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Home My WebLink About195-116XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned b~Dianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 200_ .1 PL M A T E E IA L U N D W E R T H IS M ARK E R C:LO~M.DOC Memorandum To: Wen rue: State of Alaska Re: Oil and Gas Con~rvauon Conumss~ Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject wen File. Our adopted conventions for assigning AP! numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies i the treatment of these kinds of applications for permit to ddil. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remair unchanged. The APl number and in some instances the well name reflect the number of preexistin! reddlls and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit witi-. an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9," The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbenng methods descnbed in AOGCC staff memorandum "Multi-lateral (welibore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains - ( Statistical Technician TO: FROM: DATE: SUBJECT: Blair Wondzell, AOGCC Joe Polya, BPX October 2, 1995 hered ervices rilling MPI-06 Target and Botlom Hole Location Changes I am notifying the AOGCC concerning the necessity to change the Target and Bottom Hole Locations for the MPI-08 Schrader Bluff producer well, Reference the following Permits to Drill: MPI-07 Permit Number 95-151 MPI-06 Permit Number 95-116 Should the MPI-06 well be drilled it will be necessary to change the target and bottom hole locations from the permitted: 2566' fsi and 3734' fei Section TI3N R10E to: 2566' fsi and 3599' fei Section T13N R10E. The reason for this change -- The MPI-07 wellbore was planned thru the MPI-06 Schrader Bluff Target as a back-up location in the event the Kuparuk Sands were non-commercial. In that event the MPI-07 will be completed as a Schrader Bluff producer and eliminate the need to drill the MPI-06 well, However, should the Kuparuk sands be commercial in MPI-07, then MPI-06 will be drilled as close to the original target as the Shared Services Drilling close approach guidelines will allow, Please review this information, I will call you requesting guidance to proceed in this matter. Respectfully, BPX Drilling Engineer TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 8, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPI-06 BP Exploration (Alaska), Inc. Permit No 95-116 Surf Loc 2337'NSL, 3845'WEL, Sec. 33, T13N, R10E, UM Btmhole Loc 2566'NSL, 3734'WEL, Sec. 33, T13N, R10E, UM Dear Mr Schofield: 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 from 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 petroleum field inspector 659-3607. David W. ~ohnston Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65 feet Milne Point/Schrader Bluff 3. Address 6. Property Designation P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL 025906 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2337' NSL, 3845' WEL, SEC 33, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2566' NSL, 3734' WEL, SEC 33, T13N, RIOE MPI-06 2S 100302630-277 At total depth 9. Approximate spud date Amount 2566' NSL, 3734' WEL, SEC 33, T13N, RIOE 08-13-95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in propertYi15. Proposed depth (MD and TVD) property line ADL 025517 1546' feet No CloseApproach feet 2560 4212MD/4184 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ¢880 feet Maximum hole anglecz. 48 o Maximum surface 1203 psig At total depth (TVD) 3794'/1578 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.4~ H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 9-7/8" 7" 26# L-80 Btrc 4181' 31' 31' 4212' 4184' 9o4 sx PF 'E', 246 sx TrinityLite-Wate _ 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~"~ Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet ~;!~.~[(.~ (._'iii .& 6~.S Cori~. Cornirlissio[l Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby.....,.,C,certify~t, hat~..~""j~th-~e forage and correct to the best of my knowledge 7/2..