.02 2658.84 2266.98 2201.28 2751.58 2314.63 2248.93 43 32 N 81.31 E 2.44 124.69N 500.45E 315.39 44 51 N 81.60 E 1.44 134.22N 563.90E 359.27 46 30 N 82.86 E 2.08 142.97N 628.03E 404.17 45 59 N 80.29 E 2.10 152.66N 693.53E 449.56 49 18 N 80.44 E 3.63 163.98N 760.25E 494.89 50 56 N 79.01 E 2.12 176.65N 830.10E 541.85 53 30 N 81.64 E 3.54 189.04N 903.02E 591.38 56 2 N 83.41 E 3.19 198.70N 976.77E 643.27 57 59 N 83.64 E 2.12 207.42N 1053.71E 698.23 60 9 N 83.47 E 2.35 216.35N 1132.75E 754.71 2842.46 2359.46 2293.76 2932.86 2404.38 2338.68 3024.88 2449.06 2383.36 3116.49 2489.92 2424.22 3209.07 2528.55 2462.85 60 43 N 85.30 E 1.86 224.09N 1211.42E 811.65 59 40 N 85.27 E 1.18 230.53N 1289.59E 868.99 62 14 N 85.55 E 2.80 236.97N 1369.77E 927.92 64 46 N 85.78 E 2.78 243.16N 1451.51E 988.21 65 53 N 86.05 E 1.24 249.15N 1535.42E 1050.35 ORIGINAL St ¥ 'BUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/28/97 DATE OF SURVEY: 081897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70245 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3300.86 2566.64 2500.94 65 3 N 85.87 E .92 255.03N 1618.72E 3392.80 2604.20 2538.50 66 42 N 87.75 E 2.58 259.69N 1702.49E 3485.53 2641.30 2575.60 66 7 N 87.49 E .67 263.22N 1787.40E 3576.41 2678.62 2612.92 65 22 N 87.90 E .92 266.55N 1870.20E 3666.33 2716.62 2650.92 64 36 N 87.73 E .87 269.66N 1951.63E 1112.07 1174.90 1239.34 1302.24 1364.21 3757.70 2756.53 2690.83 63 35 N 88.19 E 1.21 272.59N 2033.77E 3850.85 2800.13 2734.43 60 35 N 87.64 E 3.26 275.57N 2116.02E 3942.25 2846.31 2780.61 58 42 N 88.64 E 2.27 278.14N 2194.84E 4033.53 2894.19 2828.49 58 1 N 88.54 E .75 280.05N 2272.53E 4125.85 2944.04 2878.34 56 36 N 88.25 E 1.56 282.23N 2350.19E 1426.85 1489.54 1549.80 1609.57 1669.16 4218.91 2995.67 2929.97 55 59 N 88.04 E .68 284.73N 2427.57E 4310.89 3048.76 2983.06 53 29 N 89.30 E 2.94 286.49N 2502.65E 4403.32 3104.93 3039.23 51 38 S 89.81 E 2.14 286.82N 2576.04E 4495.10 3163.03 3097.33 49 48 S 88.50 E 2.29 285.78N 2647.06E 4587.65 3223.66 3157.96 48 19 S 87.05 E 1.98 283.07N 2716.92E 1728.32 1786.15 1843.53 1899.91 1956.40 4680.80 3287.54 3221.84 45 4 S 84.76 E 3.93 278.27N 2784.52E 4774.59 3355.22 3289.52 42 32 S 82.04 E 3.36 270.85N 2849.01E 4865.27 3423.00 3357.30 40 43 S 78.26 E 3.42 260.58N 2908.35E 4958.52 3494.78 3429.08 38 36 S 74.49 E 3.44 246.60N 2966.19E 5051.52 3568.88 3503.18 35 45 S 69.92 E 4.26 229.50N 3019.69E 2012.42 2067.62 2120.55 2174.60 2227.18 5143.37 3644.15 3578.45 34 15 S 61.92 E 5.25 208.11N 3067.73E 5235.07 3720.41 3654.71 33 16 S 54.55 E 4.59 181.35N 3'lll.01E 5328.25 3799.44 3733.74 30 41 S 51.78 E 3.19 151.80N 3150.54E 5421.16 ~ 3879.57 3813.87 30 7 S 50.06 E 1.12 122.17N 3187.05E 5516.56 3962.02 3896.32 30 15 S 49.51 E .32 91.19N 3223.68E 5612.42 4044.60 3978.90 30 46 S 47.99 E .97 59.09N 3260.28E 5708.17 4126.57 4060.87 31 27 S 47.86 E .71 25.94N 3297.01E 5803.65 4207.73 4142.03 32 7 S 46.80 E .91 8.15S 3333.99E 5838.00 4236.73 4171.03 32 41 S 46.19 E 1.90 20.83S 3347.34E 2278.14 2328.69 2378.02 2425.04 2472.99 2521.61 2570.98 2621.13 2639.46 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3347.40 FEET AT SOUTH 89 DEG. 38 MIN. EAST AT MD = 5838 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 128.31 DEG. TIE-IN SURVEY AT 0.00' MD LAST SURVEY STATION AT 5,838.00' MD SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/28/97 DATE OF SURVEY: 081897 JOB NUMBER: AK-EI-70245 KELLY BUSHING ELEV. = 65.70 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SI/B-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -65.70 .00 N .00 E .00 1000.00 995.19 929.49 14.22 N 76.86 E 4.81 2000.00 1848.20 1782.50 132.62 N 553.03 E 151.80 3000.00 2437.33 2371.63 235.25 N 1347.90 E 562.67 4000.00 2876.43 2810.73 279.33 N 2244.09 E 1123.57 4.81 146.99 410.87 560.91 5000.00 3527.49 3461.79 239.37 N 2990.65 E 1472.51 5838.00 4236.73 4171.03 20.83 S 3347.34 E 1601.27 348.94 128.75 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~ P ....gUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHA~RED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/28/97 DATE OF SURVEY: 081897 JOB NUMBER: AK-EI-70245 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -65.70 .00 N .00 E .00 65.70 65.70 .00 .00 N .00 E .00 .00 165.70 165.70 100.00 .08 S .61 E .00 .00 265.72 265.70 200.00 .21 S 2.22 E .02 .02 365.80 365.70 300.00 .27 S 6.02 E .10 .08 465.99 465.70 400.00 .33 N 12.15 E .29 .20 566.29 565.70 500.00 1.44 N 19.70 E .59 .29 666.76 665.70 600.00 3.44 N 29.18 E 1.06 .47 767.45 765.70 700.00 6.26 N 40.60 E 1.75 .69 868.39 865.70 800.00 9.29 N 53.94 E 2.69 .94 969.89 965.70 900.00 12.95 N 70.93 E 4.19 1.51 1072.46 1065.70 1000.00 17.59 N 93.19 E 6.76 2.57 1176.49 1165.70 1100.00 22.80 N 121.33 E 10.79 4.03 1282.73 1265.70 1200.00 29.94 N 156.38 E 17.03 6.24 1392.82 1365.70 1300.00 43.20 N 200.34 E 27.12 10.09 1509.07 1465.70 1400.00 62.80 N 256.21 E 43.37 16.25 1628.98 1565.70 1500.00 84.84 N 318.56 E 63.28 19.91 1753.16 1665.70 1600.00 104.09 N 389.54 E 87.46 24.18 1885.51 1765.70 1700.00 120.73 N 474.55 E 119.81 32.35 2024.68 1865.70 1800.00 135.16 N 570.25 E 158.98 39.17 2168.72 1965.70 1900.00 149.14 N 672.95 E 203.02 44.04 2317.17 2065.70 2000.00 167.48 N 781.07 E 251.47 48.45 2477.99 2165.70 2100.00 189.33 N 905.05 E 312.29 60.82 2656.43 2265.70 2200.00 207.20 N 1051.68 E ~-390.73 78.43 2855.23 2365.70 2300.00 225.00 N 1222.52 E 489.53 98.80 3060.63 2465.70 2400.00 239.42 N 1401.32 E 594.93 105.40 3298.62 2565.70 2500.00 254.88 N 1616.70 E 732.92 137.99 3545.39 2665.70 2600.00 265.52 N 1842.02 E 879.69 146.78 3778.06 2765.70 2700.00 273.18 N 2051.94 E 