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Home My WebLink About193-194Pages NOT Scanned in this Well History File XHVZE 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. I ~/,~ ")~ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] 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 by: Bevedy~ncent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si 01'4 OR BEFO W Memorandum To: Re: State of Alaska Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 Oil and Gas Conservation Commission This memo wffi remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to ddll. 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 remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or multilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddil. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods descnbed in AOGCC staff memorandum "Multi-lateral (weiibore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 17, 1993 C. R. Haskell Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit R-35A BP Exploration (Alaska), Inc. Permit No. 93-194 Sur. Loc. 608'NSL, 826'EWL, Sec. 32, T12N, R13E, UM Btmnhole Loc. 2832'SNL, 407'WEL, Sec. 32, T12N, R13E, UM Dear Mr. Haskell: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector'on the North Slope pager at 659-3607. Sincerely, David W Johnston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '-' STATE OF ALASKA " ALASKA ,,.,,~L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work Drill [] Redrill EIIlb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen1-11 Service [] Development Gas I-!- Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 52.7' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(m,, 20 A^C 25.o2s) 608' NSL, 826' EWL, SEC. 32, T12N, R13E Prudhoe Bay Unit At top of productive interval ,8. Well number Number 2963' SNL, 485' WEL, SEC. 32, T12N, R13E R-35A (23.32-12-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 2832' SNL, 407' WEL, SEC. 32, T12N, R13E ' 12/20/93 $200,000.00 12. Distance to nearest :13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD a,d'rVD) property line ADL28282-2446' feet R-10-268'@8100'MD feet; 2560 10901'MD/9248'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s~, 20 AAC 2s.o3s Kickoff depth 2so feet Maximum hole angles2.~' o Maximum surface 3330 pslg At total depth (TVD) 8800'/4390 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 9.7/8" 7-5/8" 29.7# Nr95~S NSCC 10382' 30' 30' 10412' 8812' 615 sx Class "G" 6-3/4" 5-1/2' 17# 130R80 NSCC 639' 10262' 8677' 10901' 9248' 120 sx Class ,( i:L I" I V I: U ,19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary DEC 1 6 Total depth: measured 9480 feet Plugs (measured) true vertical 7345 feet Alaska Oil & Gas Cons. Commission Effective depth: measured feet Junk (measured) Anchorage true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 20" 260 sx AS (Appx) 112' 112' S u rface 3096' 10-3/4" 1000 sx CS il & 3127' 3060' Intermediate 375 sx "G" Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program iTl Drilling fluid progran2~l[] Time vs d,eCth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements r-I 21. I hereby certj~ ~'at the foreg~ng is true,nd correct to the best of my knowledge Signed 4~.,~"'~/-,~'~;~. ~,,_...-~ Title Drilling Engineer Supervisor Date/-~,/~/~..~ Commission Use Only Permit Number IAPI number IApp~r_o~al date JSee cover letter ~._;!~¢-/?¢' 150-,~;--:.¢-.~_¢.-7. ;?.~'.L?'~..~, /I /Cra, -"/'7 '" ~/,~ Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required F'iYes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE F'I2M; 1-13M; ,1t[i.5M; I-]10M; I-I15M; Other: ORIGINAL SIGNED BY by order of Approved by ,RUSSELL A. DOUGLASS Commissioner me commission Date / r~.