~//~, Signed ~'t~ - Title Senior Drilling Engineer Date ' - .' ~/ ' Commission Use Only Permit Number IAPI number Approval date /See cover letter ¢,.2("-,//.,~ J50- ~)2_~- ~-"2'"'"('~1' '~'- ~'" ~fI~f°r other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes No Hydrogen sulfide measures [] Yes [] No Directional survey required ]~i[] Yes [] No Required working pressure for BOPE [] 2M; []3M; E]5M; I--IIOM; 1-115M; Other: Original Signed ,By by order of Approved by David W. Johnston Commissioner [ne commission Date ',~('/'~'/¢~ Form 10-401 Rev. 12-1-85 Submit in t'iplicate ] Well Name: I MPI-06 Well Plan Summary ]Type of Well (producer or injector): ]Schrader Bluff I I Producer Surface Location: 2337' FSL 3845' FEL Sec 33 T13N R10E UM., Ak. Target Location: 2566' FSL 3734' FEL Sec 33 T13N R10E UM., Ak. Bottom Hole Location: 2566' FSL 3734' FEL Sec 33 T13N R10E UM., Ak. [AFENumber: [ 330145 I Estimated Start Date: I 8/13/95 I1VID: 14212' I [Rig: I Nabors 22E I I [Operating days to complete: 14 I IT VD: 14184' bkbI [KBE: 164' [ I Well Design (conventional, slimhole, etc.): 1 7" Uni-Casing Schrader Bluff ESP Producer I Formation Markers: Formation Tops MD TVD (BKB) Formation Pressure Data KOP 1880 1880 - Base Permafrost 1884 1884 - Top NA Sand 3822 3794 EMW 8.0 ppg Target 3822 3794 EMW 8.0 ppg Top NB Sand 3847 3819 EMW 8.0 ppg '~..ii Top NC Sand 3880 3852 EMW 8.0 ppg Top ND Sand 3890 3862 EMW 8.0 ppg Top NE Sand 3901 3873 EMW 8.0 ppg Top OA Sand 3972 3944 EMW 8.0 ppg Top OB Sand 4042 4014 EMW 8.0 ppg Base OB Sand 4062 4034 EMW 8.0 ppg TD 4212 4184 - Casing/Tubing Program: Hole ~ize ~sg/~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 24" 20" 91.4# H-40 Weld 80' 32/32" 112'/112' 9-7/8" 7" 26# L-80 btrc 4181' 31 '/31' 4212/4184' Internal yield pressure of the 7" 26# L-80 casing is 7240 psi. Worst case surface pressure would occur with a full column of gas on top of plugged perfs (no packer) at the reservoir at 3794' tvd. Maximum anticipated surface casing pressure assuming virgin pressure of 1578 psi at 3794' tvd is 1203 psi, which is well below the burst pressure rating of the 7" casing. Logging Program: Open Hole Logs: Production LWD CDR/CDN (GRJRes/Density/Neutron) MDT (SCHLUMBERGER) Cased Hole Logs: GR/CCL (w/out rig on well) Mud Program: [Special design considerations ]None ABOVE PERMAFROST <2000' MD: ] 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 9.0 90 35 15 30 10 15 PERMAFROST TO TD: ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 9.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Lines. Completion Rig (Nabors 4ES) 5000 psi W.P. pipe ram, blind 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: IKoP: 1 1880', S-Shaped } Maximum Hole Angle: I 17.48° Close Approach Well: NONE Disposal: Cuttings Handling: CC2 Fluid Handling: All drilling and completion fluids will be hauled to CC2 for injection. Annular Injection: The MPI-06 well will not have an annulus available for annular pumping since it is being permitted as a single casing well (Same as the MPE-15 drilled in May 1995. Consequently, no drilling or completion fluid will be injected in this well. RECEIVED jUL 2.7 !995 ,~,:, Oii & {/-'las Con,;. Commission Anch0,: o 2, o 4, 5~ 6. 7. 8. 9. 10. 11. 12. 13. 14. MPI-06 Well Operations Summary Drill and set 20" conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. N/U and function test 20" Diverter system. Directionally drill 9-7/8" hole to 4212' MD/4184 TVD. Run Schlumberger's MDT (RFT) tool. Wiper Trip Run and cement 7", 26#, L-80, NSCC casing to surface (perform top job if req'd) N/D Diverter and N/U wellhead -- Test Tree. RDMO Nabors 22E. MIRU Nabors 4ES. N/U BOPE and test. Perforate, hydraulic frac the "N" and "O" sands and then Resin Consolidate (Call Paul Chan at 564-4226 with any questions). Complete well with 2-7/8", 6.5#, L-80 EUEtbg with Electric Submersible Pump (ESP). Set BPV. N/D BOP Stack and N/U x-mas tree. RDMO with Nabors 4ES , Drilling Hazzards and Risks: No drilling hazards or risks have been identified for this well. CASING SIZE: 7" SPACER: 75 bbl fresh water. LEAD CEMENT TYPE: Temp E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX # SACKS: 654 TAIL CEMENT TYPE: MPI-06 7" PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP: 75° F at 4500' TVDss YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50°F Trintiy Lite-Wate ADDITIVES: 2.0% CACL2, 0.2% CFR-3, 0.3% HALAD-344 WEIGHT: 13.2 PPG YIELD: 1.32 ft3/sx MIX WATER: 6.61 gal/sk APPROX # SACKS' 246 THICKENING TIME: Greater than 3 hrs at 50°F FLUID LOSS' 50cc FREE WATER: 0 TOP JOB CEMENT TYPE: (If Needed) Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 PPG YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO. SACKS' 250 CENTRALIZER PLACEMENT: 1.7-1/8" x 9-5/8" Straight Blade Turbulators -- two per joint on the bottom 17 jts of 7" Casing (34 Total). This will cover 300' above the top of the "N" sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator inside of the 20" casing. 