1012.36 132.66 3979.58 2865.70 2800.00 278.90 N 2226.73 E 1113.88 101.53 4165.17 2965.70 2900.00 283.24 N 2382.99 E 1199.47 85.59 4339.36 3065.70 3000.00 286.76 N 2525.53 E 1273.66 74.19 4499.24 3165.70 3100.00 285.70 N 2650.22 E 1333.54 59.88 4649.55 3265.70 3200.00 280.14 N 2762.25 E 1383.85 50.31 4788.77 3365.70 3300.00 269.46 N 2858.45 E 1423.07 39.22 ~'gUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/28/97 DATE OF SURVEY: 081897 JOB NUMBER: AK-EI-70245 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4921.08 3465.70 3400.00 252.59 N 2943.39 E 1455.38 32.31 5047.58 3565.70 3500.00 230.27 N 3017.50 E 1481.88 26.50 5169.38 3665.70 3600.00 200.99 N 3080.44 E 1503.68 21.80 5288.77 3765.70 3700.00 164.30 N 3134.29 E 1523.07 19.39 5405.13 3865.70 3800.00 127.33 N 3180.88 E 1539.43 16.36 5520.82 3965.70 3900.00 89.80 N 3225.32 E 1555.12 15.69 5636.98 4065.70 4000.00 50.68 N 3269.62 E 1571.28 16.16 5754.06 4165.70 4100.00 9.83 N 3314.77 E 1588.36 17.08 5838.00 4236.73 4171.03 20.83 S 3347.34 E 1601.27 12.91 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS PAGE 1 SPErRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 MWD SURVEY JOB NUMBER: AK-MM-70240 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLOR3kTION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -65.70 0 112.00 112.00 46.30 0 204.07 204.07 138.37 0 295.65 295.64 229.94 1 388.10 388.05 322.35 2 0 0 18 4 18 N .00 E .00 .00N .00E N .00 E .00 .00N .00E S 58.24 E .33 .13S .20E S 84.66 E .89 .33S 1.26E S 85.81 E 1.34 .55S 3.98E .00 .00 .24 1.20 3.46 479.50 479.32 413.62 3 568.30 567.86 502.16 5 662.72 661.78 596.08 6 750.95 749.36 683.66 7 842.96 840.49 774.79 8 34 N 88.11 E 1.42 .59S 8.66E 5 N 80.05 E 1.84 .18N 15.30E 35 N 77.38 E 1.61 2.09N 24.71E 18 N 76.72 E .81 4.48N 35.11E 31 N 78.13 E 1.35 7.23N 47.48E 7.16 11.89 18.10 24.77 32.77 935.49 931.66 865.96 10 1027.58 1021.63 955.93 13 1120.57 1111.46 1045.76 16 1211.91 1198.26 1132.56 19 1305.06 1284.76 1219.06 23 56 39 17 53 38 N 78.71 E 2.62 10.36N 62.81E N 79.00 E 2.94 14.15N 82.07E N 79.26 E 2.83 18.68N 105.66E N 78.15 E 3.97 24.26N 133.47E N 73.06 E 4.49 32.96N 166.87E 42.86 55.62 71.33 89.69 110.50 1397.48 1367.66 1301.96 28 1490.47 1447.73 1382.03 32 1582.67 1524.69 1458.99 34 1675.08 1600.08 1534.38 36 1768.69 1673.87 1608.17 39 46 17 3O 10 46 N 70.26 E 5.72 45.88N 205.56E N 70.09 E 3.79 61.91N 250.00E N 71.60 E 2.55 78.54N 297.94E N 76.11 E 3.36 93.35N 349.27E N 78.35 E 4.11 106.03N 405.43E 132.86 157.79 185.10 216.19 252.40 1862.71 1744.25 1678.55 43 1955.71 1811.05 1745.35 44 2047.28 1875.50 1809.80 45 2139.97 1939.63 1873.93 46 2232.40 2002.11 1936.41 48 16 54 37 47 7 N 80.23 E 3.95 117.58N 466.66E N 80.51 E 1.77 128.40N 530.45E N 80.30 E .81 139.24N 594.58E N 79.14 E 1.55 151.19N 660.42E N 78.34 E 1.57 164.49N 727.21E 293.29 336.63 380.23 424.49 468.65 2325.22 2062.21 1996.51 51 2418.49 2119.61 2053.91 52 2509.63 2173.24 2107.54 55 2601.84 2224.33 2158.63 57 2694.54 2272.53 2206.83 59 9 52 1 40 39 N 79.81 E 3.48 177~87N 796.65E N 80.67 E 1.97 190.33N 869.09E N 82.15 E 2.70 201.32N 941.93E N 83.59 E 3.16 210.83N 1018.09E N 83.61 E 2.14 219.65N 1096.77E 514.84 563.96 614.30 668.17 724.43 2785.18 2317.54 2251.84 2876.01 2362.39 2296.69 2967.73 2407.07 2341.37 3059.37 2448.95 2383.25 3152.08 2488.25 2422.55 60 6O 61 63 65 46 2 37 58 52 N 85.15 E 1.92 227.35N 1175.05E N 85.29 E .81 233.93N 1253.76E N 85.36 E 1.72 240.46N 1333.58E N 85.72 E 2.58 246.80N 1414.82E N 86.46 E 2.17 252.52N 1498.58E 781.08 838.77 897.35 957.17 1019.35 ORIGINAL S~ jUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 081897 MWD SURVEY JOB NUMBER: AK-MM-70240 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3243.78 2526.16 2460.46 65 16 3335.84 2563.85 2498.15 66 23 3428.26 2601.01 2535.31 66 11 3519.79 2638.43 2572.73 65 33 3609.17 2675.93 2610.23 64 49 N 85.85 E .88 258.11N 1581.89E 1081.25 N 87.24 E 1.83 263.17N 1665.72E 1143.89 N 87.30 E .22 267.20N 1750.24E 1207.72 N 87.03 E .75 271.33N 1833.67E 1270.62 N 87.36 E .87 275.30N 1914.70E 1331.74 3700.68 2715.61 2649.91 63 46 3793.66 2758.72 2693.02 60 57 3885.08 2804.50 2738.80 58 56 3976.75 2852.29 2786.59 58 12 4068.03 2901.48 2835.78 56 33 N 87.43 E 1.15 279.05N 1997.07E 1394.05 N 86.84 E 3.08 283.16N 2079.34E 1456.05 N 87.46 E 2.29 287.10N 2158.36E 1515.62 N 88.74 E 1.43 289.70N 2236.53E 1575.35 N 88.94 E 1.82 291.25N 2313.40E 1634.69 4162.19 2953.69 2887.99 56 5 4253.96 3006.41 2940.71 53 45 4346.02 3062.17 2996.47 51 40 4437.29 3119.89 3054.19 49 50 4529.03 3179.86 3114.16 48 30 N 88.86 E .49 292.76N 2391.74E 1695.24 N 89.72 E 2.67 293.70N 2466.82E 1753.57 S 89.30 E 2.40 293.44N 2540.06E 1811.19 S 88.24 E 2.20 291.93N 2610.72E 1867.58 S 86.78 E 1.89 288.92N 2680.07E 1923.86 4621.64 3242.86 3177.16 45 45 4714.59 3309.21 3243.51 43 9 4808.82 3379.21 3313.51 40 55 4899.30 3448.49 3382.79 39 6 4992.39 3521.98 3456.28 36 38 S 84.50 E 3.48 283.79N 2747.74E 1980.13 S 81.78 E 3.47 276.06N 2812.35E 2035.63 S 77.37 E 3.92 264.70N 2874.38E 2091.35 S 74.62 E 2.80 250.65N 2930.82E 2144.34 S 70.84 E 3.64 233.74N 2985.38E 2197.64 5085.39 3597.56 3531.86 34 40 S 65.34 E 4.0 5177.00 3673.40 3607.70 33 37 S 58.74 E 4.2 5268.56 3750.59 3684.89 31 28 S 53.90 E 3.6 5361.74 3830.40 ~3764.70 30 38 S 52.56 E 1.1 5455.00 3910.80 3845.10 30 15 S 51.13 E .8 5549.99 3992.77 3927.07 30 27 S 48.90 E 1.2 5646.66 4075.73 4010.03 31 17 S 48.47 E .9 5742.52 4157.35 4091.65 31 57 S 47.17 E .9 5838.21 4238.24 4172.54 32 36 S 47.07 E .6 5933.87 4319.07 4253.37 32 4 S 46.77 E .5 4 213.59N 3035.65E 2249.57 0 189.55N 3081.03E 2300.08 8 162.30N 3122.02E 2349.14 6 133.52N 3160.54E 2397.20 9 104.33N 3197.70E 2444.46 1 73.49N 3234.48E 2492.43 0 40.73N 3271.74E 2541.98 9 6.98N 3308.99E 2592.13 8 27.80S 3346.44E 2643.08 9 62.75S 3383.82E 2694.08 5950.89 4333.48 4267.78 32 10 S 47.72 E 3.04 6025.00 4396.21 4330.50 32 10 S 47.72 E .00 68.90S 3390.46E 2703.10 95.45S 3419.66E 2742.47 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3420.99 FEET AT SOUTH 88 DEG. 24 MIN. EAST AT MD = 6025 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 128.31 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 6025'MD S~ 3UN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 081897 JOB NUMBER: AK-MM-70240 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -65.70 .00 N .00 E .0 1000.00 994.79 929.09 12.94 N 75.86 E 5.2 2000.00 1842.42 1776.72 133.55 N 561.28 E 157.5 3000.00 2422.41 2356.71 242.76 N 1361.88 E 577.5 4000.00 2864.54 2798.84 290.13 N 2256.29 E 1135.4 5.21 152.36 420.02 557.87 5000.00 3528.09 3462.39 232.23 N 2989.66 E 1471.9 6000.00 4375.05 4309.35 86.49 S 3409.81 E 1624.9 6025.00 4396.21 4330.50 95.45 S 3419.66 E 1628.7 336.45 153.04 3.84 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. St SI/N DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 081897 JOB NUMBER: AK-MM-70240 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -65.70 65.70 65.70 .00 165.70 165.70 100.00 265.70 265.70 200.00 365.74 365.70 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .02 S .03 E .00 .00 .28 S .70 E .00 .00 .48 S 3.08 E .04 .03 465.85 465.70 400.00 566.13 565.70 500.00 666.67 665.70 600.00 767.42 765.70 700.00 868.45 865.70 800.00 .62 S 7.81 .15 N 15.11 .19 N 25.16 .96 N 37.15 .01 N 51.18 E .15 .12 E .43 .28 E .97 .53 E 1.72 .76 E 2.75 1.03 970.22 965.70 900.00 1073.07 1065.70 1000.00 1177.43 1165.70 1100.00 1284.33 1265.70 1200.00 1395.27 1365.70 1300.00 11.71 N 69.61 16.28 N 93.12 21.97 N 122.37 30.66 N 159.05 45.54 N 204.59 E 4.52 1.77 E 7.37 2.84 E 11.73 4.36 E 18.63 6.90 E 29.57 10.94 1511.73 1465.70 1400.00 1632.71 1565.70 1500.00 1758.11 1665.70 1600.00 1892.16 1765.70 1700.00 2033.27 1865.70 1800.00 65.77 N 260.68 86.97 N 325.34 104.66 N 398.84 121.00 N 486.56 137.55 N 584.71 E 46.03 16.46 E 67.01 20.98 E 92.41 25.40 E 126.46 34.06 E 167.57 41.10 2178.05 1965.70 1900.00 2330.79 2065.70 2000.00 2496.48 2165.70 2100.00 2681.03 2265.70 2200.00 2882.65 2365.70 2300.00 156.42 N 687.68 178.64 N 800.92 199.85 N 931.26 218.36 N 1085.18 234.41 N 1259.49 E 212.35 44.78 E 265.09 52.74 E 330.78 65.69 E --- 415.33 84.55 E 516.95 101.62 3097.53 2465.70 2400.00 3340.47 2565.70 2500.00 3585.11 2665.70 2600.00 3808.03 2765.70 2700.00 4002.21 2865.70 2800.00 249.35 N 1449.02 263.37 N 1669.95 274.30 N 1892.95 283.86 N 2091.88 290.17 N 2258.16 E 631.83 114.89 E 774.77 142.93 E 919.41 144.65 E 1042.33 122.92 E 1136.51 94.17 4183.73 2965.70 2900.00 4351.71 3065.70 3000.00 4507.66 3165.70 3100.00 4654.09 3265.70 3200.00 4790.87 3365.70 3300.00 293.11 N 2409.62 293.38 N 2544.52 289.82 N 2664.09 281.39 N 2770.66 267.17 N 2862.82 E 1218.03 81.52 E 1286.01 67.98 E 1341.96 55.95 E 1388.39 46.42 E 1425.17 36.78 St SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-14 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 081897 JOB NUMBER: AK-MM-70240 KELLY BUSHING ELEV. = 65.70 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4921.38 3465.70 3400.00 246.87 N 2944.13 E 1455.68 5046.46 3565.70 3500.00 222.47 N 3015.12 E 1480.76 5167.74 3665.70 3600.00 192.16 N 3076.60 E 1502.04 5286.28 3765.70 3700.00 156.85 N 3129.50 E 1520.58 5402.76 3865.70 3800.00 120.80 N 3177.13 E 1537.06 30.51 25.08 21.28 18.54 16.48 5518.59 3965.70 3900.00 83.95 N 3222.48 E 1552.89 5634.92 4065.70 4000.00 44.78 N 3267.17 E 1569.22 5752.36 4165.70 4100.00 3.43 N 3312.81 E 1586.66 5870.80 4265.70 4200.00 39.77 S 3359.30 E 1605.10 5988.96 4365.70 4300.00 82.54 S 3405.46 E 1623.26 15.83 16.33 17.44 18.44 18.15 6020.00 4391.97 4326.27 93.66 S 3417.69 E 1628.03 4.77 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TONY KNOWLES, GOVERNOR ALASKA OIL A~ND GAS CONSERVATION C O~I~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 7. 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-66 i2 Re' Milne Point Unit MPH-14 BP Exploration (Alaska) Inc. Permit No: 97-150 Sur. Loc.: 2949'NSL. 4133'WEL. Sec. 34. T13N. RIOE. UM Btmhole Loc: 1707'NSL, 4568'WEL, Sec. 35. T13N. RI0E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law fi'om other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSIO..N dltTenclosures cc: Depamnent of Fish & Game. Habitat Section w/o encl. ._ Department ot-' Envinomment Conse~'ation w/o encl. ~--- -STATE OF ALASKA .., ALASKA ,~,L AND GAS CONSERVATION CON .... ISSlON PERMIT TO DRILL 20 AAC 25.005 !la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil []Re-Entry I--IDeepenI [-IService I'-I Development Gas I--I Single Zone I--I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE - 66.1' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2949' NSL, 4133' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1835' NSL, 4729' WEL, SEC. 35, T13N, R10E, UM MPH-14 At total depth 9. Approximate spud date Amount $200,000.00 1707' NSL, 4568' WEL, SEC. 35, T13N, R10E, UM 08/12/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 712'I No Close Approach 2560 9499' MD / 7295' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' MD Maximum Hole Angle 65-50° Maximum surface 2848 psig, At total depth (TVD) 7025' / 3550 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1 # H-40 Weld 80' 32' 32' 112' 112' _~50 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 6026' 31' 31' 6057' 4380' 1775 sx PF 'E', 481 sx Class 'G' 8-1/2" 7" 26# L-80 Btrc-Mod 9469' 30' 30' 9499' 7295' _~76 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate i.:~, ~i':: '~"-~ ~,i,; i '~_~'"' ~'' Production ~.., ~.