~ .mA ~mAd ~'~ .m~.~ ~ Form 10-401 Rev. 12-1-85 Submit in tril:,licate I WellName: ]R-35 A Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: Target Location: Bottom Hole Location: 0608' FSL 0826' FWL Sec 32 T12N R13E UM. 2963' FNL 0485' FEL Sec 32 T12N R13E UM. 2832' FNL 0407' FEL Sec 32 T12N R13E UM. I AFE Number: 1 4P0517 I I Estimated Start Date: I Dec 20 1993 I MD: I 10901' I I TVD: Well Design (conventional, slimhole, etc.): I Rig: I Nabors 28-E I Operating days to complete: 114 19248' I IKBE: 1 52.7' I Slimhole producer sidetrack of R-35 Formation Markers: Formation Tops MD TVD (BKB) Ugnu Zone 4A 4573' 4303' West Sak Sands 5959' 5201' Top Seabee 6952' 5973' Kup/Put River Absent IKRU/LCU 8713' 7417' Top Sag River 10412' 8812' Top Shublik 10462' 8855' Eileen Member Absent Target 10554' 8936' Top Sadlerochit 10554' 8936' Total Depth 10901' 9248' Casing/Tubin~ ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 9 7/8" 7 5/8" 29.7# NT95HS NSCC 10382 30/30 10412/8812 6 3/4" 5 1/2" 17# 13Cr80 NSCC 639 10262/8677 10901/9248 N/A 4 1/2" 12.6g 13Cr80 NSCT 10233 29/29 10262/8677 RECEIVED Well Plan Summary hlaska Oil & Gas Cons. Commission Anchorage Page 1 Logging Prog I Open Hole Logs: Surface Intermediate Final I Cased Hole Logs: ram: None None DIL/Sonic/CNL/GR. Optional RFT Possible Gyro and SBT. Mud Program'. I Special design considerations I None Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss to to to to to to to Intermediate Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point §el gel Loss 9.0 35 10 5 10 9.5 5 to to to to to to to 10.4 50 15 10 20 10 10 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8 30 8 3 7 8 6 to to to to to to to 9.2 45 13 10 15 9 8 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, 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: I goP: 1250' I Maximum Hole Angle: 1 52.7 degrees Close Approach Well: R- 10 268' at 8100' MD The above listed wells will be secured during the close approach. RECEIVED Well Plan Summary DEC 1 6 199~ Page 2 Alaska Oil & Gas Cons. Commission Anchorage 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140o F S PACE R: 50 bbls BJ MCS-4 weighted to current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 3 % A-2+0.4 % FL-52 + 0.5 % CD-32 +1 ghs FP-6L for greater than 5 hr thickening time WEIGHT: 11.0ppg YIELD: 3.31 cu ft/sk MIX WATER: 20.92 gal/sk APPROX # SACKS: 350 TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3 %FL-52 + 0.5 % CD-32 + 0.1% A-2 + lghs FP-6L WEIGHT: 15.8ppg YIELD: 1.14 cu ft/sx MIX WATER: 4.85 gal/sk APPROX #SACKS: 265 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: 100-150cc @ 140° F FREE WATER: 0cc CENTRALIZER PLACEMENT: 1 Turbulator centralizer per joint on the bottom 500' of 7- 5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbulator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Pedorm 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 10-12 bpm. DO NOT batch mix tail cement. CEMENT VOLUME: 1. Lead slurry to 5450' (500' MD above West Sak) with 30% excess to isolate Cretaceous interval. 2. Tail G slurry to 1000' MD above casing point with 30% excess. 3. 120' MD 7-5/8", 29.7# capacity for float joints. RECEIVED DEC 1 6 199 A!~.ska Oil & Gas Cons. Commission Anchorage 5-1/2" PRODUCTION LINER CEMENT PROGRAM - BJ SERVICES CIRC. TEMP 1400 F PREFLUSH: 20 bbls fresh water BHST 226 deg F at 8800' TVDSS. SPACER: 70 bbls BJ MCS-4 weighted 1.0 ppg above mud weight. CEMENT TYPE: CLASS G ADDITIVES' 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + 0.5% Gel + 2 ghs FP-10L WEIGHT: 15.7 ppg APPROX #SACKS: 120 FLUID LOSS: < 50 cc @ 140° F YIELD:1.17 ft3/sx MIX WATER: 3.58 gps THICKENING TIME: 45 min @ surface + 3-4 hrs @ 140° F FREE WATER: 0 cc at 45° angle Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. A field fluid loss test on the batch mixed slurry is no longer required. Displace @ 6-8 bpm. LINER CEMENT VOLUME: , . Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar. 150' liner lap (6.750" x 5-1/2") 200' of cement on top of the liner in the 7-5/8" casing. RECEIVED Oil & Gas Cor~s. Com~nissk)n ~nchorage PP. udhoe Bey DP iii,,.© Pmudhoe Bey Un i± R-PAD R-~3~vd. llna I~ytincter' - ~mal Rane NALLIBURTON' 24O° 210° Q.iT~T R3INIS 624 24J0 6~300 6~ 8cjr] . ~ 4~74 81~ 6914D ~i~A ~A N/A ~A 147.44 ~ 44~ 4~I~.~D ~.lO 4~ ~J J ~ ~ 4~7,~ 4~ N/A N/A ~A ~A N/A ~A ~A ~A N/A N/A ~A ~A N/A N/A ~A ~A N/A N/A ~A ~A N/A N/A ~A ~A N/A N/A ~A ~A N/A NIA ~A ~A N/A ~A ~A ~A N/A N/A ~A ~A ~A ~ ~ ~ 4BgI.~ 4.t0 N/A ~A ~A ~A N/A ~A ~A ~A ~A 27~ ~ 6 ~A ~A N/A ~I~ ~ 5~t'~ 3 4~1.45 7~ ~ 747.~ ~.~ ~ ~570 N/A ~A ~A ~A ~A ~A ~A ~A RECEIVED DEC 1 6 1993 Oil & Gas Cons. Commission Anchorage Prudhoe Bey Dr i(iin9 Pr udhoe Boy Unit R-PAD R-35 r-35s-t:wp HALLIBURTON t-[]R]ZEINITAL VIEW CFRUE ixEIR~H) SCALE ~ Fi:. / DIV]SIEN SURVEY REF: WELLHEAD VER'T]CAL VIEW SCALE 500 Ft. / DIV]S]EIN TVD REF: WELLHEAD VERTICAL SECT]EN REP W1SLLHEAD 45.~1]<:> @ 4788 ~ 4B30o 8 4977 MD 51.50° ~ 5188 ~1] 52~ @ 5358 ~.~ e ~g 4~7~ .2.7~o 15(30 34.91° @ 8713 ND I CRIIICAL PC]]NT DATA MD ]nc Az~ TVO No"ih Eos't tbse L--q]I]O 1328 115.]6 1973 -142 248 SV3 / TT4 / %5 3Jl7 17.44 I,7.L::~O ~)51 -275 ~07 T]E IN / K1]~, 5650 ~.6g 69.45 500! -3~4 J~18 / BUILI~ ~.C13 I~G/tOEF ~ / 'l'K4 5959 46.53 68.g8 5__:)01 -840 .S'TARI' E]F ~ 40.C0 (:~3.3~3 543g -15~ 24J7 ~ / BUILD 8 300 BEG/lIDO F1 ~ / BUILD F'T Top .~POk)l;l~ ,04~ L;:>g. 4g 34.37 E~55 1674 / Z4B T A,K:'E[ 'i' J 0b-"54 26.00 '3~.00 Bg'-J:6 t70g TOp HL~Vy ril / J06~ L::>~.O0 ~.00 gO3J J748 To~, Z3 J OC::,g6 L:::~,.O0 3~.00 gO~4 J 7C::~' '3gg7 L.nol DNC JOT"'J4 2~.C]0 g2.00 gC)(P~ J776 J0778 26.CI3 3200 gl'3B J 7cp'3 To'roi De'p'th JOgOJ 26.00 32130 g~48 J1~38 4045 34.91° 8 t03~ lCD Lx:).4c~ 8 104Ex? ND L:600° 8 t0584 ND 3000 35~0 40C0 4503 5000 VERTICAL SECT]EN PLANE: 65,56° RECEIVED DEC 1 6 199,l, A!~sk~ Oil & Gms Con~. Commission Anchorage DO NOT WRITE IN THIS SPACE I ALA OIL AND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend __ Operation Shutdown__ Re-enter suspended well__ Alter casing Repair well __ Plugging x Time extension ~ Stimulate __ Change approved program ~ Pull tubing __ Variance ~ Perforate __ Other x Plugback for redrlll 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 608' NSL, 826' EWL, SEC. 32, T12N, R13E At top of productive interval 3560' SNL, 3300' WEL, SEC. 33, T12N, R13E At effective depth N/A At total depth 3532' SNL, 3230' WEL, SEC. 33, T12N, R13E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3096' Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 9480 7345 Size 20" 10-3/4" feet feet feet feet 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service Plugs (measured) Junk (measured) Cemented 260 sx Arcff*cset (appx) 1000 sx CS 11/375 sx "G" 6. Datum elevation (DF or KB) KBE = 52.7' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number R-35 (23-33-12-13) 9. Permit number 93-181 10. APl number 50- 029-22424 11. Field/Pool Prudhoe Bay Field/Oil Pool Measured depth True vertical depth 112' 3127' 112' 3060' RECEIVED Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation I 12/20/93 16. if proposal was verbally approved Oil X Gas ~ Name of approver Date approved Service 17. I hereby ce~,,j:f~'t~t the foregpihg is true and correct to the best of my knowledge. Signed .-~ _. ,,... Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required lO- Original Commissioner SUBMIT IN TRIPLICATE C~ . k./ ~ ~ O) C)