The URL can be used to link to this page

Home My WebLink About192-021THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M E E L E W A T E R IA L U N D ER TH IS M A R K ER C:LORILMFILM.DOC & LOCATION CLE~-~2~CE REPORT S tat e c f Alaska ~~ oz.-, · ~ c~s~v~=zo~ com~sszo~ .~ev±ew the well file, and-comment on ptuq~g, well head suauus, and !ocaticn clearance - pr=vide loc. clear, code. .:!u?s: 3~r 6~04' 5~D~ ~.6 ~lbo'~ Po~ ~oo ~ A5 1 ~o ~ ~" ~561 ~v ~ ,, ~-i~,, ~ ~, . " - I I ' ~" Well head ca= c~: Harkar pos= or pla=a: Loca:icn Cles~anca: %) " Cude 7 Signed Date · o AOGCC Individual Well Geological Materials Inventory Page: 1 Date' 02/08/94 PERMIT DATA T DATA_PLUS RUN DATE_RECVD 92-021 DRY DITCH D 100-2710, SS~838 05/05/92 92-021 GCT L 10-2604 3 06/08/92 92-021 HUD-EWR/GR L 115-1500, MWD-MD 06/04/92 9'2-021 MUD-EWR/GR L 115-1500, MWD-TVD //~' 06/04/92 92-021 407 R COMP DATE: 0.4~ ~/3~F~ ~_~ 04/20/92 92-021 DAILY WELL OP R 02/21/92-04/13/92 04/20/92 92-021 SURVEY R 0-2877 02/20/92 Are dry ditch samples required? /~~ no And received? ~no Was the well cored? yes t~/~Analysis & description received? yes~ Are well tests required? yes ~eceived? yes~ Well is in compliance ~ Initial ~ Comments ~.. ~~ ~., 2- ~ ..-~l 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 September 14, 1992 ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Attn.: John Winegarner Senior Landman Re: Location Clearance, ARCO's well Cirque #1, Cirque #Ix, Cirque #2, Tarn #1 West Sak #1 West Sak #15 PTD-92-0009 PTD 92-0021 PTD 92-0029 PTD 91-0151 PTD 71-0003 PTD 79-0099 Dear Mr. Winegarner: Our representative visited the above locations on September 23, 1992 and found that the marker posts contained the correct data and were in place, locations were clear of materials and debris, and pits had been filled and graded, and that the locations appeared to be in stable condition. Location clearance is hereby approved for the above listed ARCO wells. Sincerely, · Chairman ~;) printed on recycled paper b y C, r'j. TO: THRU: FROM: MEMORANoUM State of Alaska ALASYJk OIL AND GAS CONSERVATION COMMISSION Dave Johnsto~ Connmis s ione r DATE: FILE NO: Sept ~, .~ 1992 lS9392-8.doc Blair E Wondzell P. I, Supervisor, ,~l~u Grimaldi Petr Inspector TELEPHONE NO: SUBJECT: Location Inspection Arco Cirque~tlX Sec 20,TgN,RTE,Iffl Explorstory PTD 92-21 Sunda-~ 8-23-92 I flew to Arco's remote exploratory locatic,~t Ci_rque~lX to perform a location inspection on Cirqu.e~lX (relief well.') .for surface abandcmment, I found the location to be very clean with no evidence of trash ov drilling debris~ The marker was of proper size and construction with the following information bead welded on it:ARCO ALASKA INC. Cirque$}lX ADL375076 15FNL, 'l. 855FEL SEC20: T9N, R7E, t~l One area that needs to be addressed is the path of the now thawed ice road between Tarnq~l and this location. It appears that the edge markers were left behind a~d I feet that before full cleacance c:an be grm-,ted. these markers should be removed~ IN Sb%IMMIY: Cirque~lx has been cleaned up and I could fi,id no ovider, c:e of contamination oz trash left from thez~-'=.~o The markers left behind from the ice road still need to be removed before clearance can be granted, Doug Amos reports the markers have been revoved, therefore location clearance can ge granted. 02-00lA (Rev. 6/89) 20/11hMEMOl. PM3 ALAS~-'~IL AND GAS CONSERVATION CO~MISF--~N ., · SURFACE ABANDONMENT REPORT 20 AAC 25, ARTICLE 2 · FILE INFORMATION: ... . Operator_ ~-~ Date Downhoie P & A ~'~-~ Address /~O ~o~ /(~ ~O ~$/~ ~/C~ ._ Surface Location df ~ell ' Pe~it No. Ft. F L, Ft. F~, ~I No. Sec.~, T ' , R , M. Unit or Lease Name_ Well No. _~'~~ 20 ~C 2~.120: ~L ~DO~NT ~R~R: .... ~ ~ .. '.. Dia. Steel Post (4"Min,) ~ ~ , Length (10' Min.) .... Height Above Final Grade Level (4~ Min.) 7 z ....: Top of ~rker Pipe Closed ~th: C~efit Plug Screw Cap Welds ~ "."~;:" '.. , ~ .. .- . Set: On Well Head , On Cutoff Casing ~ ,'~n Concrete Plug · ..'.:.' ~ Distance Below Final Grade Level ~ Ft. in. "'::..' '" Side Outlets: ~1 Valves and Nipples R~o~d ' ~ '",'"."'~. All Openings Closed :- .... , With Blinds , With Cement ~, Other INFORMATION BEADWELD..ED.DIR. ECT,~_LY TO MARKER POST: (List Where Different from File Information) Operator ,,a co nit or Lease Nme Well Number C/~(~o~ /.,-~ , Surface Location of Well: Ft. F _L, F L, Sec , T f X/,., a 20 AAC 25.170: 'LOCATION CLEAN-UP F---~lled In , Liners Removed or Buried SURFACE OF PAD AND/OR LOCATION: Rough Other · Debris Removed ..':.'~.. , , · . . . Smooth... , Contoured , Flat , Compacted. · , CLEAN UP OF PAD AND/OR LOCATION: Clean ~..~ , Pipe Scrap_ , Iron Scrap Paper , Other , Wood , Mud , Cement SURROUNDING AREA: Wooded , Brush . , Tundra ~ , Grass Sand , ~_· Other CONDITION SURROUNDING AREA: Clean ~ , Trash from Site Other .... , Dirt · . .. , Trees and/or Brush from Clearing Site , Gravel , . .'. .. ACCESS ROAD: Dirt ~, Gravel ~, Ice.S_ , Other CONDITION ACCESS ROAD AND SURROUNDING:' Clean , Rough , Smooth , Trash from Operations , .... ~':::.'. . Trees ~n~_/°r Brush-~om Clearing R---~ad , Spoil from Clea. rin---~ Road ', '. -...:,. u,.-. ...: .. REMAINING TO BE DONE: P/C"/,'(.-/,~ ~:::>.../~/Z~/'~_~'". I~---_~x .... "" · . RECOMMEND APPROVAL OF ABA~NDONMENT: Yes ~' , N6. 05/26/81 / .... ... TO: DATE: ARCO Alaska Inc. Atl anticRich fieldC omp an y State of Alaska Attn: Larry Grant 3001 Porqupine Anchorage, Alaska 99501 (907) 279-1433 FROM: C. M. Posey ANO 920A ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 June 8, 1992 Transmitted herewith is the following: Final Cirque #1 LIS tape containing all MWD data Final Cirque #1X GCT Survey, sepia Final Cirque #2 Cement Bond Log, sepia - Final Cirque #2 Selective Formation Tester, sepia .~'r2- Final Cirque #1X GCT Survey, paper ..---1-- Final Cirque #2 Cement Bond Log, paper ~ - Final Cirque #2 Selective Formation Tester, pape Approved for transmittal by: / ~ /'~ T. L. Hudson Manager ~.q / Kuparuk Development and W. Extension Geoscience Receipt: ~/~~ ..~.~"~' Dale: ~,,/~~'~ /../ // v Return rece'~. / ARCO Alaska, Inc. Attn: Mr. Clifton M. Posey - ANO 920A 700 G. Street Anchorage, AK 99510-0360 (907) 265-6240 wk. (907) 265-1398 fax CMP ARCO Alaska Inc. AtlanticRichfieldCompany TO' Mr. Bob Crandel State of Alaska Anchorage AK DATE: June 2, 1992 FROM: J.E. Sallee ANO 954 CONFIDENTIAL MATERIALS wing: 'l~paper ARCO Cirque #1X ~ ~....- ~-- ~' ,~/IWD EWR-GR mudlog (measured Depth) ..-AVIWD EWR-GR mudlog (TVD) 1~-sesepia, p~paper ,.-1-sepia, 1,~paper RECEIVED Approved for transmittal by: ~" .Co~cur: ,/ Receipt: - f¢..,'u' / Return re~p~toi ¢ ARCO Alaska, Inc. / ATTN: J. E. Sallee ANO 954 P.O. Box 100360 700 "G" Street Date: Prepared by: J. Zimmerman Anchorage, AK 99510-0360 ARCO Alaska. Inc. Post Office Box 10LI360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 SAMPLE TRANSMITTAL TO: Alaska Oil & Gas Conservation Com. 3001 Porcupine Drive Anchorage, Alaska 99501 OPERATOR: ARCO DATE:4-23-92 AIRBILL #:ALT-511989 AFT#:0-2-4-23 -48 CHARGE CQDE#19712 NAME:~~iCIRC RELIEF WELL SAMPLE TYPE: Dries NUMBER OF BOXES: SAMPLES SENT: ClRC RELIEF WELL SAMPLES ARE AS FOLLOWS: 100'-1700' (50' SAMPLES) 1700'-2710' (30' SAMPLES) RICK LEVINSON IS THE ARCO GEOLOGIST 265-1652 SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company / I .2 o ~ -- R' ° 5-6 STATE OF ALASKA "~, ~'-¢ ~ ~ ~ AL..,,KA OIL AND GAS CONSERVATION CC AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG - 1 Slatus of Well Classiticalion of Service Well OIL r--] GAS r'-'] SUSPENDED I'-"] ABANDONED [] ' SERVICE [] Name o! Operator 7 IPermit Number 2 ARCO Alaska, Inc I 92-21 & 92-O62(10-403 SA) 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-029-20166 4 Location of well at surface 9 Unit or Lease Name 15' FNL, 1855' FEL, SEC 20, TDN, R7E, UM ................. ~ NA NA At Total Depth 1031' FNL, 1867' FEL, SEC 20, TDN, R7E, 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. · ........ 