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Home My WebLink About191-001TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE:: Bermudaa 11 (KRUU 366 10-7/1) Permit:191-001 DATE: 12/08/2021 Transmitted: North Slope, Kuparuk River Unit, Alaska Via email ___Sidewall Core analysis report – BP-3-1410* Depths are coded in main report. Depth Key is provided on page 13. *Data requested by AOGCC Dec. 6, 2021. Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: Bermuda 1 - e-transmittal well folder Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 12/08/2021 37' (6HW By Abby Bell at 4:43 pm, Dec 08, 2021 OH OR BEFORE 0 NOVEMBER 2 200 PLUGGING & LOCATION CLEARA/~CE R~PORT State of Alaska .ALASKA 0IL & GAS CONSERVATION COMI(ISSION .. Memorandu_m To File: APi No. Well }lame 0Derator Spud, l-' 2-{-7/, Note casing size, wt, depth, cmt vol, & procedure. Per.= intervals - tops Review the well file, and-comment on plugging, well head status, and location clearance - provide loc. clear, code. Well head c~t off: ' ~ Marker post or plate: Location Clearance: Conclusions: Code Signed Date · o TO: ARCO Alaska, Inc. Post Office Bo^ lr00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 SAMPLE Robert Crandall AK Oil/Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (754-6247) OPERATOR: ARCO AK, INC. SAMPLE TYPE: Dried Cuttings SAMPLES SENT: 200-2542 2542-4100 4100-5690 5690-6540 6540-6760 SENT BY: Angie Langston TRANSMITTAL DATE' 23 March,1993 AIRBILL #:AL646216 AFT#' 03-03-23-53 CHARGE CODE# 18503 NAME' Bermuda 36-10-7 #1 NUMBER OF BOXES: 5 UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P. O. BOX 100360 ,¢/ /// ANCHORAGE, AK. 99510 RECEIVED /' ./~"7...- ..--.,~J~'~ DATE' ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Al~3B 0003 C TO: THRU: FROM: MEMORANUUM St [e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C Smith Commissioner DATE: FILE NO: TELEPHONE NO: SUBJECT: Louis R Grimaldi Petr Inspector October 8, 1991 LG108.DOC Location Clearance ARCO KRU 36-10-7-1 Permit 91-1 Exploratory Sec 36,T10N,R7E,UM I flew to ARCO's exploratory site KRU 36-10-7-1 (known as the Bermuda Prospect). I found this location to be in extremely good shape. The surrounding area shows no evidence of the activity that was there. The marker post had the proper information, but was not attached to the casing stub firmly enough. It broke loose when I shook it. Tom Anglen will reattach it, take pictures of this operation, and send these to the Commission. In summary, when proof of the marker post repair is received, the location clearance requirements will be satisfied. Attachment 02-00lA (Rev. 6/89) 20/11LYIEMO1.PM3 ALASKA OIL AND GAS CONSERVATION SURFACE-ABANDONMENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: .. ..... operator ,' /~-~O'~C ~ ~ Address Surface Location of Well'. ¥'7/?': Sec.3& , T/O ___.~, R? ~, ~. 20 AAC 2~.120: WELL ABANDONMENT MARJfER: Dia. Steel Post (4"Min'.) 4.--~' , Length (10' Min.) Height Above Final Grade Level (4' Min'.') 7 ~ Top of Marker Pipe Closed with: Cement Plug .. Screw Cap Set: On Well Head ~, On Cutoff Casing Z/, In Concrete Plug Distance Below Final Grade Level ~D Ft. / / in. Side Outlets: All Valves and Nipples Removed Ail Openings Closed , With Blinds .... , With Cement Date Do,,,mhole P & A 6~ /~,/~"/ ' ,o., '?/-/ ' ':'. A~I No. 50-/~.~-~/ Unit or Lease N~e Field & Pool .. Welds / ". , ,, .. .. , Other INFORMATION BEADWELDED DIRECT~LY TO MARKER POST: (List h~ere~iffe~en~ from 'File Information) ' ' . . ~ ....... iGlp/.~ f%,gl~tz'l~ Unit or Lease Name ~F~.~.~J~. l /wu,c..--o" I''''~'~'ffl ..~'~ 17 ,,, Well N-aber ~'~{d ,~'~"/0' ~ **i , Surface Location of Well: .., · 20 AAC 25.170: 'LOCATION CLEAN-UP B ITS: · "' 'Filled In .,. , Liners Removed or Buried ..., Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough , Smooth , Contqured , Flat Other ' ' ' , Compact~ed' CLE.~N UP OF PAD ~ND/OR LOCATION: Clean_~, Pipe Scrap Paper , , Other .... ~RECO~ME.~D APPROVAL OF ABANDONMENT: Yes ~/,' N° Final Inspection '7r-"~-./-7'..; -' .... , --_ ~ - _ ,~ .' ,. ..,,.,, . ~.. - 05/26/8I ' ' ':' "==~'=- ""-" .: .._~ ..~' i.J SURROUNDING AREA: " Wooded ', Brush Sand , Other ,, CONDITION SURROUNDING AREA: clean L/'' Trash from Site .... , Trees and/or Brush from Clearing Site_ ¢ . · Other ' .' . ACCESS ROAD: ' :-'- Dirt_, Gravel , Ice,,~,,, Other "- ,. CONDITION ACC/SS ROAD AND SURROUNDING: Clean ~, Rough , Smooth , Trash from Operations , " ' Trees '~nd/or Brush from Clearing R----~ad , Spoil from Clea~ing Road _, "-.:...',: Other --, · ._. .,, , Iron Scrap :, Wood , Mud , Cement , _ ...... , Tundra . Grass ._....._, Dirt .... , ..Gravel......._._, ........ ALAS KA OIL AND GAS CONSERVATION COMMISSION TO: FROM: Lonnie C. Smith DATE: Commissioner Louis R.Grimaldi Petroleum Inspector FILE NO: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 9, 1991 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Attn: Robert P. Crandall Re: Geological Data and Logs ARCO Bermuda 36-10-7 #1 Well 1464' FNL, 714' FWL, Sec. 36, TION, R7E, U.M. Kuparuk River Unit, Alaska Gentlemen: Pursuant to 20 AAC 25.071, enclosed are the required geological data and logs for the above referenced well. All of said data and logs are described on the attached Transmittal/Receipt. Please execute the Transmittal/ Receipt after you verify that all described data and logs are enclosed. Return said Transmittal/Receipt to Richard A. Levinson at the indicated address after execution. ARCO appreciates your efforts to keep these data and logs confidential pursuant to AS 31.05.035 (c) for a period of 24 months following the 30 day filing period. If you have any questions please call me at 265-6914. ,~~. R. ~ii/e~~er / Landmay // JRW:sg:317 RECEIVED APR 1 0 1991 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany All:~[-:~ 600:~ (3 ARCO Alaska, Inc. Post Office Box ~d0360 Anchorage~ A~aska 99510.-03~/~0 'Telephone 907 276 12t5 Date: Subject: From/Location: Telephone: To/Location: Dear Bob, April 08, 1991 Geological Markers Encoun~ R.A. Levinson ANO 956 x 1652 Robert P. Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK. 99501 The following is a list of geological markers encountered in the ARCO Bermuda 36-10-7 #1 well. Depths are reported/as MD (Subsea). Top Kuparuk Upper Mbr. 6443' (-6278') Top Kuparuk Lower Mbr 6447' (-6282') Top Kingak 6554' (-6389') TI) 6750' (-6585') Let me know if you haVe any questions. Cheers, R.A. Levinson Sr. Geologist ARCO ALASKA INC. P.O. Box 100360 Anchorage, AK. 99510-0360 AF~CO Alaskm Inc. is a Subsidiary of A!lanticBichfieldCompany RECEIVED APR 1 0 I~ ~ Anchorage)o:~°tnmissi°~' ARCO Alaska Inc. Atl anticRichfield Company TO: Robert P. Crandall Ak. Oil & Gas Conserv. Comm. 3001 Porcupine Dr. Anchorage, AK. 99501 FROM: Richard A. Levinson ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Ak. 99510 DATE: March 19, 1991 Transmitted herewith is the following: Sepias 5"LDT 2"LDT 5" Phaser DIL 2" Phaser DIL 5" Microlog 5" HLDT-CNL-GR in Casing 2"+5" LSS RFT log . Mudlog ~ Mudlog~ 1 Tape-Digitized log data 1 Verification Listing of digitized lo ta 1 List of Geological ers Bluelines 5" LDT- 2" LDT- 5" Phaser DIL ~ 2" Phaser DIL / 5" Micro Log - 5" HLDT-CNL-GR in Casing 2" + 5" LSS-~ RF~ log. RECEIVED APR I () 1991 Alaska 0il & Gas Oons. Commission Anchorage Approved for transmittal by: T. L. HudsonO ' '~'-~ ' -' Manager - Dev. Geoscience Receipt: Return receipt to: Lists/301 ARCO Alaska, Inc. ATTN:Richard A. Levinson ANO 956 P.O. Box 100360 Prepared by: Glenn Smith 700 "G" Street Anchorage, AK 99510-0360 ARCO Alaska, Inc. Bermuda 36.10-7 #1 APl 50-103-20149-00 Sec. 36, TION, R7E, U.M. R.A. Levinson3/18/91 Depths are measured from HRI log. P=Percussion SWC 45' shot 39 Recov. R=Rotary SWC 49 drilled CORE DEPTH TYPE DESCRIPTION 3971 P 4029 P 4102 P 4242 P 4438 P 4552 P 4567 P 4572 P 4855 P 5091 P 5332 P 5448 R 5464 P 5498 P 5503 R 5505 P 5506 R 5506 P 5519 P 5520 P 5521 R 5522 R 5523 R 5528 R 5532 R 5532 P 5540 R 5540 P 5541 P 5542 R 5542 P 5558 P 5561 P 5563 P 5565 P 5569 P 5573 R 5575 R 5584 R 5589 P 5595 R 5617 P 5627 R 5706 P 5833 P 5838 P 5848 P 5850 R SHALE SHALE SHALE SHALE SHALE SANDSTONE, POROUS SANDSTONE, POROUS SANDSTONE, POROUS NO RECOVERY SHALE SANDSTONE SANDSTONE, OIL,STAIN SHALE SANDSTONE SANDSTONE, SANDSTONE SANDSTONE, SANDSTONE SHALE SANDSTONE SANDSTONE, POROUS,OILSTAIN SANDSTONE, POROUS,OILSTAIN SANDSTONE, POROUS,OK,STAIN SANDSTONE/SILTSTONE SANDSTONE, POROUS,OILSTAIN SANDSTONE SANDSTONE, POROUS,OILSTAIN SANDSTONE SANDSTONE SANDSTONE SANDSTONE SANDSTONE SANDSTONE SANDSTONE SANDSTONE NO RECOVERY SANDSTONE, POROUS,OILSTAIN SANDSTONE, POROUS SANDSTONE, POROUS SANDSTONE SANDSTONE SHALE SHALE/SANDSTONE SHALE SHALE SHALE SANDSTONE, OILSTAIN SANDSTONE POROUS,OILSTAIN POROUS,OILSTAIN ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany PAGE 1 OF 2 AR3B-6OO1-B RAL/dks/701 ARCO Alaska, Inc. Bermuda 36-10-7 #1 APl 50-103-20149-00 Sec. 36, TION, R7E, U.M. R.A. Levinson3/18/91 Depths are measured from HRI log. P=Pcrcussion SWC 45' shot 39 Recov. R=Rotary SWC 49 drilled CORE DEPTH TYPE DESCRIPTION 5858 R 5858 P 5863 R 5876 R 5878 P 5889 R 5890 P 5942 P 5982 P 6048 P 6280 P 6414 P 6424 P 6439 R 6444 R 6n.45 R 6445 P 6446 R 6446 P 6447 R 6448 R 6449 R 6450 R 6451 R 6452 R 6453 R 6454 R 6455 R 6456 R 6457 R 6458 R 6460 R 6461 R 6465 R 6479 R 6482 R 6492 P 6495 R 6504 R 6510 R 6526 R 6529 R 6535 P 6546 R 6549 R 6552 R SANDSTONE, OILSTAIN SANDSTONE SANDSTONE SANDSTONE/SHALE SANDSTONE SHALE SHALE NO RECOVERY · NO RECOVERY SHALE SHALE NO RECOVERY NO RECOVERY SILTSTONE SANDSTONE, OILSTAIN SANDSTONE, POROUS,OILSTAIN SHALE SANDSTONE,OILSTAIN SANDSTONE SANDSTONE, OIL STAIN SANDSTONE, POROUS,OILSTAIN SANDSTONE/SHALE, OIL STAIN SILTSTONE/SANDSTONE, OIL STAIN SHALE/SILTSTONE/SANDSTONE, OIL STAIN SHALE/SILTSTONE/SANDSTONE, OIL STAIN SANDSTONE, OIL STAIN SANDSTONE/SHALE, OIL STAIN SANDSTONE/SHALE, OIL STAIN SANDSTONE/SHALE, OIL STAIN SANDSTONE/SHALE SANDSTONE SANDSTONE/SHALE SHALE/SANDSTONE SHALE/SANDSTONE SHALE/SANDSTONE SHALE SHALE SHALE/SILTSTONE SHALE SHALE SILTSTONE/SHALE SHALE/SILTSTONE SHALE SILTSTONE/SANDSTONE SHALE/SILTSTONE SHALE ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany PAGE 2 OF 2 AR3B-6OO1-B RAI. Jdks/701 i, : STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ..//~7:~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 'Status of Well Classification of Service Well OIL F'~ GAS [~ SUSPENDED [-'-] ABANDONED r~ SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-01 3 Address , 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20149 4 Location of well at surface ~ .... ~ .~P~,'~i'~i' :"" , ........ 9 Unit or Lease Name 1,464' FNL, 714' FWL, SEC 36, T10N, R7E UM ,~ r.,~-,-. ', ,"--%,,~l'lON,$ [ KUPARUK RIVER UNIT AtTop Producing Interval ~ ~.~,~7._:_..~.~/ ~ ~ ~.. [ 10 Well Number N/A ~ ~'~'flt~;'~ .:; 3~;-,_,~...,p_._! KRU 36-10-7 #1 At Total Depth ~;~C [I!-~ ~b.~'~1 11 Field and Pool 1,342' FNL, 763' FWL, SEC 36, T10N, R7E UM KUPARUK RIVER UNIT 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 167', PAD 125' GLI ADL: 25609 ALK: 2604 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 1/21/91. 1/27/91. 2/2/91. N A feet M SL NA ~7 Tota~ Depth (MD+TVD) ~8 P~ug Back Depth (MD+TVD) lg D~rectiona~ Survey 120 Depth where SSSV set I 21 Thickness of permafrost 6750' MD & 6747' TVD SURFACE YES [~]~ NO r-~I NONE feat MDI 1350' APPROXIMATE 22 Type Electric or Other Logs Run HLDT, SFL, CNL, ML, AC, VSP~ GR, SP 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 6~.5# H-40 SURF 122' 24" 218 SX AS II 9-5/8" 36# J-55 SURF 2521' 12-1/4" 580 SX PERM "E" & 300 SX PERM "C" 24 Perforations open to Production (MD+TVD of Top and Bottom ~nd 25 TUBING RECORD interval, size and number) SIZE DEPTH SET IMD) PACKER SET IMDI NONE 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL IMD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ I--low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL .GRAVITY-APl (corr) Press. 24-HOUR RATI: ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. SEE ATTACHED ADDENDUM Form 10-407. Submit in duplicate Rev. 7-1-80 C(~TINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. WEST SAK TOP 1727' 1727' NA WEST SAK BOTTOM 2347' 2347' K- 10 COLVILLE TOP 2827' 2827' K-5 TOP 4017' 4017' C SAND TOP 6567' 6567' A SAND TOP 6592' 6592' : 31. LIST OF ATTACHMENTS SUMMARY OF OPERATIONS~ CO~ O,a,T,~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~L,~~ ~ Title AREA DRILLING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 pedinent 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO L and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official lest is not required upon completion, repod completion and representative test data in blocks provided. The "Final Report" form may be used for reporting Ihe entire operation if space is available. r District County or Parish I State ARCO ALASKA INC. NORTH SLOPE I AK Field Lease or Unit |Well no. KUPARUK ADL: 25609 ALK: 2604 KRU 3q-10-~ #! Auth. or W.O. no. Title AK5601 DRTLL & ?/A Accounting cost center code Operator A.R.Co. W.I. ARCO 100.0000 Spudded or W.O. begun Date SPUD 01/21/91 I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 20:30 Date and depth as of 8:00 a.m. 02/03/91 (13) TD: 0'( SUPV:JRR Complete record for each day reported POOL 7 RIG RELEASED 9-5/8"@ 2521' MW: 0.0 VIS: 0 EST INJ RATE THROUGH EZSV. SQZ 50 SX CLASS'G' BELOW RETAINER AND DUMP 25 SX ON TOP. TOC = +/-2430' LDDP. TEST CSG AND PLUG TO 2000 PSI. OK. ND BOP'S AND BRADEN HEAD. GIH TO 200' CIRC IN 90 SX SURFACE PLUG. LDDP. RR @ 00:00 HRS 03-FEB-91. DAILY:S132,406 CUM:$1,869,215 ETD:S1,869,215 EFC:$1,980,000 Old TD I New TD PB Depth Released rig I Date Kind of rig I Classifications (oil, gas, etc.) Type completion (single. dual. etc.) Producing method Official reservoir name(s) Potential test data __ Well no. Date Reservoir Producing Interval Oil or gasTest time 'Production Oil on test IG i / _.. Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable E"~ corrected The above is correct S i g n at ~.e"'"' ' ~' -- Date, T,~le /¢ ~_,, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Actual P&A Schematic KRU 36-10-7 #1 Bermuda Prospect cellar cap Surface plug from 200' to surface 90 sx Permafrost 'C' @ 15.5 ppg 16" @ 80' GL, 122' md 12-1/4"OH x 9-5/8" annulus = .0558 bpf > 10.1 ppg drilling mud TO C @ +/- 25 sx Class 'G' dumped on retainer EZ Drill Retainer @ 2499' 50 sx Class 'G'@ 15.8 ppg sqz'd below retainer 10.1 ppg drilling mud ~ Open hole plug extending f/ 5716' - 5223' 200 sx Class 'G' @15.8 ppg Avg of 9-1/4" hole via caliper log = .083 bpf (1 0.1 ppg drilling mud) Open hole plug extending f/6651' to 6231' 170 sx Class 'G'@ 15.8 ppg 10.2 ppg drilling mud cement plugs 9-5/8" @ 2521' md, 2521' tvd ID=8.921", cap=.0773 bpf TD = 6750' md, 6748' tvd LRC 2-5-91 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions:' Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded yTOrkover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates o°nrl . District ICounty, parish or borough [State ARCO ALASKA INC. I NORTH SLOPE ] AK ]Well,o. Field ILease or Unit KUPARUK I ADL: 25609 ALK: 2604 KRU 3(~-10-7 #! Auth. or W.O. no. ITitle AK5601 J DRILL & P/A Operator ARCO WI ARCO I J Prior 100.0000 Spudded or W.O. begun JDate JHour status if a W.O. SPUD 01/21/91 20: 30 Date and depth as of 8:00 a.m. 01/22/91 (1) TD: 837'( 837) SUPV:JRR 01/23/91 ( 2) TD: 