~. .... ~; Liner ORIGINAL Perforation depth: measured z:,8..-;~.8 ,,., ~;-: ........ · true vertical '"'":' ..... ~'~' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Brofka, 564-4809 Prepared By Name/Nurnber: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Ch,p A,vord j~_ ~-, .,(~._~ Title Senior Drilling Engineer Date 7 Commission Use Only P~,n~it Number AP, U~n~b~r [ ~.^,prov~, ~t. ,~-~-,,'~"4~ 50- o~...~--' 2_..2- 2 ~' ~'"' 7"/¢-'~ for other requirements Conditions of Approval: Samples Required []Yes .~ No Mud Log Required []Yes '[~'No Hydrogen Sulfide Measures []Yes ~(]No Directional Survey Required ,[~Yes[~ No Required Working Pressure for BOPE D-]2M; 1--13M; [~SM; I-I10M; I--I15M Other: Original Signed By by order of Approved By David W. Johnston Commissioner the commission Dat~ Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): Mark Brofka IMP H-14 Well Plan Summary IKUPARUK PRODUCER 564-4809 Surface Location: 1 2949 FSL, 4133 FEL, S34 T13N R10E UM., AK Schrader Target (Secondary):1 3002 FSL, 923 FEL, S34 T13N R10E UM., AK Kuparuk Target (Primary): 1835 FSL, 4729 FEL, S35 T13N R10E UM., AK Bottom Hole Location: 1707 FSL, 4568 FEL, S35 T13N R10E UM., AK I AFE Number: 1337095 ! I Rig: I Nabors 22E I Estimated Start Date: I 12 AUG 97 I I Operating days to complete: I 10 I MD: 19,499' I I TVD: 17,295' bkb I I KBE: 166.1' I Well Design: IMilne Point Ultra Slimhole Longstring 9-5/8", 40# Surface x 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) base permafrost 2002 1866 Top Ugnu 4894 3416 Top "M" Sands 5283 3724 NA 5569 3966 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 5857 4210 Base of Schrader Bluff Sands (8.3 pp.,g)~. HRZ 8249 6236 High Resistivity Zone MK-19 8479 6431 ., Top Kuparuk 8680 6601 Kuparuk Cap Rock Target Sand -Target 9110 6966 Target Sand (9.6 ppg) Total Depth 9499 7295 TD at 300' MD past base of Schrader Casing/Tui: ing Program: Hole ~ize ' Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112 / 112 12 1/4" 9-5/8" 40# L-80 btm 6026 31/31 6057 / 4380 8-1/2" 7" 26# L-80 btm- 9469 30/30 9499 / 7295 mod Pipe Specifications: O.D. ' Wt/Ft Grade Conn. ID Area Tensile Max Pull Collapse Burst (bbl/ft) (kips) (80% TR) (psi) (psi) 20' 94# H-40 Weld 19.124" 0.3552 40.0 32.0 520 1530 9-5/8" 40# L-80 BTC 8.835" 0.0758 80.0 64.0 3090 5750 7' 26# L-80 BTC-Mod 6.276" 0.0382 80.0 64.0 5410 7240 5' 19.5# G (Pr) 4-1/2' IF 4.276" 0.0178 436.1 348.9 8765 12163 5" 19.5# E (Pr) 4-1/2" IF 4.276" 0.0178 311.5 249.2 7041 8688 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at ±7025 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi (9.66 ppg EMW) is 2848 psi, well below the internal yield pressure rating of the 7" casing. Lo~ling Program: IOpen Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional surface to TD. LWD Gamma Ray/Resistivity surface to TD. N/A MWD Directional and LWD Triple Combo CDR/CDN (GR/RES/Dens/Neu). N/A Mudloggers are NOT required for this well. Mud Program: Special design considerations I None-SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 150 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 10.0 50 20 10 20 9.5 4-6 Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. Completion Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 00' MD IMaximum Hole Angle: Close Approach Well: 65.50 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluid Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on G-pad have been permitted for annular injection. . 2. 3. 4. 5. . . 11. 12. 13. 14. 15. MP G-12 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. Drill 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR/Res from surface to TD. Run and cement 9-5/8" casing. ND 20" diverter. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. Drill 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig for 30 min. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: See the updated Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad and review recent wells drilled on H Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Hydrates: Hydrates have occurred on H-Pad and there is a possibility that hydrates may be encountered in the drilling of MPH-14. Three wells drilled in 1995, MPH-05, MPH-06, and MPH-07 all encountered hydrates below the permafrost. On MPH-05 and MPH-06, mud weight was significantly cut as a result. Lecithin (DrillTreat) should be added to the mud system as a precaution before drilling through the base of the permafrost. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. Close Approach: There are no close approaches associated with the drilling of MP H-14. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. Stuck Pipe Potential: No stuck pipe incidents have occurred on H Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. While drilling the 8-1/2" production hole, be prepared for stuck pipe warning signs when penetrating the Kuparuk cap rock. No stuck pipe has been experienced here on H-Pad wells, though it has been a problem on other pads. Formation Pressure: The expected pore pressure for this well is 9.6 ppg EMW (3,500 psi @ 7,000' TVD). There are no Kuparuk well penetrations in any of the fault blocks adjacent to the MPH-14 target location and as such, the region should be normally pressured. MP H-14 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder + CELLO-FLAKES (1/4 lb/sack) 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 475 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF TAIL TO STAGE COLLAR @ 2250' MD (200' MD BELOW BASE OF PERMAFROST) +30% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: WEIGHT: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) 13.1 ppg YIELD:2.05 ft3/sx MIX WATER: 11.0 gal/sk APPROX #SACKS: 481 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (6057' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (4783' MD) + 30% EXCESS + 82' OF 9-5/8" 40# CASING CAPACITY FOR SHOE TRACK. ~' ,; -~'~ STAGE2 LEAD: ADDITIVES: WEIGHT: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 1300+ SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2250' MD TO SURFACE+ 300% EXCESS. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE' ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVEL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above the Ugnu "M" Sands with one (1) Bowspring centralizer per joint of 9-5/8" casing on bottom 22 joints of casing (22 required). 2. Run two (2) Bowspring centralizers on either side of the ES cementer tool (2 additional). 3. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is .not necessary. MP H-14 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. SPACER: 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 276 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 28 joints of 7" casing (56). This will cover +300' above the KUPARUK Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: . Single stage cement job is calculated to cover.1000 FT MD above the Kuparuk 'C' Sand with 30% excess. An&clrLll Schlumberger Alaska D£strict t11~ East 80th Avenue Anchorage, AK 99518 (907) 349-4511 .Fax 344-2160 DI~3CTfO~AL ~LL PLA~ for SHARED S~VfCES DRILLING Well ......... : NPH-14(P6) Field ........ : M3LN8 POINT, HPAD Computation,.: Miotmum Cktrvature Units ........ : ~HHT Surface Lat..: $0.43824365 N Surface bo~g.: 149.53921638 W Legal Description Surface ...... : 2949 FSi 4~33 P~L S34 T13N R£0E UM SCKRAD~R ~GT.: 3002 FSi 923 PS~ S3~ T13N R£0~ UM KUI~AR~KTGT..: 1835 FS~ 49~9 ~L ~3~ TI3N RIOE~ R~ .......... : [~07 F$~ 4568 ~ S3~ T~N R10E ~ ~OCATIONS - ~KA Zone: 4 X-Ooord Y-Cooed 556511,[2 60£0099,83 559720.00 60£0~78.00 56~05.00 ~009023.00 561367.93 6008896.28 Prepared ..... : 28 Jul 1997 Vert sect az,= 128.3~ KB eIevattoxt.: 66,10 f~ Magnetic Dcln: +~8,005 (8) Sca~e Pactor.: 0.99990363 Convergence..: +O 4341887'7 ANADRI[,I. AKA-DPC APPROVED FOR PERMITTING ONLY PLAN STATIO~ MEASURHD £NCL~ D[I~CT£O~ VERTICAI~-DEPTHS SSCT[ON COORDINATHa-FROM ALASKA Zone 4 ~L DL/ ID~IFI~TION DEPTH ~E AZI~H ~ ~-S~ DEPOT ~HYJ,~ X Y PACE 100 0.0O O.00 O.00 0.00 -66.10 O,OO O.00 N 0.00 ~ ~56S~.12 6010099.83 ~P/~U[~ 1.S/L00 300.00 O.O0 O.00 300.00 233.90 0.O0 0.00 N 0.00 · SS6~L1.12 6010099.83 64R O.QQ 400.00 1.S0 64.00 399.99 333.89 O.~7 0.~7 N 1.18 8 5~6~22.29 6010~OO,41 64R 2/100 ~00.OO 3.00 64.00 49~,9~ 433.81 2.27 2.29 N 4,90 g ~S6~1~.81 60lO102,L6 64R 3,~0 600.00 H.00 6{.00 ~99.66 533.H6 ~-29 5.3S N 10.97 H ~6~22.0~ 6010L05.29 64R BUrhU 2.5/10o 700.00 7.00 64.00 699.L1 633.0L 9.82 9.93 N 20.37 E 55653i.41 6030109.92 H$ 2.00 800.00 9.50 64.00 798.06 731.96 16.04 16.22 N 33.26 E 556544.26 6010116.30 RS 2.50 900.00 12.00 64.00 896.30 830.20 24~~ 2~.40 ~ 50.03 8 556560.96 6010124.61 HS 2.50 lO00.O0 [4,50 64.00 993.63 927.53 34.07 34.45 N 70.63 E 556581.48 6010134.8L HS 2.50 il00.00 [7.00 64.00 1089.87 ~023.77 45,83 46.35 ~ 95.02 ~ 556605,$8 6010L46,89 8S 2.50 BUILD 3/100 1163.15 38.58 64.00 1150,00 1083.90 54.20 64.80 N [12.36 E 556623.05 6010155.48 HS 2,50 (Anadrtll [c)97 NPH14P6 3.0C 10:58 AM P) ~ PROPOSED 9{HL~, PROFILE ~TAT IOlq MHASURRD INCLN DIRgCTr0N IDBNT I FICATIO~I Dll Fri{ ANGLE . AZ rMUTI{ '1200.00 1.9.68, 64, .00 I300. O0 22.68 64.00 , 1400,00 25.68 64,00 1.500.00 28,68 64,00 1600.00 31.68 64.00 mmmm{~=~mmmm~m~ VERTICA/.,-DEPTH8 TVD SUB-SEA LL84.81 3318.7L 1278.04 121L,94 . 3369.26 1303,16 1458,20 L392.10 1544.63 1478.53 CUR%5{ 3/100 1663,15 33.58 64.00 1597,81 1531.7k ~700,00 34-41 65.31 3628.36 1562.26 1800.00 36.72 68.59 1709.$] 1643.61 1900-00 39.12 51.53 1788.60 1722.50 END 3/100 CURVE 1971-50 40.87 73.45 1843.37 1777,27 BASE P~RMAFROST BUILD 3/L00 cu~w 3/zoo 2001.56 40.87 73,45 2031,50 40.87 73.45 2100,00 42.93 73.45 2200.00 45.93 73.45 2300.00 48.93 73,45 2400.00 51.93 73.45 2433.50 52.85 73.45 2500.00 54.L0 75,50 2600.00 55.94 78.39 2700.00 57.85 81.16 2800.00 59,81 83.81 2900.00 61.83 86.35 3000.00 63.89 88.80 30?6.78 65.50 90.62 3943.04 65.50 90.62 BND 3/300 CURVB CURVa 3/Z00 4000.00 64.00 91.53 4100.00 61.39 93.19 4200.00 58.79 94,92 1866.10 1800.00 1888.74 1822.64 1939.72 1873.62 201L.13 L945,03 2078.77 2012.67 2142.46 2076.36 2161-68 2095.58 2202.44 ~136.34 2259.78 2L93.68 23L4-41 2248.31 2366.17 2300.07 2414.93 2348.83 2460.55 2394,45 2493.37 2427.27 2852-59 2786.49 2876.89 2810.79 2922.76 2856.66 2972.62 2906.52 (Anadrill (e) 97 MPH14P6 3.0C 10:58 AM P) .SECT I01~1 DBPART 5~ .43 75.10 92,85 LL2.6~ ~34.45 149,.21 158,36 186.26 2i8.63 244.45 255,78 ~67,05 293,38 333,67 596,05 28 Ou[ 1997 Page 2 OOORDINATI{S-FROM WELI_,IqF_.AD X Y FAC~ 60.10 N 123.22 B 556633.87 6010160.89 HS 75.94 N ~55.69 E 556666.22 6010L76.94 ~ '93.89 N 192.5L H 556702.89 60LOL95.17 HS 113.92 N 233.57 H 556743,79 6030215,50 RS 135,96 N 278.75 E $~6788,81 6010237.88 HS ALASKA Zone 4 TOOL D~/ 100 3.00 3.00 3,00 3.00 3.00 150.88 N 309.36 H 556819.30 60L0253,04 42R 3.00 159.70 N 327.98 H 556837.84 60]0262.00 41R 3.00 182.42 N 38/-49 ~ 556891,18 6010285.t2 38R 3.00 203.34 N 439.26 E 656948.79 6010306.47 36R 3.00 217.15 N 483.09 H 556992.50 6010320.61 HS 3,00 222-75 N 501.94 R 557011.31 6010326.36 HS O.O0 228-34 N 520.72 B 557030.05 6010332.08 HS 0.00 241,37 N 564.57 E 557073.79 6010345.~5 ES 3.00 261.31 N 633.6~ H 557140.73 6010365.99 HS 3.00 282.29 N 702.26 H 557211.15 6010387.40 HS 3.00 420.41 304.24 N 776.13 E 434.78 311.35 N 800.06 E 467.27 326.08 ~ 853.10 E 518.44 34~,55 N 932.90 R 573:91 359.40 N 1015.33 H 633,54 697.15 764.59 8L8.84 1442.65 1483,67 1555.58 1627.21 557284.85 6010%09.92 HS 3,00 557308,92 60L04LT,21 S4R 3.00 55736L.64 6010432.33 53R 3.00 557441,30 6010451.41 51R 3.00 557523,60 6010%66.88 50R 3.00 370,57 N 1100.14 E 557608,31 6010479.69 48R 3.00 378.04 N L187.11 H 557695-22 6010486.81 47~ 3.00 381.78 N 1276.01 H 557784,08 6010491.23 46R 3.00 382.1~ ~ ]345.42 H 557853,48 6010492.L0 H5 3.00 373.55 N 2133.64 E S~8641.66 6010489.50 151R 0.00 372.58 N 2L85.34 E 558693.17 6010488.92 L51R 3.00 368.94 N 2273.91 ~ 558781.95 6010485,95 i50R 3.00 362.83 N 2360.37 H 558868.44 60]0480.50 149R 3.00 u Z ST'ATI 0[~ I DIINT2 FKCkT EON TOP LIGNU TOP M SANDS BND 3/L00 CURVB SCHRADER TGT OA DEPTH ~=mm~m= 4300.00 4400.0O 4500.00 4600.00 4700.00 PROPOSED XNCLN ' DXR~CT£oN ANGLE 'AZXMUTH 56.22 96.76 53,.6~ 98.71 $~.'37 100.79 46.71 ' [03.02 46.29 .105,42 4800.00 43.92 108.02 4893.90 4L.76 ~L0.68 4900.00 4L.62 LL0.B6 S000.00 39.39 113.96 SiO0.O0 57.25 117.35 5200.00 35.23 121.09 5282.79 33.64 124.48 5300.00 33.32 125.21 5369.~7 32.09 128.31 ~569.17 32.O9 ~28.31 5569.17 32.09 128,3L 5752.13 32.09 L28.3~ 5769.L$ 32.09 L28.31 5827.68 32.09 128,31 5857.~9 32,09 128,31 6057.19 32.09 128,3i 8248.66 32.09 L28.31 8378.51 32-09 L28.31 8478.84 32.09 /28.31 8679.51 32.09 228,31 VERTICAb-DH~TH8 8ECTEO~ TVD SUB-S~A DEPART 3026,~4 2960,24 L698.35 ~083.$7' 3017.6~ ~768.81 3144.74 3098.64 1838,40 3209.10 ~L43.00 1906,93 ~276.66 3210.56 L974.20 3347.25 3281.15 34L6.10 3350.00 3420.66 3354.56 3496,70 3430.60 3575,L5 ~509.05 2040.05 2100,40 2104.27 2L66.70 222~.17 3655.62 3589.72 3724.10 3658.00 3738.46 36~2,36 3~96.66 ~30.56 3966,~0 3900.00 2285,52 2332.09 2341.5~ 2378.92 2485.18 3966.10 3900.00 412L.30 4055.00 4L35.54 4069,44 4L85.10 4119.00 4210.L0 4144,00 2485.18 2582.39 259L.45 2622.53 2638.21 4379.54 43L3.44 6236.10 6170,00 6346.10 6280,00 6431.10 6365.00 6601.10 6535.00 2744.47 3908.83 3977.82 4053.12 4237,74 Jul 1997 Page 3 COORD I NATHS WH hl..~ilK D 354,26 N 2444.26 E 343,2.7 N 2525,38 329.88 N 2603.48 314.12 N 2678.3'7 E 296,04 N 2'749.82 Pt 275.70 N 2817.66 254.58 N 2877.89 253.14 N 2881.68 228.42 N ~941,73 201.63 N 2997,62 AI~gKA Zone 4 X 558952.39 60104'72-57 559033.58 559111.78 6010449.39 $59186.'7'7 6010434-20 559258.36 6010416.67 559~26.34 6010396,84 559386,T2 6010376./8 559390.53 60~0394.77 559450.75 60t0350-52 559506,84 6010324.15 172.82 N 3049.2L E 559558.64 6010295.73 147.51 N 3088.57 H 559598.38 6010270.72 E42,08 N 3096.36 H 559606,02. 6010265,35 115.73 ~ 3126,31 H 559636,13 6010243,23 53.86 ~ 3209.69 H 559920.00 601OL78.00 53.86 N 3209-69 il 6.40 S 3285.97 ~ 12,02 $ ~293.O7 H 31.~9 $ 3317.46 Pt 4L.O1 $ 3329-77 E L06.88 S 3413,15 828,67 S 4326,79 871.43 8 4380.92 904.48 S 4422.75 970.57 S 4506.41 14IR 3,00 139R 3.00 139R. 3.00 L3'7R 3.00 134R 3.00 131R. 3.00 128R 3 · O0 L2BR 3.00 H8 3. O0 RS 0. O0 TKUC 8856,57 32.09 128.3L 6751.i0 6685.00 4231.82 1028.89 S 4580.23 TK'UB 8925.59 ~2.09 128.32 680£.10 673~.00 4263.17 E048,33 $ 4604.84 KIJPARUK TGT 9310.35 32-09 L28.32 6966.1q 6900,00 4366.65 i112.48 fi 4686.04 559220.00 60L0178.00 559~96.72 6010118.33 559803.87 6010112.77 559028.40 60~0093.69 S59840.78 60~0084.06 HS 0.00 HS 0.00 RS 0.00 NS 0.00 HS O.00 (AnadriLL (c)9'; MPH14P6 3.0C ].0:58 AM P) 559924,65 6010018.83 HS 0.00 560843,65 6009304.05 RS 0,O0 560098.10 600926L.70 HS 0.00 560940.17 6009228.98 DIS O.00 561024-32 6009~63,53 H~ 0.00 56L098,57 6009105-78 ES 0.00 561123.32 6009086.53 HS 0.00 561205.00 600902~.00 HS 0.00 07/28/1997 11:32 ~~(-~44-~lbtl H~HU~~~~ ur~ I ~w~ v~ . ¡r (- '- ~ ; ~ _/' u . 00000 ",",0100000 [) it ~ ° 81 In ; uo... 1100000 ~ ~ '~ ~~~I « Z - 1 ~ U . . -cIO)(¡JCI.I - /I Þc.:z::c:s: 0 J.- :\ . u 0 ,., t") (Q co LLlJ- U " ~ 0 In r"'I N N > ,,-, " .. -",- a 1 t") Ø'\ <qO \D \þ . -'-- 81 II N 0 <II 0\ <II 0 ~ -.ill -....¡ " ~ > II 0 0 <II co ø . II 0\ C7I co co co -.II Z :ij: . 41 II 0 0 0 0 0 .... ....., . ~ . 0 0 000 ....0 :~ I\D\D\Þ\D\D o..w ... II IONNM"-¡ CL.^ Z 11< U Or"'lr"'lO\<II <... II:Z:: II . 41 ~~ l(lnNNf'ot' « en . x liON ~ oD \D -J ~ I!:I 1 IIMNCII,.,,., --' ~ 0. 10< """r"'I""~~ -- 0 ..... . I \D \D \D \D ~ ~ n I Lt)LnLnU"lU') [) A... , &¡. , ~ 111':ùÞ:1111c.1~ Z<'(,(,. I ~ : ~ <qO \D ~ N N ~ I:¡: ~ONO\OO < .... 1 O. . I .... : g; : ~ ~ ~ ~ :: "'--- ." =' III~U\D~t"-coco ÞO) U Cf.J II'" <qO ... .. .. . þ: II co I ~ Ñ ~~ :COCl.lCf.lO)C/.I /I ~ Þ:1 I co co ,., ~ ~ ~ ~ ~ n q ~ \D ~ q . 0 "N oD r"'I 0 0 I 0 /I rl Ñ ~ ~ ~ I U ~ M ~ ~ N N . " r"'I ~ .... ~ .... 1 . n 1 U"I 0 C7I co co u 2 ~ ~ \D ~ \D Q 0 : 2 ~ n ~ (Q ,., ,., ~ : t ~ : ~ ~ ~ ~ ~ . I':ù C I <qO .. ~ ~ ~ . œ I 11 ~ OOOLnI.O : CI.I ~ ~ 0 ~ ~ .... ~ Þ:1 1 ~ ~ . 0 Lt) In <II 0\ ~ .fi: I ~O,.,t'NN ~ : ~ § : ~ : ~ ~ ~ 0 11 I to .. ~ . ~ ~ 1 < II 0 0 0 ~ Lt) IU . ""~""MN ~ .~ . .... ~ I ~ § : ~ ~ ; ~ ~ ~ n ~ ~ : ~ ~ ~ ~ ~ Q U Þ Þ:I ~ 12 '''''r"'Ir-i''''~ ~ . 0 ~ I ~ ~ ~ ,., M 0 . ~ . .. ~ ; t : ~ ~ ~ ~ ~ ~ ~ ~ : ~ .... ~ .... M I .... ocr:: u . ~ II õ; ~:2:111 ;~~~~~ .~ :Gã~ÑÑNN~ co .~=:; ""''''~''''M 11\ I .... 4: .. 0 .... :~ I~~::: tJ ag;¡z; ~ O~COCOa:l 0 . CI) 6:: II M Lt) (!\ (!\ C7I ,., . < ~ II M ~ ~ ~ .. I~A:O\O\C\<II<II ~ qo r-I II 1 :c u 1 ~ . 11 ::s: . Z" . o. t' . .... fool 0\ 1 ~ I :2: .... ~ ~ ð : 8 ~ u .... 10-1 " ~ -- IIt-'ÞcIl ~ \D :~H = !~§g ~ ~ ItIl~. .... ~ ... n &1. en 13 M II CI d ..... ~ III I U ""IIMN-IU ;¿ ~ : ~~~~"Q ~ X I . ~ E-' ~ t"- e-- ", 87/28/1997 11'32 987-344-2168 ANADRIKL DPG PAGE · [ ' SH'ARED SERVICES DRILLING MPH- 1_ 4 (PC) VERTICAL SECTION VlE~ Section at: 128.31 TVD Scale.- ~. inch = :tO00 feet Oep Scale · 1 inch : :t000 feet <KB> o ~ I I iDrawn · 28 Jul 1997 B-- , _~oo c ' AnadrJ]] Schlumberger r]m -, ! Marker Identification MD BKB SEClN INCLN 1000 t - Al KB 0 0 0 O. O0 E~ 8) KOP/BUILD 1.5/100 300 300 0 0,00 · · C) BUILD 2/100 500 500 2 3.00 DI BUILD 2.5/100 700 699 10 7.00 1500 -~ E) BUILD 3/100 1t83 1150 §4 18.58 F) CURVE 3/100 1663 1598 149 33.58 ~000 H) BUILD 3/~00 RO3R ~889 267 I) CURVE 3/{00 2~32 2162 ~35 52.87 d) END 3/100 CURVE 3077 ~93 819 65.50 T 2500 K) CURVE 3/JO0 39a3 2853 ~4a3 65.50 L) ENO 3/100 CURVE 5369 3797 2379 32,09 ~ M) SCHRADER TGT 5569 3966 2485 32.09 V N) 9-5/8" CASING POINT .6057 4380 2744 32.09 ~D 3000 · K ' O) KUPARUK TGT 91t0 6966 4367 32.09 P) 7" CASING POINT 9499 7295 4573 32.09 ~] TD 9499 7295 4573 32.09 3500 ~-- ~ " = ..... ~'' s~ ADER TGT (Radius RO0 feet ] 4000 ~ - ~' ' ' .... ' "~ ~~=:-' ::::. =::..~' ;;;,, ~;~;;-- 4500 ~ ~ ~ ~ ~. A qADRIL' AK ~-DPC . , APP ~vr:n 5000 J FOIl P~~tMITTIN(~ ' ~ X 6000- ~ F ..... _ .... ... ...... . ........ :---,- . . ..... ~_...:: .. :: _.~:~:- .......... P 7500 · .-, 8000- ' ' ' ' 0 500 1000 1500 2000 2500 3000 3500 4000 aSO0 5000 5500 6000 6500 Section Departure ~ i (~s~ill [c)97 ~t~6 3.or- 1t:00 ~ P~ SHARED SERVICbS DRILLING NPH- 14 (PC) ' % V, ERTICAL, SECTION VIEW, -- \ Section at: ~28.3~ TVO Scale.' ~ inch = ~00 fee~ Dep Scale.' J inch = JO0 feet '~ Drawn - 2B Jul ~997 " ~nadr~ ] ] Schlumberger Marker Identifica(~on MD BKB SECTN INCLN I A) END 3/100 CURVE 5369 3797 2379 32.09 .......... B) SC~ADER TGT 5569 3966 ~485 32.09 ~-~ - ~ ........ C) 9-5/8' CASING POINT 6057 a380 2744 32.0~ D) KUPARUK TGT 9510 6B66 4367 32.09 I ' E} 7" CASING POINT B499 7295 4573 32,09 F) TD 9499 7295 4573 32.09 } )RILL A~J FOR f ERMITTING ~N~ Y . . . ~- ~~H~ARFR fGT (Rad us 200 ~-~ .............. . 0-~ . 0 , 0 - --- ;;..... 'o~ - ~l~t ....... " iO - '~ - ~t~ ........ ' ........................ ~ ~' ~¢ ......................... k _ iO ' ~ . .., ~100 2150 8200 2250 2300 2350 2mO0 2450 2500 2550 2600 2650 2700 ~750 2800 (i~aOpill (c)~7 i~c~4P6 3.0C it:O! AN P) , ANADRILL DPC PAGE 08 07/2@/1997 11'B2 907-B44-2160 SHARED SERV ICES DR ILL I N6 i i ii i i m i i ~' ' ' \ ' ' IVll-'F1- .L '-t ~r-u) VERTICAL SECTION VIEW , Section at: TVD Scale.' ~ inch = ~00 feet Dep Scale · i inch = 100 feet ~ ' Brawn · 28 Jul t997 Anadri ]] $chlumber'gen ::) ,, Marker Tdentiftc~t~.on HD BKB SECTN fNCLN ~,) KUPARUK TGT 9110 6966 4367 32.09 B) 7' CASIN6 POINT 9499 7295 4573 32,09 L . C] TO 9499 7895 4573 3;2.09 ) = :i-~ - e~ - - -~ - . I- ! · } ~,~ 7~o~ .......... N ............ i-~t/llCv- '~' ~'' ...... I' /'NADRLL ACA-DP( I ~ I APl,ROVED C),,NL? · · .,~ 4000 4050 44.00 4 t50 4;200' .4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 Section Oeparture IAna~rill (c)g7 I,~'I14P6 3.0C 'l~;OJ, .~ P) ,4ha#hill 5cl~lu~ber~er I I I I I II MPH-14 '(P6) PLAN VIEW CLOSURE ' 5~04 feet at Azimuth ~04,35 DECLfNATION.' +28,005 (E) SCALE · I inch = 600 feet DRAHN · 28 Jul 1997 'SH'ARED SERVICES'dRILL'ING' " ! I! I1~1111 I I j i I I _ I III 14arker Identification Al KB 0 0 N 0 E BI KOP/BUILD 1.5/~00 300 0 N 0 E CI BUILD 2/100 500 2 N 5 E D} BUILD 2.5/100 700 10 N 20 E E) BUZLD 3/~00 1163 55 N ]12 E F) CURVE 3/~00 1663 iSi N 309 E G) END 3/100 CURVE 1972 2~7 N 483 E H) BUILO 3/~00 2032 228 tl 52~ E I) CURVE 3/fO0 2432 311 N I]00 E J) END 3/t00 CURVE 3077 302 N 1345 E K) CURVE 3/100 3943 374 N 2134 E L) END 3/300 CURVE 5369 120 N 3126 E N) SCHRADER fGT 5569 54 N 3210 E N] 9-5/6' CASING POl~lf 6057 107 S 34t3 E D] KUPARIJK '[Gf 9]i0 ]]12 S 4606 E P} 7' CASING POINT 9499 ]240 $ 4848 E (}1 ]0 9499 ~240 S 4848 E ANADRILL AKA-DPi APPROVED FOR PERMITTING ONLY PLAN .~ ~r~,~ ~ ~,'.,~',~,-,r_n ~-r,-r ~n . .,.- ,n,, 'x ~ ',UP~RUK 13T I 300 0 300 600 BOO 1200 1500 1800 2tO0 ~400 ~700 3000 3300 3600 3900 4;~00 4500 4~00 5100 <- ~ES1 ' EAST -) ~et ) Z ]~ I~nadrtl] (cig? l~qll~UB .1.0C II:Og ,~1 PI ID' 1,5'40'59" I ~ H-14 -(~ H-13 · -~ H-12 H-11 JUL lb'Y( _., Mpu H'PAD' ,7//,'.: : ...... LEGEND -~ AS.'BUILT WELL CONDUCTOR' ~ EXISTING wELL.coNDUCTOR . . . . : . LOCATED wITHIN PROTRACTED SECTION 34, T. 13 N.,' R; 10 E,, UM!AT MERIDIAN ALASKA ~LL -A:S.P. PLANT GEbDETIC ' GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y= 6,010,013.33 N= 1,295.2~' ~0"26'16.828" 70.4380078*" 2,88~;' FSL H-11 X= 556,487.05 E= 760.41 1_49'3.2'21.905" 149.,5394181' , 37.0' 4,158' FEL Y= 6,010,041.75 N=,' 1,324.83 70'26~17.107" 70.4380853° 37.0' 2,891' FSL H-12 X: 556~495.12' E'- 760.50 149'32'21,662" 149.53,93506, 4,150' FEL Y:6,010,070.40 N= 1,354.57 70'26'17.3B8''~ 70.4381633. 2,920' FSL H~13 X= 556r503.05 E: 760.39 14..9.'3.2'21.422" 149.5392839' 56.7r 4~142' FEL Y=6,010,099,83 N: 1,385.08 70'26'17.677" 70,4382436' 2,949' FSL H-14 X: 556,511.12 £-'- 760.20 !49'32'21.179" 149.5392164' 36.6' 4.133' FEL ..... VICINITY MAP .SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME' OR UNDER MY DIREC1 SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARF CORRECT AS OF JUlY 13, 1997. NOTES 1. DATE OF SURVEY: JULY 9-13, i.~97. 2, REFERENCE FIELD BOOK: MP97-06 (POS. 31--32, 63-67). ,3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC COORDINATES ARE NAD 1927. PAD SCALE FACTOR IS 0.9999036. HORIZONTAL/VER'I'ICAL CONTROL IR BASED ON MONUMENTS H-1 AND H-2. 7. ELEVATIONS ARE BPX MPU M.S,L. 4, BP EXPLORATION MILN~' POINT UNIT H-PAD AS-BUILT WELL CONDUCTORS WELLS-H-II, H-12, H-13 AND H-14 Slit[ h lo~1 Input by: SS Date: 7/15t97 Check by: LOH Date:?/15/97 ID' JUL lb'~F ~0 ;~'-~ I~lO .UUO I" .UO MPU H-Pad Well Conductor H-'I4 ADJACENT WELLHEAD LOCATIONS AS-BUILT CONDUCTOR: H-14 WELL NORTHING EASTING H-14 6,0'10'099.83 556,511.12 WELL H-4 H-5 H-10 H-11. H-12 H-13 ADJACENT WELLHEAD DATA NORTHING .61010,062,74 6,010,033.41 6,009,984;48 ' ' 6,010,013.33 6,010,041,75 6,010,070.40 EASTING 556,624.81 556,617.27 556,478.67 556,487.05 556,495.12! 556,503.05 DISTANCE Feet 119.59 125.22 119.83 89.79 60.24 30.52 REMARKS i · ii East of Conductor H-14 -Southeast of Conductor H-14 South of Conductor H-14 South of Conductor H-14 South of Conductor H-14 South of Conductor H-14 NOTES: 1. All coordinates shown are Alaska State Plane Coordinate System, Zone 4, 'NAD 27. 2. Reference field book: MP97'0o (pgs.31-32, 63-07). 3. Dates of survey: JulY 9-13, 1997. 4. Existing wellhead data from record well.asTbuilts. . ADJ-MP-H. XLS MPU H-14 F.R. Bell and Associates Page 4 of 4 · WELL PERMIT CHECKLISTCOMPANY .~/'~ WELLNAME FIELD & POOL ,_~'"~ ,.~.,/z/c"') INIT CLASS ._/~ _.,/ ,., ,~ ,~ // GEOL AREA PROGRAM: exp [] dev~redrll [] serv [] wellbore seg E] ann. disposal para req ~ UNIT# //',~ .2..<~' ON/OFF SHORE ,,~ ~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N N ENGINEERING APPR. DATE 14. Conductor string provided ................... (.~N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ N 17. CMT vol adequate to tie-in long string to surf csg ........ Y 18. CMT will cover all known productive horizons .......... L_~ N 19. Casing designs adequate for C, T, B & permafrost ....... (~ N 20. Adequate tankage or reserve pit ................. C'~ N 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... (-~ N 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to _.4'oo o .psig. (~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (~ N 28. Work will occur without operation shutdown ........... (~ N 29. Is presence of H2S gas probable ................. Y GEOLOGY 31. Data presented on potential overpressure zones ....... ~ 32. Seismic analysis of shallow gas zones ............. / 33. Seabed condition survey (if off-shore) ............ ~ Y N 34. Contact name/phone for we,ekly,pro¢lress reports ....... ~/ Y N lexplora-tory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION: eEW~/f~/97 DWJ ~ JDH /' Comments/Instructions: HOW/Ijt - A:\FORMS\cheMmt rev 07/97 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. Sperry-Sun Drilling Services LIS Scan Utility Mon Nov 02 15:06:25 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-70240 TOBIAS LOCKWOOD MPH-14 500292279600 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 02-NOV-98 ~_' ~ 34 13N 10E 2949 4133 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 65.70 36.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 REMARKS: 20. 000 112.0 6025.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN #1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PPLASE-4 (EWR4) 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER THE E MAIL MESSAGE FROM D. DOUGLAS FOR K. NITZBERG OF BP EXPLORATION (ALASKA), INC. ON 10/29/98. 4. THIS WELL REACHED A TOTAL DEPTH OF 6025'MD, 4396'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PAHSE 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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.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 RPD 56.0 RPM 56.0 RPS 56.0 RPX 56.0 STOP DEPTH 5971.0 5971.0 5971.0 5971.0 GR 64.0 FET 110.0 ROP 110.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 5978.5 5971.0 6025.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 112.0 6025.0 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 ...................... -999.25 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 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28~_ ~ 8 ~. - Name DEPT GR RPX RPS RPM RPD ROP FET Min 56 8 448 0 355 0 369 0 226 0 179 9 136 0 105 First Max Mean Nsam Reading 6025 3040.5 11939 56 113.9 53.8408 11830 64 2000 18.9694 11831 56 2000 27.7965 11831 56 2000 39.7687 11831 56 2000 45.4155 11831 56 1899.37 208.578 11830 110.5 6.041 0.626036 11723 110 Last Reading 6025 5978.5 5971 5971 5971 5971 6025 5971 First Reading For Entire File .......... 56 Last Reading For Entire File ........... 6025 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/02 Maximum Physical Record..65535 File Type ................ 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 ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.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 RPD 56.0 RPM 56.0 RPS 56.0 RPX 56.0 GR 64.0 FET 110.0 ROP 110.5 $ 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: STOP DEPTH 5971 0 5971 0 5971 0 5971 0 5978 5 5971 0 6025 0 18-AUG-97 5.06 5.46 MEMORY 6025.0 112.0 6025.0 .3 66.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~ 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) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P0819CGR8 P0819CGR8 12.250 12.3 SPUD 9.80 79.0 9.0 700 6.2 3.400 2.900 3.600 4.000 28.4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 Name Min Max DEPT 56 6025 GR 8.448 113.9 RPX 0.355 2000 RPS 0.369 2000 RPM 0.226 2000 RPD 0.179 2000 ROP 9.136 1899.37 FET 0.105 6.041 Mean Nsam 3040.5 11939 53.8408 11830 18.9694 11831 27.7965 11831 39.7687 11831 45.4155 11831 208.578 11830 0.626036 11723 First Reading 56 64 56 56 56 56 110.5 110 Last Reading 6025 5978.5 5971 5971 5971 5971 6025 5971 First Reading For Entire File .......... 56 Last Reading For Entire File ........... 6025 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF ~IT~ SI% ~0 pu~