7 WILDCAT RKB 171' ABOVE SEA LEVELI ADL-375076 12 Date Spudded02/22/92. 13 Date T.D. Reached03/01/92. 14 Date Comp. , Susp. or Aband.04/13/92. 115 water Depth' ii OffshOreN A feet MSL 116 No' °f c°mpletionsN A 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Deplh where SSSV set 21 Thickness of permafrost 2709' MD ,2399' TVD SURFACE( BP @ 160' GL) YES ~ NO O NONE feet MD 22 Type Electric or Other Logs Run GCT 23 CASING, UNER AND CEMENTING RECORD I SETI'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' SURF 118' 30" AS I 13-3/8" 72# L-80 SURF 525' 17-1/2" 1000 SX AS I 9-5/8" 47# L-80 SURF 1769' 12-1/4" 500 SX ASIII, 200 SX CLASS G 7" 29# L-80 SURF 2692' 8" 1042 SX ASlII, 250 SX CLASS G, DOWNSQUEEZE 600 SX AS III 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED I · See attached operations summary 27 ~RODUClION IESI Date Fimt Production I~tho~ of Operation (Flowing, ges lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (con') Press. 24-HOUR RATE Brief description of lithology, porosily, fractures, apparent dips and presance of oil, gas or water. Submit core chips. A,,Ia~ka OJt & Gas Cons. Commissio~ Anchora,ge Form 10-407 Submit in duplicate Rev. 7-1-80 (:X3N~NUED ON REVERSE SDE NAME Include interval tested, pressure data, all fluids recoverd and gravity, IVE. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF A'I-rACHMENTS P & A SCHEMATIC, GCT, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ___~___~____~__~___ Title AREA D~ENGI'~iEER 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 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 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 2/21/92 2/22/92 2/23/92 2/24/92 2/25/92 2/26/92 2/27/92 2/28/92 2/29/92 3/1/92 3/2/92 CIRQUE # 1X REPORT OF OPERATIONS Move Doyon 9 from Prudhoe Bay DS 15 to Cirque # IX. Accept rig at Cirque #1X@ 0400 hrs, 2/21/92. NU diverter. Test diverter. Spud at 2000 hrs, 2/22/92. Drill 12-1/4" hole from 105' to 168'. POOH and change BHA with 2° AKO sub. Directional drill from 168' to 391' Change to 2.4° AKO sub. Drill from 391' to 506'. Drill from 506' to 544'. POOH, RIH with 17-1/2" hole opener and bullnose. Open hole to 17~1/2" from 105' to 532'. Run 13-3/8" casing to 525'. Pumped 40 bbl fresh water spacer, 1000 sx Arctic Set I cement at 15.7 ppg. Displaced with mud, bumped plug to 2000 psi, good returns with 18 bbls cement returns at surface. RU Schlumberger, ran GCT gyro, 1' correction made to Sperry MWD surveys. ND diverter, install csg head, NU BOPE. Test BOPE aswitnessed by Mr. Harold Hawkins. RU Dowell pump equipment to BOP stack for lost returns possiblities. RIH with 12-1/4' bit, test casing to 2000 psi, drill out cement from 435' to 508'. Test casing to 2000 psi. Drill cmt from 508' to shoe at 525', cleaned out rathole to 544' and drill new hole from 544' to 549'. POOH and change to steerable mud motor. Drill from 549' to 716' with 2° AKO sub. POOH and change to 1.5° AKO sub. RIH and ream from 584' to 638' to reduce dogleg severity. Bit not following old hole, slid in new hole from 638' to 716'. Drill from 716' to 985'. Drill from 985' to 1780'. Short trip, drop Sperry ESS survey, POOH. Ran 9-5/8" casing to 1769'. Pumped 40 bbl fresh water spacer, 500 sx Arctic Set III cement at 12.1 ppg followed by 200 sx Class G with .2% D-46, 2% S-! at 15.8 ppg. Displaced with mud, bumped plug to 2500 psi, good returns with 60 bbls cement returns at surface. Ran Schlumberger GCT gyro. ND BOPE, installed tbg head, NU BOPE, test same as witnessed by Mr. Harold Hawkins. RiH with 8- 1/2" bit. Tested casing to 3000 psi. Drill float collar at 1682', hard cement to 1759'. Test casing to 3000 psi. Drill float shoe at 1769', clean out rathole to 1780'. POOH. RIH with steerable mud motor, drill from 1780' to 2100'. Drill from 2100' to 2436', POOH to reprogram MWD directional survey tool. RIH and drill from 2436' to 2709' TD. No indication of communication with Cirque # 1 wellbore. Short trip, POOH to run casing. Ran 7" casing to 2692'. Pumped l0 bbl water spacer, 1042 sx (360 bbl) Arctic Set III lead cement at 12.1 ppg followed by 250 sx (52 bbl) Class G tail cement with 2% S- 1 and .25 pps D-29. Lost circulation after 263 bbl of lead cement pumped. Bumped plug to 2000 psi. Down squeeze 600 sx (207 bbl) Arctic Set III 12.1 ppg cement in 9- 5/8" x 7" annulus. No returns observed in Cirque # 1 wellbore. ND BOPE, set slips. P. AlaoKa Oil &~,a~ Cons. ~ommis~on Anchorage 3/3/92 3/4/92 3/5/92 3/6/92 3/7/92 CIRQUE # 1It ;PORT OF OPERATIONS Page 2 NU tubing spool, NU BOPE and test same. RU HIS wireline unit, RIH with temperature tool, set down at 2405'. POOH with wireline. RIH with bit, clean out to float collar at 2644'. Test casing to 3000 psi, displace well with 10.6 ppg CaCl brine. POOH, run HIS temp log from surface to PBTD. Run PET/CBL log from PBTD to surface. Run Schlumberger GCT gyro. Run Schlumberger noise log, no effects from Cirque # 1 were observed. NU tree, test tree and valves to 3000 psi. Released Doyon 9 at 1200 hrs 3/5/92. Wait for move to Cirque # 1. Wait on Cirque # 1 pad clean-up. Move to Cirque # 1. 4/13/92 RU HRS wireline unit, set EZSV bridge plug at 160' below ground level. RIH with l" pipe to 160', RU Dowell and pump 100 sx Arctic Set I cement at 15.8 ppg to fill 7" casing. Cut off 20', 13-3/8", 9-5/8" and 7" casing strings 4' below tundra level. Weld cap and dry hole marker on top of casing stubs. Area Drilling Superintendent (Cap Ci lue #1X Relief Well CURRENT P&A will be 3' below tundra level)~t~ All depths RKB unless noted othenNise Pad level= 133.6' above sea level Doyon 9 RKB = 37.5' RKB = 171.1' above sea level 20" Conductor @ 80' Below Ground Level 7" Bridge plug at 160' Below Ground Level 13-3/8" 72#, L-80, BTC @ 525'MD/519'TVD Cemented w/ 1000 sx ASI to surface 10.6 ppg CaCI brine from PBTD to bridge plug. Calc. Top of Class G tail at 1110' MD/987' TVD Cement Legend Arctic Set I Arctic Set III ~ Class G '..':::.::',.'.::::;:'..::: 9-5/8" 47 ~, L-80, BTC ~ 1769' MD/1498' TVD Cemented w/ 500 sx ASIII and 200 sx G to surf. PBTD= 2644' MD/2334' TVD 7" 29#, L-80, BTC @ 2692' MD/2382' TVD Cemented w/ 1042 sx AS III and 250 sx G Downsqz. 9-5/8"x7" with 600 sx ASIII @ surf. TD @ 2709' MD/2399' TVD PERMIT ~ ,~-,~- - --~// WELL NAME . · · .........-~-...,. "'""- ~.,~UMI~LE I IUI~I URI r' ~,UIII I' ^OGCC GEOLOGICAL MATERIALS INVENTORY LIST ( check off or liszt date. as it is received ) .o? I ~>/_L~/¢.,_ dr, illing history ~ survey I I well tests ! core desription cored intervals ' core analysis .. . dry ditch intervals digital data LOG TYPE RUN INTERVALS SCALE NO. ,, ., , , ,, ,, -.~1 , ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 23, 1992 Commissioner David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Sundry Notification of P&A ARCO Cirque #1X (Relief Well) Dear Mr. Johnston, Attached is ARCO Alaska, Inc.'s proposal for plugging and abandoning Cirque #1X as per 20 AAC 25.105(i) and 20 AAC 25.120. If you have questions or require any additional information, please contact me at 265-6575 in our Anchorage office. Sincerely, Tim Billingsfey~..Y Senior Drilling Engineer Alaska Oil & Gas Cons. Commissior~ Anchorage ~OIL AND GAS CONSERVATION COMMIS''~4)N 0 ~ [C ~ '~'-~ ;~t~ [ APPLIC ~ION FOR SUNDRY APF 3VALS 1. Type of Request: Abandon X Suspend -- Alter casing _ Repair well Change approved program _ Operation Shutdown Re-enter suspended well Plugging X 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 15' FNL, 1855' FEL, Sec. 20, T9N, R7E, UM At top of productive interval N/A At effective depth N/A At total depth 1031'FNLr 1867' FEL~ Sec. 20~ T9N~ R7Er UM 12. Present well condition summary Total Depth: measured 6709' true vertical 6709' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 171' ABOVE SEA LEVEL 7. Unit or Property name N/A 8. Well number Ciraue #1X 9. Permit number 92-21 10. APl number 5o-103-20166 11. Field/Pool Wildcat Effective depth: measured 5144' true vertical 5144' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 20" 487' 13-3/8" 1731' 9-5/8" 2654' 7" N/A measured true vertical Tubing (size, grade, and measured depth N/A Packers and SSSV (type and measured depth) N/A Cemented Measured depth True vertical depth Arctic Set I grouting 1 1 8' 1 1 8' 1000 sx Arctic Set I 525' 519' 500 sx AS111, 200 sx G 1769' 1498' 1042 sx AS III, 2692' 2382' 250 sx G, Downsqz 600 sx ASIII RECEIVED MAR 2 4 1992 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal X P&A Exploratory well. (Wellbore schematic attached) 14. Estimated date for commencing operation March 25.1992 16. If proposal was verbally approved Name of approver 17. I hereby,certify that the foregoing Signed Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission Detailed operation program BOP sketch I 15. Status of well classification as: Oil __ Gas _ Suspended _ Date approved Exploratory __ Service X is true and correct ~:_ of~,.~/,///~,,~my knowl~ge~ ~ Title ' /~ ~ ~ Date F~ ~MI~N USE ~LY/ I~proval No. ORIGINAL SIGNED BY Commissioner Date Form 10-403 Rev 06/15/88 LONNIF C, SF.,"IITH SUBMIT IN TRIPLICATE P&A Discussion Cirque #1X No geo-pressured zones were encountered while drilling the well. All significant hydrocarbon zones are covered with cement by the primary cement jobs on three strings of casing which were set in the well. Current Status 3/4/92 Cirque 81X was drilled as a relief well for Cirque 81 which experienced a shallow gas blowout on ¥~/12/92. The Cirque 81X had 13-3/8" surface casing set at 525' MD or 519' TVD with cement circulated to surface. A 9-5/8" intermediate casing string was set at 1769' MD or 1498' TVD with cement successfully circulated to surface. The well was drilled to a TD of 2709' MD or 2399' TVD with 7" casing run from surface to 2692' MD. The 7" casing was cemented but returns were lost before cement was circulated to surface. However, 162 bbls of cement had been pumped around the shoe before returns were lost which more than covered the open hole interval from 2692' MD to the 9-5/8" intermediate shoe at 1769' MD. A 600 sx (207 bbl) Arctic Sett III cement downsqueeze was also performed after the primary cement job to fill up the 7" x 9-5/8" annulus to surface with cement. The Cirque 81X was not required as a relief well because the Cirque 81 was successfully killed on 2/29/92 by pumping mud down the drill pipe still remaining in Cirque 81. Cirque 81X has remained unperforated. Doyon Rig ~ moved off Cirque 81X on 3/7/92 and successfully plugged Cirque 81. Prm3osed P&A Procedure NOTE: Notify AOGCC so their representative can witness surface plug. 1 ) Rig up Halliburton Logging Services E-Ii'ne unit. Set bridge plug in 7" 298 casing at 160' from surface. Rig up Dowell cementing unit. Run 1" line down 7" casing to bridge plug at 160'. Circulate Arctic ,Set I cement from bridge plug to surface. (160' of 7" = 37 sx of 0.93 yield AS I cement) Dig out, chip out cellar to appx. 4' below tundra level. (Casing needs to be cut at least 3' below tundra level so thickness of ice pad needs to be taken into consideration) Cut 20" conductor, 13-3/8", 9-5/8" and 7" casing strings at 3' below tundra level. Remove casing stubs, wellhead, etc. and send in for reconditioning. Weld cap across top of 20" conductor. Weld P&A marker post to cap. Top of post is to be from 4' to 6' above original ground level. The following information should be bead welded onto marker post: ARCO Alaska, In{=. ADL-375076 Cirque 81X 15' FNL, 1855' FEL, Sec. 20, T9N, R7E, Umiat NOTE: Notify AOGCC so their representative can inspect marker post. 2) 3) 4) 5) 6) T. A. Billingsley 3/23/92 RECEIVED MAR ~ 4 1992 Alaska Oil & Gas Cons. Commisslon Anchorar~e (Cap Cir " e #1 X Relief Well Proposed P&A will be 3' below tundra level)~ All depths RKB unless noted otherwise Pad level= 133.6' above sea level Doyon 9 RKB = 37.5' RKB = 171.1' above sea level 20" Conductor @ 80' Below Ground Level 7" Bridge plug at 160' Below Ground Level 13-3/8" 72#, L-80, BTC @ 525'MD/519'TVD Cemented w/ 1000 sx ASI to surface 10.6 ppg CaCI brine from PBTD to bridge plug. Calc. Top of Class G tail at 1110' MD/987' TVD RECEIVED MAR ~ 4 t99~ Alaska Oil & Gas Cons. Oommissio~ Anchorage 9-5/8" 47 #, L-80, BTC @ 1769' MD/1498' TVD Cemented w/ 500 sx ASIII and 200 sx G to surf. Cement Legend Arctic Set I Arctic Set III Class G PBTD= 2644' MD/2334' TVD 7" 29#, L-80, BTC @ 2692' MD/2382' TVD Cemented w/ 1042 sx AS III and 250 sx G Downsqz. 9-5/8"x7" with 600 sx ASIII @ surf. TD @ 2709' MD/2399' TVD ! r, ('~0 O0 h<'~',~)O0 ~ 00 00 "~()0 O0 ' '()() ()0 '1 )0 O0 19()0 O0 1 ,$~)O O0 I 1()o O0 400 O0 ',OO O0 ~00 O0 ~, ,~ ) ('? co I (;(). () 0 ()()0 O0 9()0 (')0 i()(; O0 a,,() O0 h~!(i O0 ,'~ ()0 O0 ~()o O0 ?oo oo lO0 00 10 O0 F ) DEPTH cp 32.6 NORTH -1011,94 -1011.73 - ] 006.48 -1004.00 -997.05 -977.60 -948.75 -915.47 -872 47 -824 75 -775 30 -721 24 -659 85 -595 25 -527 88 -'~58 68 -390.26 -321.49 -254.68 -190.56 -130.76 -82.52 -45.49 -20.34 -6.56 -.63 .07 0.0 (F ) NORTH CP 32.6 FILE 5 · 04-MAR- 1992 22.'47 INPUT FILE(S) 2 · 2"/MIN EAST TVD (F ) (F ) -5.11 2294.83 -4.77 2289.95 -.37 2190.20 1.39 2090.27 2.49 1990.64 2.66 1892.61 4.18 1796.90 7.88 1702.68 11.27 1612.58 11.24 1524.70 11.50 1437.79 11.28 1353.70 10.65 1274.80 9.36 1198.48 7.81 1124.62 6.22 1052.44 5.39 979.53 4.65 906.94 3.23 832.56 1.39 755.85 .58 675.82 1.56 588.29 1.95 495.49 .41 398.79 -.93 299.80 -.45 199.99 -.11 100.00 0.0 10.00 (F ) (F ) EAST TVD .2"/MIN FILE CREATION DATE 04-MAR-1992 20:22 VERTICAL SECTION (F ) 1011.95 1011.74 1006.47 1003.98 997.03 977.58 948.72 915.41 872.40 824.68 775.23 72t. 17 659.78 595.19 527.83 458.64 390.22 321,46 254.66 190.55 130.75 82.52 45.48 20.33 6.57 .64 -.07 0.0 (F ) VERTICAL SECTION 04-MAR-1992 22:47 INPUT FILE(S) CREATION DATE 2 04-MAR-1992 20:22 DOG-LEG AZIMUTH DEVIATION (D/HF) .76 1.61 .63 1.84 5.73 6.20 3.91 8.27 2.99 .79 2.38 8.02 2.03 .86 1.45 .87 1.13 2.05 2.40 2.21 8.80 6.83 6.56 6.82 4.46 3.51 0.0 0.0 (D/HE) DOG -LEG (DEG) 239.15 238.11 206.10 251.49 184.47 181.50 184.90 187.19 181.02 179.71 179.99 179.77 179.00 178 72 178 73 t78 78 179 61 179 07 178 68 178 29 180 61 181.39 178 94 173 70 178 91 194 03 348 19 224 22 (DEG) AZIMUTH (DEG) 4.69 4.67 3.59 .40 8.40 14.66 18.55 21.11 28.42 28.51 30.97 35.42 39.24 40.93 43.85 43.80 42.83 43.67 40.38 4O.O5 32.41 25.65 18.08 11.07 5.36 1.75 .10 .19 (DEG) DEVIATION RECEIVED M AR 4 199 Alaska 0il & Gas Cons. bummi', . MEMORANDUM Stale of Alaska ALASKA OiL AND GAS CONSERVATION COMMISSION TO: Lonnie C Sm~..gh~ DATE: March 3, 1992 Commissione~ FILE NO: HH33. DOC THRU: Blair Wondzell Sr Petr Eng FROH: Harold R HaWkins Petr Inspector TELEPHONE NO: SUBJECT:Blowout AAI Cirque #1 & #1X SEC 20, T9N, R7E, UM Permit No. 92-21 Wildcat Monday, Februarv~, 19.92 I left my house at 5:45AM for check-in at Alaska Air at 6:00AM. I left Anchorage at 6:55AM by Alaska Air, arriving in Prudhoe at 8:30AM and arriving at Cirque #1 command post at 12:30PM. I talked to on-site incident commander Kirk White, planning section chief Mike Winfree, Jack Warr, alt. G.W. Craig and logistics section chief Eddie Vaughn. The well "Cirque ~1" was blowing about 6 million cubic feet per day according to their estimates at Doyon 14. At Doyon 9,Cirque ~X, relief well,13 3/8 CSG had been run, cemented and tested before I arrived on location. I called and informed Lonnie Smith of problems and progress to kill Cirque #1 blowout. Tuesday,..Februarv 25,~ 1992 From 2:30AM to 4:30AM, I witnessed the BOP test. From ll:30AM to 12:00PM, I witnessed upper and lower kelly tested. Today the spool for the diverter washed out on Cirque #1 blowout. Twenty to thirty million cubic feet of gas was blowing out with quite a bit of dark brown sand. I talked these figures over with the command center officials. I talked about the diverter lines also, schedule 80 pipe was used. I called the Commission in the morning and afternoon. wednesday, February.26, 199~ I witnessed another pressure test to 2000 psi for 30 minutes of the 13 3/8" casing-down to 425'. Test was from 9:50AM to IO:20AM and was satisfactory. Drilling through 13 3/8 shoe was performed at 3:00PH. Well still blowing hard at Doyon 14, Cirque #1 blowout. I called the Commission both morning and night on progress and problems. Thursday, February 27, .1992 Not blowing sand as much but still blowing at 6:00AM 50 or 60 million according to command center's estimate. The 9 5/8 relief hole was completed at 12:30PM; 1780' MD; 1437 TVD. I attended a meeting from 7:00PM to 8:00PM on plans AAI was going to use in well killing proceedures, ect. I called the Commission twice. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 Friday, February 28, 1.9.9.2 I went to the command center for Cirque #1 blowout at 6:00AM. The 9 5/8 was run and cemented to surface with good returns at 4:00AM. I called Lonnie Smith and informed him at 10:30AM on progress. At 2:30PM to 3:00PM I witnessed the BOP test on Doyon 9 particularly on the extra spool that was added and pipe rams that were changed; the annular, 3 HCR valves, stack body and choke body, all tested okay. AAI is going to drill out 8.5" hole tomorrow. Saturday, February 29, .1992 AAI Cirque #1 blowout is girgling,but'.~ no sand and very little gas. Plans have changed overnight. New pipe was run and hooked up with T I W valve to heavy wall pipe that was in hole at 775'. Kill MW was l!.4#/gal., 1000 bbls BBLS followed by MW 10.5#/gal. and MW 10.0#/gal.. Total 3225 bbls. + about 45 bbls CA/CL2. This was started and pumped on February 1992, from 11:20AM to 2:30PM. Well is dead. I witnessed 9 5/8 casing in hole for 30 minutes with no leak off at 3000 psi, 1786' MD and 1388 TVD. AAI Cirque #1X drilling started on the 8.5 hole at approximately 8:00PM. Sunday, March 1, 1992 The 8.5 relief hole is drilled to within 1 or 2 feet of target of 2100 feet at AAI Cirque hole #1 blowout. Now coming out of hole to change direction tools and go back to bottom to find wellbore of Cirque #1. I went over to Doyon 14 with Gary Martin, AAI Co. man, and took some pictures of Cirque #1 blowout and equipment. After trying for another 8 hours, the directional driller did not find Cirque #1 annulus. Monday, March 2, 1992 I went to Cirque command center and talked to Kirk White, incident commander. They are coming out of the hole at Cirque #1X and will run 7" casing, then cement, and try to drill out as close as they can to Cirque #1 and pump cement down Cirque #1X, thru the formation and into #1 at the bottom to plug it (Cirque #1). I left Cirque location at 6;00AM. In summary, AAI and Cirque operation groups were environmentally and safety conscious. I went over their plans with them and was very pleased. Attachments ICS 201 Current Organization, , , On-Site Incident Commander Kirk White Planning Section Chief Mike Winfree Operations Section Chief Jack Warr alt. G. W, Craig ,, L~gistics Section Chief Eddie Vaughn I Div./Group Dovon Ria #9 B. Campbell G. Cooper G. Martin I Div,/Group Safety Boss Mke Miller Jarvis Jackson Ken Rose Div,/Group Dowell KRU Su 3port Bruce Metcalfe Tim Vincent Daily Meeting 2/29/92 1.) Meeting w/Arco and Safety Boss 2.) Safety meeting on site. 3. ) Test lines. 4. ) Get pump rates with CA/CL2 water 5.) Do top kill on Cirque A.)Begin Pumping w/11.4# Mud (1000 BBC) followed by 10.5# Mud (1700 BBL) 10.0# Mud (3325 BBL) Total = 6035 BBL B.)Once .kill is made or hole filled to surface, Pump CA/CL2 water @ 10.7# to freeze protect if sucessful (45 BBLS) · C.)Monitor hole and keep full (Recording all fluid volumes''~ pumped thru-out operations) 24 HR Monitor ***Press Limitations based on hydralic lift of drill stg. '5" O.D.D.P. and 3500# P.S.I. =68,700 lbs. Appox stg. wt~. ..... =61,600# · (Drill stg. is chained down to rotary.) ***Friction Press as per D/S = 29BPM @+/- 3500 p.s.i. ORGANIZATION ASSI'GNMENT LIST ~. INCIOENTNAME ' 2. DATE 3. TIME PREPARED PREPARED Cirque Well Blowout ICS 203 2/26/92 0700 ......... E~ "' E) .... 4 (DP IONAL PERIOD (DATE/TIM POSITION NAME 5 INCIDENT COMMANDER AND STAFF 2,'26/92 to 2/26/92 from 0700 to 1900 INCIDENT COMMANDER DouG Rukel DEPUTY Doug St~ltz~Kirk W'~ite ' 9, OPERATIONS SECTION ,, , SAFETY OFFICER R, Kratsas .... CHIEF ~ Jack Warr/G. W. Craig INFORMATION OFFICER ' ' ' DEPUTY I LIAISON OFFICER ~J, ives LEGAL OFFICER D. Rodg~rs~S', Parks ' , 6. AGENCY REPRESENTATIVES a. BRANCH I · DIVISIONS / GROUPS AGENCY' NAME ' ' ~ BRANCH DIREC,,TOR AC)GCC ' Ha~old HaWkins .......... DEPUTYI .......... 0~WSION/GROUP Safety BoSs DIVISION / GROUP Dowel - DIVISION / GROUP Doyon _ DIVISION / GROUP Milpark 7: 'PLANNING SECTION ''" " 0~VlSlON/GROUP .... CHIEF - :Mike Winfree ............. , DEPUTY b BRANCH II - DIVISION8 / GROUPS RESOURCES UNIT Bru(~e Metcalfe/Tim 'VinCent "' BRANCH DIRECTORiGr"B: Campt~ll/G:' Cooper ' srl'UAT~ON UNIT Bruce Metc~lfe/Tir~"Vincent DEPu'rY Martin . .. DOCUMENTATION UNIT BrUce Metcalfe/Tim Vincent' ' DEMOBILIZATION UNIT BruCe Metcalfe/']'im Vincen{ '~' . DiV~S~ON / GROUP Cirque' i'X A(~tivities ~" TECHNICAL SPECIALISTS 'Environ.: "A. 'Schuyl~'r/L. Krizan " DIV~SION/GROUP ...... Doyon Rig ~ .... I Fi~e @nga~'e' - D. Dev0r~/R', QUes~da O~VlS~ON / GROUP Dowel Ci~;~n.u~" ' Al'aska Clean Seas ....... ' ' DWlS~ON / GROUP Milp~rk' Mud ....... 8. LOGISTICS SECTION DIVISION/GROUP CHIEFr'Eddy Vaughn " , DEPUTY C BRANCH III . DIVISIONS I GROUPB , , a.. SUPPORT BR'~N'~H ......... BRANCH DIREC'rOR I Finance'Engineering: R. MOrgan DIRECTOR 'Bruce ~etc~'lfe/Tim Vincent - ' DEPUTYI ' ' ' SUPPLY UNIT "Bruc~ Metcatfe/Tim Vincent , , FACILITIES UNIT Bruce Metcalfe/Tim Vince'nt-" DIVISION / GROUP Relief Well GROUND SUPpORT UNIT '" . D~WS~ON / GROUP Critical Well Team .... b, SERVIC'E i~IRANCH ' ' DIVISION/GROUP Business Support DIRECTOR I DIVISION / GROUP ' ' ' DIVISION / GROUP COMMUNICATIONS UNiT ~, Lybyrd?R, Allen ....... MEDICAL UNIT '~. Chapl~ell ' 10. FINANCE SECTION FOOD. UNIT CHIEF c. AII¥-O~ERATIONS ' BFiANCH DEPUTY AIR OPERATIONS BR DIR TIME UNIT AIR SUPPORT SPVR. PROCUREMENT UNIT HELICOPTER COORD. COM r~ENSATION/CLAIMS AIR TANKER COOR0 COST UNIT II II i! I I ii I I i I C S i g' Prepare0 by ii~E~O~JRCES UNIT) 203 ! ~ I I II I I II II I I 2/26192 Prepared by: , Date' , '~.- IMT 203 Cirque. Well #1 Intercept/P & n Plan 3/1/92 Note' This well plan is contingent on the intersection of'Cirque Well #1 with Cirque #IX relief well. !) Directionally drill Cirque IX relief well to intercept Cirque gl at 2,100' TVD. "~ 2) Note intercept depth. Continue to drill and cleanout to Cirque gl TD at 2,415' TVD. , From intercept point to TD of Cirque glX monitor Cirque gl fluid height for signs of communication between well bores. · · At TD, make wiper trip to 9-5/8" casing shoe. RIH to TD and drop single shot survey. POH. · 4) Stand back B HA and RIH with open ended 5" drill pipe to TD. Circulate. DP volume of mud. 5) Spot a 410 bbl balanced cement plug using 2000 sks Class G with 2% S- I (CaC12), .2% D-46 (anti-foam), and 1/4 lb/sk D-29 (LCM) premium cement. Use drill pipe wiper dart. Yield = 1.17 ft3/s Density = 15.8 ppg 4 hrs 10 min pump time @ B HCT = 70°F and B HST = 50°F Compressive strengths: 230 psi @ 12 hrs 800 psi @ 24 hrs Be prepared to spot additional 2000 sk.balanced plugs with Class G cement. 6) POH above ~'afety top of cement and reverse circulate drill pipe clean of cement. POH. 7) WOC 12hrs. RIH With open ended 5" drill pipe. Tag TOC. Depth of TOC will determine next cement plug size and cement type. If ceme.-.t top is deep, assume big hole and communication up Cirque gl. 'if cement top is nigh, assume cement is staying in Cirque #1X's well bore. Proceed with Step 9. 8) Continue spotting balanced plugs until TOC is at intersection of Cirque #1 and Cirque #1X. 9) RIH with open ended 5" drill pipe to 9-5/8" shoe 1769', close Doyon Rig #9 annular preventer and break circulation. Monitor Cirque #1 for returns. POH. 10) PU 9-5/8" EZSV and RIH. Set EZSV in 9-5/8" casing at 1700' (AOGCC regulations require retainer to be within 50-100' of shoe and require at least 50' of cement on top of retainer). 1 1) Mix and pump Arctic Set IV cement on the fly (with Gillsonite for LCM) until cement returns show at surface of Cirque Well #1. Tail in with 200 bbls Arctic Set II cement for final plug. Unsting from retainer and dump 50 sks of cement on top of retainer. 12) Continue with P & A of surface hole. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg. / Wkvr Operator A~ ~ Location: Sec ~/J Location (general Housekeeping (general R 7~C)M ? Rig# ,, MUD SYSTE]~S: Trip tank Pit gauge Flow monitor Gas detectors Vi sual Audio TEST: Initial__ Weekly Representative Permit ~ ~ ~--Z ACCUMULATOR SYSTEM: Full charge pressure psig Press after closure psig Pump incr clos press 200 psig min sec Full charge press attained min sec N2 psig Controls: Master Remote B1 i nd switch cover KELLY AND FLOOR SAFETY VALVES: BOPE STACK: Annular.preventer Pipe rams Blind rams Choke line valves HCR valve77'/d Kill line valves Check valve Upper Kelly Test pressure' Test Pressure Lower Kelly Test pressure ~ ~ Ball type Test pressure ~'~00 Inside BOP Test pressure Choke manifold Test pressure Number valves ~'-~P ~0 Number flanges Adjustable chokes Hydraulically operated choke -. TEST RESULTS: Failures /~Y'~yb/~ Test time ~ /~F'/Uhrs Repair or replacement of failed equipment to be made within "'---days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Remarks: D~stribution: orig - AOGCC ¢ - Operator c - Supervisor C,004 (rev 01/92) STATE. W I TNESS REQU I RED? yes.___~, no 24-HR NOT I CE G I VEN? yes.~ no Waived by: Witnessed by: OPERATION: Drlg / Wkvr STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COmmISSION BOP Test Report TEST: Initial V//~ Weekly Other Operator ..AA I Location: Sec 20 T~/V Drlg contact. ~ Location (general) o~A-j ,, Housekeeping (general) ~/ Reserve pit . -- RT~ ~/M Well sign Rig MUD SYSTEMS: Vi 1 Audio Trip tank P J Pit 'gauge ~' J Fl ow moni tot J J Gas detectors ~ J J BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve 7~X=6 Kill line valves Cheek valve Test Pressure ~0o Representative ~ p/Z./~ ACCUMULATOR SYSTEM ft Full charge pressure j~bO Press after closure /7~J" Pump incr clos press 200 psig psig psig ~ min ~ min ~ psig ~ ~ sec ,~'~ sec Full charge press attained Controls: Master Remote__~ B1 tnd switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly Test pressure Lower Kelly Test pressure Ball type Test pressure Inside BOP Test pressure Choke manifold ~ Test pressure Number valves /~1/ Number flanges ~ Adjustable chokes ~/~ ' ~/~7 Hydraulically operated choke ~Y/~ ~OOO d-d~ o TEST RESULTS: Failures /~8/-]~ Test time ~ ,~' hfs Repair or replacement of failed equipment to be made within days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/08/91) WITNESS C / ~ l ~l ~ o q 4,,_5 (i,,~ O..L WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (900) 279-1433 TELECOPY: (907) 276-7542 February 21, 1992 Richard F. Morgan Regional Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: CIRQUE#1XRelief Well · ARCO Alaska, Inc. Permit No: 92-21 Sur. Loc. 15'FNL, 1855'FEL, Sec. 20, T9N, R7E, UM Btmhole Loc. 1010'FNL, 1859'FEL, Sec. 20, T9N, R7E, UM Dear Mr. Morgan: 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 given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-3607. D_avi_d W.._J~nh _sto% Chairman Alaska Oil a Ga Conservation Commission 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 ALA,..,A OIL AND GAS CONSERVATION COMMIS~E)N PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill ~ Redrill ~ J lb. Type of Well Exploratory~ Stratigraphic Test . Development Oil _ Re-Entry ~ Deepen --I Service ~ Development Gas ~ Single Zone_ Multiple Zone _ 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB ht above sea level; 170' Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-375076 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 15' FNL, 1855' FEL, Sec. 20, TgN, R7E, UM N/A Statewide At top of productive interval 8. Well number Number N/A CIRQUE #1X Relief Well #UG30610 At total depth 9. Approximate spud date Amount 1010' FNL, 1859' FEL. Sec. 20~ T9N, R7E, UM 2-21-92 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 1859 feet 5 ft at TD 5099 acres 2877' RKB feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 200feet Maximum hofe arkie 56° Maximum,u~f=~ 802 psi~ At total depth (TVD) 1222 18. Casing program Setting Depth size Specification Top BoUom Quantity of cement Hole Casing Weight Grade Coupling .ength MD TVD MD TVD linclude sta~e dataI 26" 20" N/A B,API ~ L PEB 80' 35' 35' 11 5' 1 1 5' Permafrost grouting 17.5" 13.375" 72# L-80 BTC 470' 35' 35' 505' 500' 830 sx Arctic Set I 12.25" 9.625" 47# L-80 BTC 1830' 35' 35' 1865' 1500' 200 sx "G"r 430 sx AS III 8.5 7 29# L-80 BTC 2842' 35' 35' 2877' 2500' 240 sx "G"r 140 sx AS III 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 Measured depth True V~cal~,,d~.~hl, S,,uc, ur ,K I::IVED Conductor Surface Intermediate ProductionF?~3C-L 2 0 '~r~Q~O Liner Perforation depth: measured Alaska Oil & Gas Cons, true ve.~l Anchorage 20. Altachments Filing fee ~ Property plat :X BOP Skelch X Diverler Skelch ~ Drilling program X Drilling fluid program ~ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ FZ/~c~4~J/~a'/~'Titlle- CommissionRegi°naluse OniyDrilling Engineer Date Permit Number ~API number I ~"'~:~ isee c°ver ~ter'or ~::~_-2_/~507/O~- ~O/~'~' '~, / "' ~:~'~ ..... other requirements CondiJions of approval Samples required ~Y e s ~ N o Mud log required~ Y e s ~ N o Hydrogen sulfide measures ~ Y e s ~ N o Directional survey required ~ Yes ~ N o Required working pressure for BOPE 'X~ 2M; ~ 3 M · ~ 5 M · ~ 1 0 M; ~ 1 5 M Other: by o~der of ~ Commissioner the commission Date . Form 10-401 Rev. 7 Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 20, 1992 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Cirque #1X (Relief Well) Dear Commissioner Johnston, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore well, the ARCO Cirque #1X, on State lands near the western boundary of the Kuparuk River Unit. This well will be a relief well for the Cirque #1 which had a blowout on 2/12/92. The proposed surface location is 1000' north of the blowout well. ARCO will be using Doyon Drilling, Inc.'s Rig 9 to drill this relief well. ARCO Alaska, Inc. as operator of the exploration well Cirque #1X, requests exemption for Hydrogen Sulfide measures. No hydrogen sulfide was detected on the mud log while drilling Cirque #1 prior to and during the blowout. No formations containing hydrogen sulfide are expected to be encountered in this relief well. The total depth for the well is 2877' MD or 2500' TVD' which will penetrate the K-10 formation. Enclosed find the information required by 20 AAC 25.005(c). If you have questions or require any additional information, please contact Tim Billingsley at 265-6575 or myself at 263-4970 in our Anchorage office. Sincerely, Richard F. Morgan ' Regional Drilling Engineer RECEIVED FEB 2 0 t992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 21, 1992 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Cirque #1X (Relief Well) Dear Commissioner Johnston, Tim Billingsley is my designated alternate to sign the Permit to Drill for the Cirque #1X relief well. Sincerely, .:. Richard F. Morgan ,.- Regional Drilling Engineer CIRQUE #1X DISCUSSION The Cirque #1 well blew out while making a trip out of the hole in preparation to run 9- 5/8" surface casing. TD of the well was 2415'. A mud weight of 9.4 ppg was sufficient to drill to this depth without observing any well flow. However, the subsequent blowout on a trip out of the hole indicates that the formation gradient is very close to 9.4 ppg. Mud Icg information and a MWD gamma ray/resistivity Icg on Cirque #1 indicate the K-10 sand at 2350' TVD is probably the source of the gas blowout. There are also some West Sak sands from 1700' to 1850' TVD which may be contributing to the gas flow. The Cirque #1X relief well will drill with 8.6 to 9.5 ppg mud to 500' TVD and set 13-3/8" surface casing. The intermediate hole will also be drilled with 9.4 to 9.6 ppg to 1500' TVD and 9-5/8" casing will be set. These mud weights should minimize the chance of losing returns into the blowout wellbore at a shallow depth. The production hole below the 9-5/8" shoe at 1500' TVD will be drilled with 10.0 ppg mud. If the two wellbores communicate at this time, the 10.0 ppg mud should circulate into the blowout wellbore and kill the gas flow. At all times while drilling the relief well, pumping equipment and large quantities of mud will be on site in order to pump down the drill string should communication (lost returns) occur. The BOP stack includes a spool which will have lines rigged up to auxiliary pumps to augment the rig's pumping capacity. The relief well will be directional drilled from 1000' away from the blowout well. An "S" shaped wellbore will provide close proximity between the two wellbores from the highest possible gas zones in the West Sak to TD. If no communication results while drilling the relief well, 7" casing will be set at TD of 2500' TVD. The K-10 at 2350' TVD will be perforated and mud pumped into the K-10 in an attempt to kill the blowout well. If this is not successful, the relief well may be plugged back and a similar procedure performed in the West Sak. RECEIVED FEB 2 0 992 Alaska Oil & Gas Cons. Anchorage PROPOSED DRILLING PROGRAM ARCO CIRQUE #1X (Per 20 AAC 25.005(c)(10)) I . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Note: Well Plan Cirque #1X Relief Well (All depths are measured from RKB unless otherwise noted) Move in and rig up Doyon 9. Install diverter system on pre-set 20" conductor. Test diverter system. Drill 12-1/4" hole to 13-3/8" surface casing point at 505' as per directional plan. Haul all drill cuttings and excess mud from this well to Kuparuk River Unit 2M pad for disposal in KRU Injection Well #2M-23. POOH with 12-1/4" bit and ream hole to 505' MD with 17-1/2" hole opener. Run and cement 13-3/8" 72#, L-80, BTC casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and drill 12-1/4" hole to 1865' MD. Run and cement 9-5/8" 47#, L-80, BTC casing. ND BOPE, install tubing spool, NU and test BOPE. RECEIVED FEB 2 0 3992 Alaska Oil & Gas Cons. Commission Anchorage Drill out float shoe and 10' of new formation. Run pressure integrity test to 12.0 ppg EMW. Drill 8-1/2" hole to TD of 2877' MD. POOH and PU MWD formation logging tools. Log open hole section with MWD tools. Run 7" 29#, L-80, BTC casing. ND BOPE and NU tree. Review logs and perforate blowout interval. RU Dowell on tree and pump at high rates into blowout interval attempting to kill Cirque #1. P&A both Cirque #1 blowout well by pumping cement from Cirque #1X. Using drill pipe as the work string, squeeze all open perforations in Cirque #1X and abandon well per 20 AAC 25.105. Install well abandonment marker per 20 AAC 25.120. Rig down and move rig. Thoroughly clean and abandon the ice pad and ice road. Large volumes of mud and pumping equipment will be on location at all times in case communication with Cirque #1 occurs while drilling Cirque #1X. DIRECTIONAL DRILLING PLAN ARCO CIRQUE #1X (Per 20 AAC 25.050(b)) RECEIVED FEB ~ 0 t992. Alaska Oil & Gas Cons. Gommis$ior~ Anchorage ATTACHMENT I ' ..:~. * 6 -; "" ' '~'' '" ' " . -~ ~ x. '.~ '~ .; .~· ..... ..~.. ,~ _. Iceberg~.,- ' - -' ..... '",,, (Proposed) UNION .... .;-._~ - -- Koo~ik ~1-: · . ,¢ ~ . SINCLAIR j - .Colville Delta #1 .... . - . · - r .., ; . , ,,, , I~ _;: I ;l! ~,-- · . ~ . ,: "', ,'r.' '7'~ 3 %1.- 2M PAD '^. ~ '. , ) .~" ~q-, ~ -, - ,~,'3~', .. :' 2T PAD MINE F 2A PAD 2H PAD ,,. PAD 1. ~A~ 0t:' HORfZONTAL I. OCA ~ I$ ~O~f, IId~NT CIRQUE REUE z ¢~r, ~ ,r ¢~ ~ I ~ ~ X= 4~9,121 LAT=70' 07' 58.05' ~ ~ LONG-150' 24' 51.05' ~ m 15' F.N.~, 1,855' F.E.~ ' SEC. 20, T9N, R7 E ~~ RECEIVED FEB 2 0 I ~ Alaska Oil & Bas Boris. ~~ OONDUOTOR AS-BUILT LOOA~ON Y=5, B~E,224 I ~ I x~ F[~ 101 F.N.L., 1,851' F.E.b I Le~Is~c. ~o. T, N., ~ ~ I C~"qU['-'' I ~0 ~.~..~. L __ -- -- --- J CIRQUE REUEF TO CIRQUE AZIMU~ ~ DISTANCE · C£A.-IitlXX-$O~DfO~ ~hf. 0Ol ~ ~ 't ~ '"l ..... "' ~ pr. ^~ iChk:.- MO= J NO $co~e ! I I .,,· ...... NO T~$ ~. BASIS OF HORIZONTAL LOC~TION I$ MONUMENT PER LOUNSBURY & ~SOC~ AND I~ONUI4ENT D.S, SOUTH PER L OUNSBURY ~ A5:51~ 2. BAS~S OF E~-VATION I$ MONUWE~VT O,$, 2-W SOUTH PER LOUNSBUR Y a ASSO~ $. ¢OOROINAT~$ SHOWN AR~ ALASKA STAT~ PLANE ZON£ 4, N.~O. 2Z 4. ELEYA llON$ SHO~N AR£ ~ IC~ PAO HAS NO ROTA 110N t'ROM NOR1H. $. CONDUCTOR NOT INSTALLE~ A~ TIME OF" ~URVEY, CIRQUE RELIEF WELL CELLAR X= 449,121 LAT.~70' 07' LONC~--I$O' 24' L~~ ~IN PRO~AC~D ~C. 20, ~. 9 N., R~. UMIA T M~/DIAN, O.G. EL= 1~4' T~ ~ ~~= 134.8' 'VOT TO SCALE L_. 819' $00' SUR VE YOR 'S CER T/FICA TLc t H£RE~Y CERTIFY THAT I AM PROPERLY REGI$TER£D AND LICENSED TO PRACTICE LAND SURVeYiNG IN TH£ STATE OF ALASKA AND THAT THIS PLAT REPR£$ENTE A 5%IRV~Y MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND THAT AI..L Oilt~E'N$1ON$ AND OTHER DETAII._~ ARE CORRECT AS OF' F'E~RUARY l~, 1992. ARCO ALASKA, INC. OIYG. NO: CEA-MI,)O(-6OIDI07 ~h£ 00! C/ROUE RELIEF WELL CELLAR AS-BUlL T MOG Bht 1 of 1 I: NS'K E, OI d107 ARCO ALASKA, Inc. Well · RLF #1 Location · NoFth Slope, Structure'Cirque Field · o o .. lOO o 200 O9 300 - - 400 - 500 600 700 ~) 800 900 1200- _ 1300- _ 1400- - 1500- _ 1600- - 1700- _ 1800- Tie on KOP 6.00 12.00 18.51 13 3/8 Csg Pt 24.00 30.00 36.00 42.00 48.00 54.00 EOC 54.00 48.00 42.00 Begin Angle Drop 36.00 50.00 24.00 18.00 Top Possible Gos Zone 12.00 6.00 Bose Possible Gos Zone End Angle Drop K--lO TO / 7 Liner J ~ i i ~ i i i t i i i { i i I i i i i i i i i 0 1 O0 200 300 400 500 600 700 800 go0 1000 11 O0 I1111111. <-- West 4-0 30 20 10 0 10 20 30 40 9 5/8 Csg Pt 970 .. 9~0 990 0 1000 - ---t-- -1010~" _ -1020 I - I - 1 o3o _ -1040 L 1060 RECEIVED FEB 2 0 t992 Alaska Oil & Gas Cons. Commission Anchorage DIAGRAM AND DESCRIPTION OF DIVERTER SYSTEM TO BE USED ARCO CIRQUE #1X (Per 20 AAC 25.005(c)(5)) RECEIVED F~B ~ 0 ~99~ Alaska Oil & Gas Cons. t,u~.nmisS'~O~ Anchorage DIVERTER SCHEMATIC ARCO CIRQUE #1X 10", 2000 psi Hydraulic Valve HYDRIL-GK 600, 20" Annular Preventer 20", 2000 psi Spool I Flowline I I 10" Blanked Flange 10" Outlet 20", 2000 psi Spool 10" Outlet 20" Riser Connector I 20" Conductor ! 10" Blanked Flange 10", 2000 psi Hydraulic Valve ,/ NOTE: Divert lines are 90° apart. Divert Lines are 10" Sch. 80 RECEIV D Alaska Oil & Gas Cons. Cornmiss~O~ Anchorage ARCO Alaska, Inc. requests approval of this diverter systemas a variance from 20 AAC 25.035(B) DIVERTER SCHEMATIC ARCO CIRQUE #1X TOP VIEW North Doyon 9 250' divert line 150' divert line Note: All divert lines are schdule 80 welded pipe connected to flanged Series 150 HCR divert valves on 20" diverter spools. There are no turns in the divert lines. Per 20 AAC 21~.005(c)(3): DIAGRAM AND DESCRIPTION OF BOP EQUIPMENT TO BE USED (As required in 20 AAC 25.035(a)(1)) AND INFORMATION ON MAXIMUM PRESSURES (As required in 20 AAC 25.035(d)(2)) RECEIVED ,~laska Oil & £~as Cons. Cornmiss~'°~ Anchorage BOP SCHEMATIC ARCO CIRQUE #1X DOYON 9 13-5/8", 5000 PSI Choke I I I I I I 1 I I I 3 I I ! I 10 II I I I I I Kill Line See listing of individual components on following page. ARCO CIRQUE #1X Doyon 9 13-5/8, 5000 PSI BOP COMPONENTS I , . . . 13-5/8", 5000 psi WP, Hydril annular preventer with companion flange to bell nipple. Single 13-5/8", 5000 psi WP, Hydril MPL blowout preventer fitted with pipe rams. Single 13-5/8", 5000 psi WP, Hydril MPL blowout preventer fitted with blind shear rams. 13-5/8", 5000 psi WP drilling spool. Choke Valves: 5. 3-1/8", 5000 psi WP Demco hydraulic valve. 6. 3-1/8", 5000 psi WP Demco manual valve. Kill Valves: 7. 3-1/8", 5000 psi WP Demco manual valve 8. 3-1/8", 5000 psi WP Demco hydraulic valve . 10. 13-5/8", 5000 psi, Hydril MPL blowout preventer with pipe rams. 13-5/8", 5000 psi WP drilling spool w/ a pair of 3-1/8" x 5000 psi Demco manual valves connected to lines and auxiliary pumps for additional kill pumping capacity. Alaska Oil & Gas Cons. Anchorage PRESSURE INFORMATION ARCO CIRQUE #1X The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Cirque #1X relief well. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure D ri I ling {in.) (ft. TVD~ {'lbs/gall (lbs/gal) (psi~ .~ 20 I 15 10.9 8.7 52 53 13-3/8 500 11.3 8.8 229 239 9-5/8 1500 12.4 9.1 710 802 7 2500 13.4 9.4 1222 Procedure for Calculatino Anticipated Surface Pressure ('ASP) _ ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)- 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 -- Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2) ASP: FPP - (0.11 x D) where' FPP = Formation Pore Pressure at the next casing point ASP Calculations 1. Drilling below conductor casing (16") ASP = ..-. [(FG x 0.052) - 0.11]D [(10.9 x 0.052) - 0.11] x 115 53 psi ASP = ,..,. FPP-(0.11 x D) 1161 - (0.11 x 2400) 897 psi RE'CEiVED FEB Alaska Oil & Gas Cons. Corn~iss~'°~ Anchorage . Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.11]D = /(11.3 x 0.052) . 0.11] x 500 -- 239 psi ASP= FPP. (0.11 x D) = 710- (0.11 X 1500) = 545 psi Drilling below intermediate casing (9-5/8") ASP = [(FG x 0.052) . 0.11]D = [(12.4 x 0.052) _ 0.11J x 1500 = 802 psi ASP= FPP . (0.11 x = 1222 - tO.11 x 2500) = 947 psi RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage Casina Performance ProDerties -- Size Weight Grade (in) (Ib/ft) 20" B, APl 5L 13-3/8" 72 L-80 L-80 L-80 9-5/8" 47 7 29 Cnxn Internal Collapse Tensile Strength Yield Resistance Joint Body (.osi) (psi) {1000 lbs) PEB Conductor Casing BTC 5380 2670 1650M 1661M BTC 6870 4750 1122M 1086M BTC 8160 7030 587 676 Casino Settino DeDth Rationale 2O" 115' TVD 13-3/8" 500'TVD 9 - 5 / 8" 1500' TVD 7" 25OO' TVD Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide early installation of BOPE in case deviated relief well communicates with blowout wellbore. Intermediate casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. This set point is above all suspect gas zones in the blowout well. Production casing to be set near blowout wellbore. Proceed with perforating suspect gas zones in blowout wellbore and establish communication to enable kill and P&A procedure on blowout wellbore. PROPOSED CASING AND CEMENTING PROGRAM ARCO CIRQUE #1X (Per 20 AAC 25.005(c)(4)) RECEIVED FEB ~ 0 ~9~ Alaska Oil & Gas Cons. Uui.nmiss'~o¢ Anchorage Cirque Relief #1X Well 20" Conductor @ 80' below Ground Level 13-3/8" 72#, L-80, BTC @ 505' MD/500' TVD RECEIVED FEB Alaska 0il & Gas Cons. 0omm'ts¢or~ Anchorage Top of Class G tail at 1550' MD/1241' TVD Cement Legend Arctic Set I Arctic Set III Class G 9-5/8" 47 #, L-80, BTC @ 1865' MD/1500' TVD 7' 29#, L-80, BTC @ 2877' MD/2500' TVD Cementing Program Cirque #1X Relief Well 13-3/8" Surface Casing Hole Size: 1 7- 1 /2" Depth: 505' MD Top of Cement: Surface Excess Calculated: 100% BHT (Static): 20°F BHT (Circ): 50°F Slurry Components and Properties: Preflushes: 40 bbl water Tail (No Lead) 830 Sx Arctic Set l Slurry Weight: Slurry Yield: Thickening time: 15.7 ppg 0.93 cu. ft./sk 3-4 hrs. 9-5/8" Production Casing Hole Size: 1 2 - 1 /4" Depth: 1865' MD Top of Cement: Surface Excess Calculated: BHT (Static): 40°F BHT (Circ): 50°F Slurry Components and Properties: 100% Preflushes: Lead: Tail: 40 bbls water 430 Sx Arctic Set III Slurry Weight: Slurry Yield: Thickening time: 12.1 ppg 1.94 cu. ft./sk 4+ hrs. 200 Sx Class G with 0.2% D-46, 2% S-1 Slurry Weight: 15.8 ppg Slurry Yield: 1.17 cu. ft./sk Thickening time: 3-4 hrs. RECEIVED FEB 2 0 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage Cementing Program Cirque #1X Relief Well 7" Production Casina Hole Size: Depth: Top of Cement: Excess Calculated: BHT (Static): BHT (Cir¢): 8-1/2" 2877' MD Surface 100% 40°F 50°F Slurry Components and Properties: (Cont.) Preflushes: Lead: 20 bbls ARCO spacer 140 Sx Arctic Set III Slurry Weight: Slurry Yield: Thickening time: 12.1 ppg 1.94 cu. ft./sk 4+ hrs. 240 Sx Class G with 0.2% D-46, 2% S-1 Slurry Weight: 15.8 ppg Slurry Yield: 1.17 cu. ft./sk Thickening time: 3-4 hrs. PROPOSED DRILLING FLUID PROGRAM and DRILLING FLUID SYSTEM DESCRIPTION ARCO CIRQUE #1X (Per 20 AAC 25.005(c)(6)) RECEIVED Alaska Oil & Gas Cons. Commission Anchorage CIRQUE #1X MUD PROGRAM Spud to 13-3/8" surface casing Drill out to 9-5/8" Drill out of 9-5/8" casing point to TD Density 8.6-9.5 9.4-9.6 10.0 PV 15-25 5-15 10-18 YP 15-35 30 reduced to 12 8-12 Funnel Viscosity 80-100 (Gravel 50-80 35-50 zones) 50-80 (Below zones) , Initial Gel 5-15 5-10 4-10 10 minute Gel 15-40 10-20 6-12 Filtrate API 10-15 10-15 10-15 pH 8.0-9.0 8.0-9.0 9.5-10.0 A. Spud Mud (To 13-3/8" Casing Point) Build 400 bbl new mud with funnel viscosity to 80-100 sec/qt (15-35 YP) and maintain as needed for effective hole cleaning in gravel zones. Maintain a pH of 9.0-10.0 with caustic soda or soda ash. Allow viscosity to come down as hole cleaning requirements are reduced to accommodate finer shaker screens. Funnel viscosities of 50-80 sec/qt should be adequate below the initial gravel zones. Run all solids control equipment to reduce solids content. Thin mud back to less than 20 YP before cementing surface casing. B. Spud Mud (13-3/8" csg. shoe to 9-5/8" casing shoe) Treat out any cement contamination with Bicarb. Keep YP in 30 range to ensure hole cleaning during directional work. Lower YP to 10-12 for cementing. Pre-treat for any contamination. C. Lightly Dispersed Mud (9-5/8" shoe to total depth) Treat out any cement contamination immediately with Bicarb. Run pH at 9.5-10.0 to help activate the lignites, etc. Before drilling out, lightly treat with CF Unical (1/2 ppb.) Before drilling out with a higher mud weight, (10.0 ppg or higher), consider treating with 6-8 ppb Check-Loss to eliminate potential losses during the last interval. Maintain YP @ 8-12 to keep hole clean, Gels @ 4+ to suspend Barite. DOYON g DRILLING FLUID SYSTEM DESCRIPTION MUD PITS AND CAPACITIES Number Volume · Active Pits 6 1115 bbls · Trip' Tank I 110 bbls · Pill Pit I 15 bbls MUD FACILITIES AND EQUIPMENT · Shale Shakers: 2 each Brandt Tandem II screen shale shakers mounted on sand trap. · Mud Cleaner: 2 each Triflow Model 8-4 mud cleaners, each with eight 4" cones. Each mud cleaner charged by one Galigher Model HRO 200 5"x6" pump rated at 900 gpm at 12 ppg. · Centrifuge: One Pioneer Mark II, rated at 200 gpm. · Gas Buster: One each; 15' high x 30" wide, with one 4" inlet, one 13-3/8" gas exit line and one 12" mud exit line. 150 psi rated working pressure. · One surface mixing gun on Iow pressure pit system. · One Press-Weld cellar jet pump, rated at 75 gpm. RECEIVED Alaska Oil & Gas Cons. L;ornrnissio~ Anchorage LEGEND f~ AMTATflo ~ 8UCTIO~ VALV~ FLOW ~T~FLY DOYON DRILLI INC. J.V. ~G q-MUD ~STEM F~W SHEET D- 8207 - 08 ~UCTION TANK i PILL I .... J L .... i I VOLUME TANK WATER TANK HOLE FILL TANK WATER ';'ANK GUN - SWIVEL , SHAKER TANK DOYON DRILLING INC. J.V. ,~,:, * ,.,,,, ,. , RIG 9 - MUD SYSTEM DISCHARGE PIPt~G - TANK LEVEL l-" SUCTION TANK (TYP) VOLUME TANK COUPLING (TYP) TYPE SUCTION VALVE(1YI~! _. (TYP] WATER___._TANK HOLE FILL TANK TANK SHAKE/? TANK ! I I I_ ..... -I I I I Ii PUI~I I I I I I TANK INFORMATION COMPARTMENT NO. I CAPACITY'- 130 BBLS. - 3t.2 BBLS/FT. - 2.6 BBLS./INCH DIMENSIONS-14°-6' L X 12'-O'W. X ~:)MPARTMENT NO, ~' CAPACITY o 125 8BLS, - 30 BSLS./FT. - 2.5 B~LS./INCH DIMENSIONS - 14'-0" EX 12'-O*W. X 7% O' O. HOLE FILL TAN.K. CAPACITY - I10 BSLS. - 20 BBLS./FT · 1.7 BBLS./INCH DIMENSIONS - 9% 3"L X 12'.- 0' W.X 7'-O' D. WATER TANK CAPACITY- 250 BBLS. - ~8.5 BBLS./FT. · 3.2 BBLS./INCH DIMENSIONS- 19'-O" L X 12'-O'W. X 7'~ O' D. $,6J~ID TRAp CaPACiTY- 14 8BLS. COMPARTMENT NO. - ~ BBLS./FT. - 25, ~LS./tNCH DIMENSIONS - 14'- O' L. X 12% 0' W. X 7'- O" D. C01V~ARTMENT NO. 4 CAPACffY- 120 BBLS. - 28.8 BBLS/F"[ - 2,4 [}BLS]INCH DIMENSIONS - 14°-6'EX 12 HOLDING TANK CAPACITY- 15 BBLS. -2.7 8BLS./FT. · 0.22 BBLS/INCH DIMENSIONS- ~.'o 0" L.X COMPARTMENT NO. 5 CAPACITY- 11.5 BBLS. -27.6 8Bt~/Fl: - 23 BBLS./INCH DIIVIENSIONS- 13'-O"L,X 11'-9' W. X '~-0' O. PILL TANK CAPACITY- 15 BBLS. 3.S B~LS/FI:. · 0.3 BSLS./INCH DIMENSIONS- 3'-O'L.X 6'-6'W.X?'-O'n COMPARTMENT N~. 6 CAPACITY- 120 BBLS. - 28.8 BBLS./FT. · 2.4 BBLSJINCH DIMENSIONS ~ 15% 6' L. X I I'- 9' W. X ?'- O' D. NOTES' I. ALL CAPACITIES SHOWN AR[ WI:N~KING CAPACATIES. CALCULATED FROM THE TOP OF TH[ SUCTION I:qI:qNG TO THE BOTTOM OF ~ MUD TROUGH. ~ TOP OF THE TANK. 2. ALL D4MENSIONS SHOWN ARE OVERALL DIMENSIONS I I I I I I I IJ I I I DOYON DRILLING INC. J.V. ~ ~' 81l:~177.1~rtII11 t:LrRSF~'C~ ~Lre".II3NL~ LTO. RIG 9- MUD SYSTEM SUCTION PIPING Depth 0,00 200,00 300,00 400,00 500.00 505,17 600.00 700,00 800,00 900,00 1000,00 1100,00 1143,27 1332.48 1375,75 1473.~ 1575,75 1675,75 1 ?73,75 I~6 187~.7~ 1975.75 Z075.73 2175.75 2227.19 2500,00 ARCO ALASKA, ir~, Cirque #1,RLF #1 ,#orth Stop~, Alaska Your ref : SLF #I Varslofl ~6 Leal re¥teed: 18-Feb-92 lnclln, Azimuth True Vart. R E C T A N a U L A R Oogt~ Vert Degreee DeQreeo Depth C 0 0 R D [ N A T E 0 Peg/lOOFt Se~t 0,00 t80,24 0,00 0,00 # 0.00 E 0.00 0.00 0,00 180.24 200.00 0,00 N 0,00 E 0,00 0,00 KOP 6,00 180,24 299.82 5.~ ~ 0.02 W 6.00 5.23 12.00 180,24 398,54 20,87 $ 0,09 ~ 6,00 20,87 10,00 150,24 ~95,09 66.?~ $ O,ZO ~ 6,~ ~,?& 18,31 180,2& 500,00 48,35 S 0,20 w 6,00 2&,O0 1R0,24 5M,48 82,56 s 0,35 u 6.00 30,00 180,24 677,46 t27.9~ s 0,54 u 6.00 36.00 180.24 761,29 182.37 S 0,77 U 6,00 &2.00 180,24 838.97 2~5.28 $ 1.0~ ~ 6.oo 48.00 180,2& ~9,65 315.95 S 1.34 Y 6,00 54,00 180.24 972.55 393,~ S 1.~ Y 6,00 56,60 iS0.2~ 997,18 429,20 ~ 1,82 ~ 6,00 56,60 180,24 1101.36 587,16 S 2,48 W 0,00 54.00 180,24 1125.99 62~,73 0 2,63 W 6,00 48.00 180.2& 118~.89 700.~1 g 2,96 W 6.00 &2.00 180.2~ 1~59.S? 771.08 S 3.26 ~ 6.00 36,00 180,24 1337,25 833,99 S 3,53 W 6,00 30,00 180,24 1~1,08 888.42 S 3,76~ 6.00 24.67 180,24 1500,00 929.22 S 3.93 U 6.00 24.00 180,24 1510.I& 9~3,80 S 3,95 W 6,00 18,00 180.Z& 1603,45 969,62 S &.lO U 6.00 12.00 180.2~ 1700.00 995.49 S ~,21 W 6.00 6,00 180,2~ I'~NI.~ 1011,13 S ~.28 ~ 6,00 2.91 180.24 1850.00 I015.12 $ 4.29 W 6.00 0,00 180,24 18~,5~ 1016,36 S 4,30 W 6.00 0,00 180.24 21~,~ 1016,~8 4.30 Q 0,~ 0,00 1~.2~ 2350.00 I016,~ S 4.30 W 0.~ 0,00 180,2& 2500,00 I016.~ $ 4,30 ~ 0,00 48.35 13 3/8. csg Pt 82,56 182.38 245.28 315,96 393,64 429,Z0 EOC 587,16 Begin Angle Drop 622.73 TO0.&1 ?71,09 833,99 929.23 9 5/~" Csg Pt 933.81 99~.50 Top PoaetbLe Gao Zone 1011,14 1016,37 End Angle Dro~ 1016,37 1016,37 g-t0 I016.37 TO / ?, Liner ORIGINAL RECEIVED _ Alaska Oil & Gas Cons. Anchorage ~EB Coordtnatea are from ol~t RLF #1 and TVDs ara fram wellhead, Vertical smctlon t8 fr~ ~ellhead on azimuth 180,Z~ ~aQraaa, calculation uaes the minimum curvature method, 18 '92 18:36 PAGE.a03 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee [2 thru 8] (3) Admin [~C,,, :~3~./~. 2_ 9. [9 thru 10. [10 & 13] 12. 13. [14 thru 22] 15. [23 thru 28] Company.... YES 1. Is pemit fee attached ............................................... ~ 2. Is well to 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 ava[-l'able in this pool ............. .~ 6. Is well to be deviated & is wellbore Plat included ................... ~ Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ (5) BOPE (6) Other E29 thru 31'] Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension, and burst. 20. Is well to be kicked off from an existing wellbore ................... 21. Is old wellbore abandonment procedure included on 10-403 ............. 22. Is adequate wellbore separation proposed ............................. (6) Addl 23. 24. 25. 26. 27. 28. 29. 30. 31. Is a diverter system required ........................................ ~ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of diverter & BOPE attached .... ~ Does BOPE have sufficient pressure rating -- test to ~2_¢oo psig ..... .//,F/~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... .... FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. 32. NO REMARKS O -4 '-rZ ~O Z geo 1 o~y' DWJ'd2) RPC eng i neer i ng~:. MTM,C~F LCS .,4~¢: dH'.3//~ .~f rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA .~ SHORE Additional remarks'