2542' ( 1705) SUPV:JRR 01/24/91 ( 3) TD: 2542' ( 0) SUPV:JRR 01/25/91 ( 4) TD: 4063' (1521) SUPV:JRR 01/26/91 ( 5) TD: 6287' (2224) SUPV:CTD 01/27/91 ( 6) TD: 6732'( 445) SUPV:CTD 01/28/91 ( 7) TD: 6750' ( 18) SUPV:CTD Complete record for each day reposed POOL 7 DRILLING 16"@ 122' MW: 8.6 VIS: 58 FINISH RIGGING UP. ACCEPT RIG @ 1600 HRS 1-21-91. PU BHA. DRILLED TO 150'. M'WD FAILURE. POH & CHECK MWD. DRILLED TO 295'. MWD FAILURE. POH & CO MWD. RE.Z~VJED AND LOGGED F/205'-295'. DRILLED TO 837' DAILY:S560,193 CUM:$560,193 ETD:S560,193 EFC:$1,980,000 RUNNING 9-5/8" CASING 16"@ 122' MW: 9.4 VIS: 51 DRILLED T0 2542'. ST. POH FOR CSG. RU WEATHERFORD. PAN 57 JTS OF 9-5/8" SURFACE CASING. DAILY:S63,993 CUM:$624,186 ETD:S624,186 EFC:$1,980,000 PICK UP BHA 9-5/8"@ 2521' MW: 0.0 VIS: 0 FINISH RUNNING TOTAL OF 61 JTS 9-5/8" 36# J-55 BTC SURFACE CSG. CMT'D CSG WITH 580 SX PERMAFROST 'E' FOLLOWED BY 300 SX PERMAFROST 'C'. REC'D 42 BBLS OF CMT AT SURFACE. PLUG BUMPED AND FLOATS HELD. CIP @ 1100 HRS, 23-JAN-91. ND DIVERTER. MU WELLHEAD. NU BOP STACK AND TEST SAME. PU 8-1/2" BHA. DAILY:S160,925 CUM:$785,111 ETD:S785,111 EFC:$1,980,000 DRILLING 9-5/8"@ 2521' MW: 8.9 VIS: 36 FIN PU BHA. PU 33 JTS DP. TAG FC @ 2440'. TEST CSG TO 2000 PSI, OK. DRILLED OUT AND PERFORMED PIT=12.5 PPG EMW. DRILLED TO 4063' DAILY:S86,668 CUM:$871,779 ETD:S871,779 EFC:$1,980,000 DRILLING DRILLED TO 6287' 9-5/8"@ 2521' MW:10.0 VIS: 51 DAILY:S72,127 CUM:$943,906 ETD:S943,906 EFC:$1,980,000 DRILLING 9-5/8"@ 2521' MW:10.0 VIS: 48 DRILLED TO 6302'. TFNB. DRILLED TO 6732'. DAILY:S97,375 CUM:$1,041,281 ETD:S1,041,281 EFC:$1,980,000 LOGGING 9-5/8"@ 2521' MW:10.2 VIS: 44 DRILLED TO 6750'. ST. POH FOR LOGS. DOWN LOAD LWD LOGS. RU SCHLUMBERGER AND GIH W/ TRIPLE COMBO. COULD NOT GET PAST 3072' MADE CONDITIONING TRIP. RU SCHLUMBERGER AND GIH W/ ROTARY SWC TOOL. DAILY:S215,324 CUM:$1,256,605 ETD:S1,256,605 EFC:$1,980,000 The above is correct For form ~ra~n and di~ribut¢, see ProceSs ~nual, Section Drilling, Page~nd 87. AR3B-459-1-D INumber all dally well histo~ forms consecutively they a~ ARCO Oil a,,= G'as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show Iormation name in describing work performed. Number all drill stem tests sequentially. Attach description of aJJ cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnterl~l" sheets when lilled out bul not less trequenIly than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workoverS and following setting of oil strinG until completion. District IC°unty® lStale ARCO ALASKA INC I NORTH SLOPE AK KUPARUK J ADL; 25609 ALK: 2604 ~U 36~!0-'? ~] Date and depth Complete record for each day while drilJing or workover in progress as of 8:00 a.m. 01/29/91 (8) TD: 6750' ( 0) SUPV:CTD 01/30/91 ( 9) TD: 6750'( SUPV:CTD 01/31/91 (10) TD: 6750'( SUPV:CTD 02/01/91 (11) TD: 6750'( SUPV:JRR 02/02/91 (12) TD: 2499'( SUPV:JRR POOL 7 LOGGING LOG OPEN HOLE. 9-5/8"@ 2521' MW:10.1 VIS: 41 DAILY:S62,129 CUM:$1,318,734 ETD:S1,318,734 EFC:$1,980,000 GIH W/ BHA 9-5/8"@ 2521' .MW:10.1 VIS: 39 MADE CONDITIONING TRIP. TOOK RFT'S AND SWC'S. RD SCHLUMBERGER. GIH W/ BHA. DAILY:S64,341 CUM:$1,383,075 ETD:S1,383,075 EFC:$1,980,000 WOW 9-5/8"@ 2521' MW:10.1 VIS: 40 LD BHA. PU DP FOR SETTING PLUGS. WOW AND CMT TRUCK FOR P&A. MADE CONDITIONING TRIP. POH INTO CSG AND CONTINUE TO WOW. DAILY:S229,822 CUM:$1,612,897 ETD:S1,612,897 EFC:$1,980,000 GIH 9-5/8"@ 2521' MW:10.1 VIS: 41 CIRC AT 9-5/8" CSG SHOE AND WOW. GIH TO 6651' AND CONDITION HOLE. POH TO CSG SHOE. GIH FOR P&A WHILE RU HALLIBURTON. DAILY:S61,183 CUM:$1,674,080 ETD:S1,674,080 EFC:$1,980,000 PREPARE TO MIX CEMENT 9-5/8"@ 2521' MW:10.1 VIS: 38 FGIH. WASH TO 6651'. SPOT 170 SK CLASS 'G' BALANCED PLUG F/6651'-6231'. POH 10 STDS AND CIRC DP VOLUME. LDDP. GIH TO 5716'. SPOT 200 SK CLASS 'G' PLUG F/5716'-5223' POH 10 STDS AND REV CIRC. LDDP. FPOH. GIH W/ 9-5/8" EZSV. SET @ 2499'. PREP TO CMT. ~"~AILY:$62,729 CUM:$1,736,809 ETD:S1,734,080 EFC:$1,982,729 The above is correct For ~rm p(~'para, ti~n and diS~rib~on see I-'roced~es MaJnuat SectionklO, \ Drilling, Page~and 87 AR38-459-2-B INumber all dally well history Corms consecutively as fhey are prepared for each well PERMIT ~ ~;~/ - / WELL NAME /~'(.~ .~ o~ /o- ~/. . ,. COMPLETION DATE I .......... ~OGCC GEOLOGICAL MATERIALS INVENTORY LIST ' { check, off or list data as it is received ! "07 ! drilling history /'"survey !/I t~sts I core dcsription cored inte~als, core anal~,is' ~.~ d~ ditch intewals ,,, digital data Ill Il I I Il I I III I I I I I I , , LOG TYPE RUN INTERVALS SCALE NO. / · ,~ J ,,, / ~] ~ __ ,, ,, 11] ~] , , ,, 13] ,,, ,, ,, , , 1si ,,~ ,,, , 1si ,OILAND GAS CONSERVATION COMMI,. )N- .- ,J ~. - ?~?~.~'--....~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1464' FNL, 714' FWL, Sec. 36, T10N, R7E, UM At top of productive interval N/^ At effective depth N/A At total depth 1342' FNL, 763' FWL, Sec. 36, T10N, R7E, UM 12. Present well condition summary Total Depth: measured true vertical 6750 6750 feet feet 6. Datum elevation (DF or KB) RKB 165 7. Unit or Property name Kuparuk River Unit f~et 8. Well number · KRU 36-10-7 #1 (~,':~u,~.~) 9. Permit number 91-01 10. APl number 50-1 03-201 49 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) See attached Effective depth: measured true vertical N/A N/A feet Junk (measured) None feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 2521' 9 5/8" N/A measured Cemented 218 Sx AS II 580 sx Perm 'E' 300 sx Perm 'C' Measured depth True vertical depth 122' 122' 2521' 2521' RECEIVED true vertical Tubing (size, grade, and measured depth N/A Packers and SSSV (type and measured depth) N/A FEB - 8 t991 Alaska 0ii & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~X P&A Exploratory well. (Wellbore schematic attached). 14. Estimated date for commencing operation Completed 2-2-91 16. If proposal was verbally approved Mr. Lonnie Smith 1 - 2 5- 91 Name of approver Date approved 17. I~hereby,~-e~at the foregoing is true and correct to the best of my knowledge. c.._~,,z, ~_ . ../ ,, , ,,c'o.,~ ,,4 ~ ~c~,~,,/~ Si~ned //t~//'~~/ Title Area Drilling Engineer FOR COMMISSION USE ONLY Detailed operation program_ BOP sketch_ 15. Status of well classification as: Oil __ Gas __ Service Suspended Conditions of approval: Plug integrity Mechanical Integrity Notify Commission so representative may witness,, BOP Test ~ Location clearance .~ Test ~ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY i nMl~liC ~ qMITH JAppro~val No. C~~or Date;' /3~ ~/ SUBMIT IN TRIPLICATE P&A Sundry Supplement KRU 36-10-7 #1 Bermuda Prospect The KRU 36-10-7 #1 was P&A'd because hydrocarbons were not present in economic quantities. No geo-pressured zones were encountered while drilling the well. The well was plugged once open hole logging operations were completed. Open hole and cased hole cement plugs were placed per the attached schematic which includes descriptive information on the plugs. Prior to setting the final surface plug, the 9-5/8" surface casing was tested to 2000 psi 1/2 hour. It should be noted that 10.0 ppg was the maximum mud weight utilized while drilling to TD. Status Completed steps: All plugs have been spotted or set. The braden-head has been removed. Remaining Steps (after rig move): Cut off 16" and 9-5/8" casings at base of cellar. Weld cap across top of 16" conductor. Install P&A marker post with appropriate information bead-welded to post. Remove cellar culvert and fill in cellar with clean gravel material. Haul cuttings to KRU disposal site. Clean location. RECEIVED FEB - 8 t991 Alaska 011 & Gas Cons. C;ommissiot~ Anchorage Actual P&A Schematic KRU 36-10-7 #1 Bermuda Prospect cellar cap Surface plug from 200' to surface 90 sx Permafrost 'C' @ 15.5 ppg 16" @ 80' GL, 122' md 12-1/4"OH x 9-5/8" annulus = .0558 bpf 10.1 ppg drilling mud TO C @ +/- 25 sx Class 'G' dumped on retainer EZ Drill Retainer @ 2499' 50 sx Class 'G' @ 15.8 ppg sqz'd below retainer 10.1 ppg drilling mud ~ Open hole plug extending f/ 5716' - 5223' 200 sx Class 'G' @15.8 ppg ^vg of 9-1/4" hole via caliper log = .083 bpf (1 0.1 ppg drilling mud) Open hole plug extending f/6651' to 6231' 170 sx Class 'G' @ 15.8 ppg 10.2 ppg drilling mud I~ = cement plugs 9-5/8" @ 2521' md, 2521' tvd ID=8.921", cap=.0773 bpf RECEIVED FEB - 8 t99~ Alaska Oil & Gas Cons. Commission Anchorage TD = 6750' md, 6748' tvd LRC 2-5-91 D~TH 0.00 0.0 0.00 203.22 203,2 203.22 232.15 28.9 232.14 414.50 182.3 414,39 602,03 187,5 601,~ 764,41 ~,.,.~,74 1137.72 1140,46 1537.16 1563,42 1747,79 2174.42 2450,30 2~39.33 334.25 3403.12 3496.89 3590,O6 3680,94 377'5,~ 3871.18 4~5.28 4794.87 5254.70 5711,00 6193.40 6646.04 182,4 784.3O 174,3 958.63 179.0 1137,61 2,7 1140.35 3?6.7 1537,03 26.3 184.4 1747.67 426,6 2174.29 275,9 2450.17 459.0 2939.17 94,9 3034,0B 3,68,9 3402,91 93,8 3496.65 93,2 35~9,79 90,9 361~.63 ~.0 3775.60 ~.2 3870.78 4,64.1 4334.68 459.6 459.8 5253.42 456,3 5709.3~ 4~.,4 6191,45 452.6 6,643.82 ~ RNA1)RILL ~ CAU:ULJ~TI~ RADIUS T~'I~'T S'I'ATI~ ~IIq.111.1~TI1'1.1)£ S]~'TIOI, I INL'LN. K/-S f,t dq ft 0,00 0,00 0.00 0,00 0,67 0,~ 356,43 0.67 1.47 2,87 19.22 1,47 6,53 0.51 20.69 6.53 7,57 0.14 354.46 7.57 -' ORI F,/-w ft ft de9 lOOft 0,00 0.00 0.00 0,00 -0.02 0.67 3'58.21 0,18 0,09 1,45 3.49 8,74 1,72 6.80 16.43 1,29 2,05 7,64 15.25 0.21 7,92 0.09 34.52 7,92 8,02 0,03 85.03 8.02 7.65 0,33 195.80 7.65 7,63 0,54 136.13 7,63 8,04 0.26 23.48 8.04 2,15 8,20 15,22 0,05 2,33 8,35 16,19 0,04 2,64 8,09 19,02 0,19 2.64 8,07 19,10 17.16 4,95 9,45 31,62 .0,17 8.14 0.44 76.66 8.14 8.23 0,11 92,20 8,23 7,52 0.26 151.~ 7.52 6.32 0.45 118,82 8,32 7,18 0,74 40.23 7.18 5,07 9,59 31.91 1.33 5,94 10,15 35,85 0,18 7,07 10,33 43,23 0.05 8.26 10,41 52,57 0.10 12,86 14,73 60.85 0.16 8.39 0.84 35'5.49 8,39 13.83 0.91 ~.41 13.83 15.69 1.59 25.24 15,69 18,08 1,64 23.04 18,08 20.54 1,72 22.97 20.54 13.25 15.69 57.67 0,~4 14.16 19,79 45.68 0.12 15.00 21,71 43.71 0.72 16,07 24,20 41.63 0,08 17,12 26.74 39,80 0.08 23,13 1,66 23,69 23.13 25,67 1,63 18,46 25,67 38,72 1,75 16.94 38,72 54,61 2.35 12.59 54,61 73.13 2,40 15,97 73,13 18,23 29.45 38,25 0,06 19,21 32,06 36,81 0.16 23,38 45,23 31,12 0,03 27.57 61.17 26.78 0,13 32.28 79,93 23,82 0,03 89,82 2,03 21,74 89,82 10~,50 2,16 16,04 106,50 121,27 1,81 22,88 121,27 37,98 97,52 22,92 0.09 43,69 115,12 22,30 0,05 48,91 130,76 21,96 0,0~ RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION January 11, 1991 STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 2794433 A. W. McBride Area Drilling Engineer ARCO Alaska P. O. Box 100360 Anchorage, AK 99510-0360 Re: Well No. Kuparuk River Unit 36-10-7 #1 Company ARCO Alaska, Inc. Permit No. 91-01 Sur. Loc. 1464'FNL, 714'FWL, Sec. 36, T10N, R7E, UM Btmhole Loc.1464'FNL, 714'FWL, Sec. 36, T10N, R7E, UM Dear Mr. McBride: 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. Sufficient notice must be given to allow for a representative of the commission to witness the BOPE installed on the surface casing and a test of same prior to drilling out the surface casing shoe. Sincerely, ~Chairman Alaska Oi~and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,'-"~ ' STATE OF ALASKA --.- AL~ ,A OILAND GAS CONS~VATION COMIV, ON PERMIT TO DRILL 20 AAC 25.OO5 ! la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory ~{ Stratigraphic Test . Development Oil. Re-Entry __ Deepen --I Service _ Development Gas -- Single Zone _2[ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool /~RCO Alaska. Inc. RKB 167, Pad 125' GL feet Kuparuk River Unit 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage, AK 99510-0360 ADL 25609 ALK 2604 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1464' FNL & 714' FWL Sec 36, T10N, R7E, UM Kuoaruk River Unit Statewide At top of productive interval 8. Well number Number (Kuparuk) 1464' FNL & 714' FWL Sec 36, T10N, R7E, UM .KRU 36-10-7 #1 #U630610 At total depth 9. Approximate spud date Amount 1464' FNL & 714' FWL Sec 36, T10N~ R7E, UM 1-1 5-91 $200~.000 ' 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) property line 7000' MD 714' BHL feet Only well in Section feet 2560 7000' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth feet Maximum hole angle o ~laximum surface 1500 psl~l At total depth (TVD) 3640 psig 18. Casing program Setting Depth size Specification, Top Bottom Quantity of cement , Hole Casing Weight Grade Coupling Length bO 'FVD bO TVD (include stage datat 24" 16" 62.5# H-40 PE 80' 42' 42' 122' 122' :~_.200 CF 12-1/4 9-5/8" 36# K-55 BTC 2458' 42' 42' 2500' 2500' 850sx ASlll+300sx CI'G'* 8-1/2" 7" 26# J-55 BTC 6958' 42' 42' 7000' 7000' 200 sx Cl 'G' or 500' above uppermost hydrocarbon bearing zone 19. To be completed for Redrill, Re-entry, and Deepen Operations. * 150% Excess 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 Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee :X Property plat ._2[. BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time va depth plot m Refraction analysis m Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //'~~W~~e~~~ Title Area Drilling Engineer Date · , Commission Use Only Permit Number I APl number ~ I Approval date I See cover letter for C,?/..~,/' 50-/~:::~..P ' .~:~/~,~ 0 ]- / ]- ]./~1 ]_ other requirements Conditions o f approval Samples required e s __ N o Mud I~o~ required ~ Y e s __ N o Hydrogen sulfide measures__ Yes ~L. N o Directional survey required ~ Yes ~ N o Required working pressure for BOPE m 2M; ~ 3 M; __ 5 M; m 1 0 M; B 1 5 M Other: by ordar of Approved Commissioner the commission Date / Form 10-401 ~ in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 27, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Sirs: Enclosed please find the completed form 10-401, application for Permit to Drill, with attachments for the proposed KRU 36-10-7 #1, Bermuda Prospect. The main offsets used to plan the subject well are the Kuparuk 21-10-8 #1 well drilled in 1989 and the West Sak #20 well drilled in 1981. These wells were drilled through the Kuparuk River Formation and were drilled with maximum mud weights of 10.2 ppg and 10.4 ppg respectively. It is felt that with the extensive drilling information available within the KRU combined with the fact that horizons beyond the Kuparuk interval will not be penetrated, the maximum mud weight required for drilling the subject well will be +/-10.2 ppg. No overpressured zones will be encountered prior to reaching proposed total depth. Therefore, AAI is requesting a waiver of the seismic velocity analysis requirement of 20 AAC 25.033 el for overpressure prediction in exploration wells. An exception to 20AAC25.061 (a) is also requested due to the drilling information available from the above mentioned wells where shallow gas accumulations were not encountered. Also, the nearest development pad, 2K, did not have any wells that encountered shallow gas accumulations. No shallow, high resolution siesmic surveys have been run in the area and therefore there is no data indicating that a shallow hazard should be expected at the proposed location. Nonetheless, the surface hole will be drilled with a diverter system installed and diverting guidelines will be available to the rig supervisors. A confidential formation top prognosis is included for the subject well. Due to the exploratory nature of the subject well, AAI is asking that the Commission maintain the information contained in this application as confidential. Original permit plats will be submitted to replace the enclosed duplicates of telefax transmittals once they are received from the surveyors. If there are any questions concerning this application or if additional information is required, please contact Lowell Crane at 265-1544 or me at 263-4962. Area Drilling Engineer Enclosures RECEIVED DEC $ i 1999 Alaska 0il & Gas Cons. C0mmiss[0~ Anchorage Permit to Drill Supplement Maximum anticipated Surface pressure determination: With surface casing set ~ +/- 2500' tvd: assumptions: csg totally evacuated of mud with a full column of gas from the csg shoe to surface @ .11 psi/ft. Fracture gradient at surface csg shoe = 13.5 ppg EMW Maximum pressure at surface prior to casing shoe failing = [(13.5 ppg emw)(.052)-.11psi/ft](2500' tvd) = 1480 psi Maximum anticipated bottom-hole pressure determination' assumptions- No continuity in zones receiving injected fluids from the KRU Maximum eqivalent mud weight(pore pressure) = 10.0 ppg EMW M{~ximtjm anticipated BHP in KRU 36-10-7 #1 = (10.0ppg emw)(.052)(7000' tvd) = 3640 psi. NOTE: Calculating the maximum anticipated surface pressure assumming a full column of gas exerting .11 psi/ft from TD to surface on top of the maximum anticipated BHP, the resulting maximum anticipated surface pressure would only be 2870 psi as shown below. 3640 psi - (.11 psi/ft)(7000' tvd) = 2870 psi 9-5/8" Surface 7" Intermediate ..S..ummary of Casing Safety Factors ~ , Coll"aose PBY$ TJYS 2.22 1.63 7.30 9.78 1.47 1.19 2.69 3.84 RE(EiVED 9.EC 3 ~i 1990 Alaska Oil & Gas Colas. Com~is~ol~ Anchorage Formation Markers Top of Ugnu Sands Base of Permafrost Top of West Sak Sands Base of West Sak Sands K-10 Colville Sands K-5 Kuparuk River Formation TD ~ljbsea depth, ft -900 -1350 -1560 -2180 -2650 -3850 -6400 -6800 General Procedure KRU 36-10-7 #1 Bermuda Prospect 1. Build ice roads and pads, (all necessary permits for surface usage and flaring will be obtained.) Install 16" conductor. 2. Move in and rig up Pool 7. 3. Install diverter system. 4. Dri1112-1/4" hole to 9-5/8" +/- 2500',surface casing point Note' All cuttings and excess fluids will be hauled to permitted disposal sites in the KRU. 5. Log open hole, run and cement 9-5/8" casing. 6. Install and test BOPE. Test casing to 2000 psi. 7. Drill out cement and 10' of new hole. Perform leak off test. 8. Drill 8-1/2" hole to TD. 9. Run open hole evaluation logs. Plug and abandon per AOGCC regulations with necessary cement plugs. 10. If it is decided to test the well, run and cement 7" casing. Pressure test to 3500 psi. 11. ND BOPE and install temporary Xmas tree. 12. Secure well and release rig. 13. Run cased hole cement evaluation and gyro logs. 14. Move in and rig up completion rig. equipment. Rig up surface well testing 15. Install and test BOPE. 16. Circulate well to diesel and then perforate the well. REf EIVEO 17. Run down hole testing completion assembly. Gas Cons. Commiss'~o~ ! 18. Install testing tree and rig down workover rig. ~ Flow well through testing facilities. (Gas will be flared, any oil will ,,~ hauled to KRU processing facilities or reinjected into the produced zone.) 20. Shut well in for 24-48 hours for pressure buildup test. 21. Test any additional higher zones with through - tubing plug back and perforating techniques or with a workover rig assisted recompletion. 22. Plug and abandon per AOGCC regulations with necessary cement plugs. 23. Clean location. DRILLING FLUID PROGRAM KRU 36-10-7 #1, Bermuda Pros_Dect Spud to 9-5/8" Drill out casino Doint to TD -- Density 8.6-10.0 10.2 PV 15-35 1 1-16 YP 15-35 8-12 Viscosity 50-100' 35-50 Initial Gel 5-15 3-5 10 Minute Gel 15-40 5-1 2 APl Filtrate 10-1 2 5 pH 9-1 0 9.0-10.5 % Solids +/- 10 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1500 psi could be reached. ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - Maximum anticipated bottom hole pressure is 3640 psi. - Excess non-hazardous fluids developed from well operations will be hauled to an approved KRU offsite injection facility. * Spud mud should be adjusted to a funnel viscosity between 100-150 to drill gravel beds. 20" DIVERTER SCHEMATIC KRU 36-10-7 #1, Bermuda Prospect I I HCR I 5 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 20" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD (landing ring) 3. 20" FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"-2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER LRC 12-26-90 13-5/8" 6000 PSI BOP STAC,. DIAGRAM KRU 36-10-7 #1, Bermuda Prospect ACCUMULATOR CAPACITY TEST I I REYENTE ¢ I PI PE RAHS I I BLI ND RAHS DRILLING SPOOL PIPE RAHS TBG POOL 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD. 3. OPEN CASING VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 3,000 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PIPE RAMS. TEST TOP PIPE RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 3,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST TO 250 AND 3,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 3,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN PIPE RAMS. $. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 3,000 PSI. 10. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 3,000 PSI. 11. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 12. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BLIND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPMENT 5000 PSI RATED LRC 12-26-90 Well Bore Schematic KRU 36-10-7 #1 Bermuda Prospect ! I 16"@ 80' GL 12-1/4"OH x 9-5/8" annulus = .0558 bpf ~ 9-5/8" x 7" annulus= .0297 bpf 8-1/2" OH x 7" annulus = .0226 bpf 9-5/8" @ 2500' md, 2500' tvd ID=8.921", cap=.0773 bpf TOC @ +/-5200' md or 500' above uppermost HC bearing zone 8-1/2" hole to TD = .0702 bpf 7" csg @ 7000' md, 7000' tvd ID=6.276", cap=.0383 bpf cement AS III = 1.94 cu ft/sk Class 'G'= 1.16 cu ft/sk LR( 12-26-90 FLARE PiT , $CALg ~)£RM£D a LINED AR£A FOR CUTTING$ S TORA G£ KRU $$-10-7 i~tl, BERMUDA PROSPECT LOCA TED WITHIN PRO TRACTED SEC 710N ASP ZONE 4 Y-$,915, 791.61 X,,, 46:7,600.$9 LAT--70' 10' 51.495" LONG=150' 1,5' 39.194" 1464:' F.N.L., 714' F.. 14/..I.. ~p?RO~. ^c~E:'~(;~' OF pal:): 12' 3.0 SECTION A-A _ NOT TO $CAL£ SECTION NOT TO SCALE Ifil .... .. j:)escrip'l:ion~, . · .. ii .,. iii KRU $$-10-? BERMUDA PROS. ~NTER DR/LUNG PERMIT L~XHIBI BERMUDA PROSPECT \ ~ _~/~O~ Or" ~ o,- LOCA TED ~THIN PROTRACTED /kpF~OX /kc~<r~ ~ SECTION 36, TI4zP. 10 N., RGE. 7 E. ASP ZONE 4 Y=5,915, 791.61 X= 467,600.59 LA T=70' 10' 51.495' ~2' ~N~U~ 6' ~U~ 1464' F.N.L., 714' ~ ~ ~ t RECEIVED S~O~ON A-A NOT TO ~A~ J~N 0 ~ tg~t ~ ~ & ~s Oon~. ~ommisslo~ ~ohor~ -'-~x'xxxxxx,xxxx~-,~,----' KRU J6-10-7 ]1, SEG~ON B-B BERMUDA PROS. ~N~R NOT TO SC~L~ DRILUN~ PER~IT EXHIBIT ~OUNSBU~ · ASSOC. Dr. AJR ~hk: DOS J S hr 2 of 2 Rev, By Dote Description Dote: 12/27/90~wg: NSK 6.01-d90 26 ~'-25 29 27 · ~',~1 I ~ .S. 2-H~ ~ J2 JJ J4 '~'"~'~ ~ ,o ~ ~. _)~- 15 14 18 16 15 ~ ~, . :,~' GRAPHIC SC~ .~BERMUDAPROSPECT~ ~CO ~aska,Inc. ~ ~ ' ~ KRU J6-10- ~ ~I ~ ~ ~ 35 ~6 ~1 ~2 ~ K~U J6-~0-7, ~, . T ~0 N BERMUDA PROS. ~N~R T ~ N ~ DRIVING PERM/T EXHIBIT M ~ ~ , ~ ~~LOUNSBURY~& ASSOC. Rev, By Date D~cription Date: 12/27/90 ~wg: NSK 6.01-d90 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 3, 1991 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: KRU 36-10-7 #1, Bermuda Prospect Dear Sirs: The main offsets used to plan the subject well are the Kuparuk 21-10-8 #1 well drilled in 1989 and the West Sak #20 well drilled in 1981. These wells were drilled through the Kuparuk River Formation and were drilled with maximum mud weights of 10.2 ppg and 10.4 ppg respectively. Considering the offset~ data and the extensive drilling information available within the KRU combined with the fact that horizons beyond the Kuparuk interval will not be penetrated, the maximum mud weight required for drilling the subject should not exceed +/-10.2 ppg. No overpressured zones are anticipated prior to reaching proposed total depth. Additionally, there is no siesmic data available to AAI for this specific location which would allow for the interval transit time analysis to be performed as required by 20 ACC 25.033 e 1. Th~r~fcr~., ,",^! !s ~'~ ~ .~ ....... ~ ~wa~ver ~f t~.._ ~,~,~ ,,~ny._ ..... ~n~ys~s requ:rcm~nt cf ~ ~ ~ ~ 25 033 ~I ~ ~ '~',~, ov~rpr~ssu~-e pr~iCiiOn ;i', expJorat[cn .... ,,~,,~."- ~ ~ If there are any questions concerning this request or if additional information is ~ ~.~. required, please contact Lowell Crane at 265-1544 or me at 263-4962. ~~ ~. W. McBddo ~roa Drillin~ Enclosures RECEIVED JAN 0 3 ]991 ch0ra CHECK LIST FOR NEW WELL PERMITS Company ~~' Lease & Well No. ,~/_ -~Z5~09'' ,~,~. ITEM APPROVE DATE ' ' YES N__qO '/REMARKS (1) Fe~ //~. ~' 1. Is the permit fee attached .......................................... /~_ ............. (2) Loc (2 thru 8) ($ thru~3~ .... lO. (10 and 13) 12. 13. (4) Casg ~,i.~/.~". I-~-~// (14 thru 22) (5) BOPE (23 thru 28) 2. Is well t~ be located in a defined pool ............................. ~_ 3. Is well located proper distance from property line .................. ~_ 4. Is well located proper distance from other wells ............... ' .... · 5. Is sufficient undedicated acreage available in this pool ............ ~_ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. '~-~'i 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~ ..... __~ Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ .. Does the well have a unique name and number ......................... Is conductor string provided ........................................ ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ~ Is enough cement used to circulate on conductor and surface ......... /~ ...... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~<~_ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~o~o psig .. Does the choke manifold comply w/AMI RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. . (6) OTHER .'i~( ~/~/$2 (29 th~u 3i) (6) Add: -'~-~/~? / -3- =} Geology./~ Engineering: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic ~alysis data presented on shallow gas zones .......... If an offshore loc., are su~ey results of seabed conditions presented ~.~. Additional requirements ............................................. Additional Remarks: , · INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , ,, ,, , ,, ,