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 requirements. Displace at 114 BPM Minimum. Batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry Volume is calculated to cover 500' md above the top of the upper "N" sands with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3.80' of 7", 26# capacity for float joints. 4. Top Job Cement Volume will be 250 sx, if necessary. ~ iii m I I I I I I I I I I I 'SHA'RE'D SI RVICI-S-DRILLING ~(arker I~entification I~ BKB SECT. ,NCLN MIJ/'--I )1~ '1~, A) KB O' 0 0 0.00' ~, ~o,,~,~o ~._~/,oo ,~o ,,o o o.oo VERTICAL SECTION VIEW' cl END e.~/Soo ~U~[O e~ e~$~ ~o~ ~Y.~e ..... , , , · O) DROP 2.5/~00 2723 270S ~9 ~7.4S ~e'Ctjon at: 25,97 E) ENO 2.5/~00 OROP 3a~ 3394 E55 0,00 Fl TARGET ~ 3794 ~5 0,00 TVD Sca]e.' ~ ~nch = 600 feel. <KB> ~ TO 4~ ~e4 a~_ ,o..oo - DeP Scale,' ~ inch - 600' feet' ' ~ " o~e~n ' 07/~/95 · · _ _ ......... ~m _~ ~ i I i i II I ..... ', i I II ~ ..... , ~, --,, ~ .... · . , - ~ ~ - .~ ~ , ,, ,~ _ , .. _ - _ 8 '~500 ............ ' ..... K B ~e~ ---e ............. ~~~-~ ' FEA',SIBI _ITY. P~ N ~T APF'ROS~ED F~R_ __ 2~00 ............. - -- - ' ~ ';~'~"'~ -Z';:' ' ': ",,~', ~ ..... ' .- ;- ;;i . .. . .~ , ..~ . .~ , . ; .... '(;., .,';, ./ .... :-,...,.j ~.. . ,. . . ~ ' ~ ,. _ .' . D ~ " ' '.':?C ' ":" .... ;":' ..........~ ..; .. '. . 3000- - - ......... '~ . "-'-' ... . . ............ ~-~ '~ ~ ~'~;. , ~, , , E ' ' ';~'.,0. ~ '1 '.'. '" ' 3~0..... - ........ ~ -; .. ..... ' ................. ............................ ~-~ ,, . ....,~, ~~ ~;~'~;;,~,'~:~"+" ....;....;. .. ~0= - ........ -= ~ - · ~ ~,.~ ~..~:,~;r., ~,~ r~,.~.... .. .... . ,,., ~.~..,~,.~; ...~; ,.',r ... . . ~ -f~..~: ,/.:; · ...... L~. ' ~'~;? '/'.~· ' ' ~ " ,' .'. , - · aSO0 -.~ .. .. .I, ........ ._ ~ ........ 0 300 B~O go0 t~O0 SSO0 t8~ 2i~ 8400 2700 :'. ','~0':', ,. 3300,...' 3~0 3900 . ....:...:, ::. :.,;,.,[ ' ;. '.'~ : . , · ., o~rt .., ~ Section ure . m II m m mm m mm ..... SHARED S RV lt 't S OR ILL ....... ~,) K~ 0 0 0 ' .~ .o~/~u~o ~.~oo ~o o o ~. PLAN 'VIEW ..~ ~.u~oo ~3 ~ s~~ ' " .... ~ END ~,5/~00 DROP, 34~2 2~g tt~. CLO~URE .... ' ~55 feet a[~;kZj~uth .25.97 T~RGET , SCALE ' J ~nch = 50 feet I' ., . '.,',. , Ana~rj ll " .. 3~5 .............. · .. . [...' 30O ' ' ~ ~. ~ " ~ .... 250~ ' ~5 ....... ~ ............. '., " / F~AS! ~ILI~'Y' Plan . 75--- ~ EX~CU'FIObl . '..r. '.:'f~'~ I';~'~.~ '~,';' ~'~.:L..~..~ .,, ':, .' .. . .. _ ..... ....,~szv'~.~ ,,.. . ..: . .. . .. ,'. ;,~ . ., ~:..,. ,...- . .. . : · .~. .?,. ~..,:;. h, ,. .... ..., .. . . .~ .. i.,.,.'.'~, ... 2 ,, . ~ - , ...... 25 0 25 ~ 75 ~00 ~5 tSO 175 ~00 ~t ,' ~50,,:...,'~7~.. ,.300. 3~5 <-~EST' EAST-> i ' .'.;"'~' :'.'":'.: ":".'."...".; ' i ,, ==m ii - -- Jl WELL PERMIT CHECKLIST ! INIT CLASS ~_~ UNIT# PROGRAM: exp [] dev~ redrll [] serv [] //3 Z 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 drlg 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 ....... ENGINEERING APPR D~ 14. Conductor string'provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. i~ N 17. CMT vol adequate to tie-in long string to surf csg . .~ N 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. 20. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... N 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to '_~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ........ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones. .... Y/N 32. Seismic analysis 9f shallow gas zones ......... / N 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . ./.. Y N [explorator~only] GEOLOGY: ENGINEERING: COMMISSION: comments/Instructions: