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Home My WebLink About185-279Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (~o.e) RESCAN o Color items: o Grayscale items: o Poor Quality Originals: o Other: _ . DIGITAL DATA [3 Diskettes, No. [] Other, No/Type ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds o Other ISl Project Proofing n Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: 3~'~ (at the time of scanning) SCANNED BY; ~BREN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScannecl.wlXl Memorandum To: Re: State of Alaska Well File: <~,~._ ~-~r-~c~ DATE Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 Oil and Gas Conservation Commission This memo will remain at the from of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to ddil. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician . . Page 1 of2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, July 27,20071:53 PM To: Peterson, Terry L (DNR) Subject: RE: ConocoPhillips lease surrenders \ ß5,~1 Terry, I have reviewed the subject well files. Kuukpik #3 (192-138): This well was plugged and abandoned by ARCO Alaska in April 1993. After an inspection in summer 1993, location clearance was granted by letter dated September 15, 1993. I saw nothing in the file to question the status. Colville 25-13-6 #1 (185-278): This well was plugged and abandoned by Amerada Hess Corporation in March 1986. After an inspection in early August 1994, location clearance was granted by letter dated August 19, 1994. saw nothing in the file to question the status. Please note that I have found the well name slightly different for the Amerada Hess well. Our files show the middle number to be 13 rather than 23. Also, has the lease been "transferred" from Amerada Hess to ConocoPhillips (or Phillips or ARCO)? Our file has no information regarding any company other than Amerada Hess. Amerada Hess intended to drill 3 wells and set conductor on another well_Colville 32-13-6 #1 Cj 85-279) on lease ADL 364475. According to the file, since the well was not drilled Amerada proposed to weld a plate on the 20" conductor and fill in the cellar box with the spoils from the conductor hole. Our file has no record of any site inspection for that well. I hope this fits your need, please message back with any questions. Tom Maunder, PE . en UL 3 0 2007 AOGCC SCANN...... J cc: well files ----.---.-- ..-.-'---.~-. From: Peterson, Terry L (DNR) Sent: Friday, July 27,2007 11:30 AM To: Maunder, Thomas E (DOA) Subject: ConocoPhillips lease surrenders Tom, The lease numbers are ADL 364477 and 364478: with Kuukpik #3 well being on 477 and AHC Colville 25-23-6 #1 well being on 478. I need to know if your office has signed off on their well abandonment before I can release them from the leases. Thank you for your help. Terry P Terry L Peterson State of Alaska, DNR Division of Oil and Gas Lease Administration 7/27/2007 May 5, 1993 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 J. Michael Robbins 540 L St Ste 205 Anchorage, AK 99501 Dear Mr. Robbins: We have received your April 23 letter requesting access to all information relating to wells permitted by Amerada Hess Corporation; and your May 3 telecopy of the protective order issued by the District Court in Case No. N90-004 Civ. Pursuant to Title 31, Section 31.05.035 of the Alaska Statutes, the Commissioner of Natural Resources has found that the well file on Colville Delta 25-13-6 No. 1 contains significant information relating to valuation of unleased land in the same vicinity. This well has been classified as confidential indefinitely, and will remain so until released by the Commissioner. Currently, we are seeking advice from the Department of Law as to the appropriate response to your request in view of the above referenced protective order. Due to workload constraints and the need to consult with legal counsel, we are unable to respond fully to your request within ten working days per 6 AAC 95.070. We anticipate furnishing the requested records, or issuing a determination that they are not disclosable, by May 24, 1993. This extension is not interposed for the purpose of delay. The following is a complete list of permits issued to Amerada Hess. PERMIT APl # WELL NAME WELL WELL CLASS STATUS 85-0085-0 029-21341-00 Northstar 1 expl susp* 85-0278-0 103-20054-00 Colville Delta 25-1 expl conf indef 85-0279-0 103-20055-00 Colville Delta 32-1 expl expired 86-0013-0 029-21511-00 Northstar 2 expl p&a* 87-0088-0 629-21747-00 Northstar 3 expl expired *The two publicly available well files can be reviewed at our office. Please contact Larry Grant at 279-1433 to schedule a time convenient for you. For your records, Mr. Chatterton retired in August, 1990. David W. Johnston is currently chairman of the Commission. Yours very truly, Russell A. Douglass Commissioner rpc/jo~amerhess RMERRDR HESS CORPORRTION February 24, 1986 550 WEST 7TH SUITE 1400 ANCHORAGE, ALASKA 99501 907-274-451 2 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Colville Delta 32-13-6 #1 Dear Mr. Chatterton: Enclosed in triplicate is Form 10-403, Sundry Notices and Reports on 'Wells, Notice of Intention To Abandon, on Colville Delta 32-13-6 91 well. Sincerely, · ~Mead Drilling Manager RJM:pk /, Enclosures. ALASKA ulIL AND GAS CONSERVATION C~J,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Amerada Hess Corporation 3. Address 550 W. 7th Avenue, Suite 1400, Anchoraqe, AK 99501 4. Location of Well 316'FNL,406'FWL,Sec. 32,T13N,R6E,U.M. 7. Permit ~ 8. APl Number 50- 103-20055 9. Unit or Lease Name Colville Delta 10. Well Number Colville Delta 32-13-6 #1 11. Field and Pool Wildcat 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Ground Level - 9' I ADL-364475 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon J~] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note. Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit ~n Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached schematic. AHC will postpone drilling of the referenced well until a later date. The location was an ice pad and cellar box and conductor was set and cemented. 20" pipe was set at 98' ground level and cemented in place with Permafrost type cement. The cellar will be backfilled with cuttings from the conductor hole. A plate will be welded over the conductor and the cellar box covered. See schematic drawing attached. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space b~iov~ for Comm~i~s ion use~ Date 2/24/86 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" m Triplicate and "Subsequent Reports" ~n Duplicate I November 29, 1985 Mr. Robert J. Mead Dril ling Manager Amerada Hess Corporation 550 W. Seventh Avenue, Suite 1400 Anchorage, Alaska 99501 Re: Colville Delta 32-13-6 No. 1 Araerada Hess Corporation Permit No. 85-279 Sur. Loc. 3i6'FNL, 406'FUL, Sec. 32, T13N, R6E, U~.~. Btm/~ole Loc. S ~ M E. Dear I,~. Mead: Enclosed is the approved application for permit to drill the above reference well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the ~ell site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout pre- vention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to comanencing equipment installation so that the Commission may ~tness testing before drilling below the shoe of t+~e conductor pipe. ~!~~_______V tr ~ ~ ours · · ~ k ! C. V. Chatterton Chairman Alaska Oil and Gas Conservation Co-remission BY ORDER OF THE CO~,~,ISoION be Enclosure cc: Department of Fish & Game, i~abitat Section u/o encl. Department of Environmental Conservation w/o encl. l'fr. Doug L. Lowery RMERRDR HESS CORPORRTION November 8, 1985 550 WEST7TH SUITE 1400 ANCHORAGE. ALASKA 99501 907-274-451 2 COlilOilIIAI Mr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Application for Permit to Drill Dear Mr. Chatterton: Enclosed in triplicate is form 10-401, Permit to Drill for Colville Delta 32-13-6 #1 well. The application filing fee in the amount of $100 is al so enclosed along wi th the required attachments. Sincerely, Robert J. Mead Drill ing Manager RJM-pk Attachments. .... STATE OF ALASKA '-' ALASKA OIL, .ND GAS CONSERVATION COM'...3SION RI=RMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY J~ DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L.~ SINGLE ZONE [] MULTIPLE ZONE [] 2 Name of operator Amerada Hess Corporation 3. Address 4. Location 3t6'FNL,406'FWL,Sec. At top of proposed producing ~nterval Same At total depth Same 550 West 7th, Suite 1400, Anchorage, Alaska of well at surface 32,T13N,R6E,U.M. 5 Elevation ~n feet (indicate KB, DF etc.) GL 9' 6. Lease designation and serial no ADL-364475 99501 9. Umt or lease name Colville Delta 10. Well number Colville Delta 32-13-6 #1 11. Field and pool Wildcat 12. Bond informanon (see 20 AAC 25.025) Type B1 anket surety and/or number 948498 13. Distance and d~rection from nearest town Nuiqsut 1 7,5 miles 16. Proposed depth (MD & TVD) 6689'MD 6689ITVDfe~t 14 Distance to nearest property or lease I~ne 4964' feet 1 7. Number of acres in lease ~ F~.7~ 2870 acres'~ - 19. If deviated (see 20 AAC 25.050) KICK OFF POINT UA feet. 21 MAXIMUM HOLE ANGLE 120. Anticipated pressures NAo I (see 20 AAC 25.035 (c) (2) Proposed Casing, .iner and Cementing Program Amount $200,000 15. D~stance to nearest drilling or completed we. Gulf Col vi 11 e feet 18. ApproxiJ~tlel~l~uc~l~te 2 i, 000 pslg@_ Surface 3400 _ps,g@ 6689 ft. TD (TVD) SIZE ~ Hole J Casing Weight 26"1 20" 92 72 17 1/;~13 3/8 ~,12 1/~ 9 5/8 81/ 7" 47 26 22. Describe proposed program. CASING AND LINER Grade Coupling A36 Weld N-80 BTC N-80 BTC N-80 BTC Length 80' SETTING DEPTH QUANTITY OF CEMENT TVD NA 300' NA MD TOP \ 80' I 300' i 2500' I NA 6689! i ~ NA 2500' 6689' MD BOTTOM TVD NA NA NA i NA NA I NA NA ~ NA I (~nclude stage data) Permafrost concrete 500 sk Arcticset est. 1625 sk Arcticset est. 450 sk Class G blend See program for details See attached' Drilling program, diverter schematic, diverter line location, BOP schematic, schematic of surface location and well course, survey plat of proposed location. RECEIV:LD Alaska 0u & (~as turin. Gu ..... ',msion Anchorage 23. I¢~r ,.~fy thaitheforego, ngistrueandcorrect to the best of my knowledge S,GNED/'~'-a ...../~Z~.-¥/'/=_: .... '>7:L':: RJ. . Mead TITLE Drilling Manager The space below for CommissiOn use DATE 1!/8/85 Samples required ~j~-Y ES []NO Permit number APPROVED BY Form 10-40t Rev 7-1-Rg CONDITIONS OF APPROVAL Mud Icg requ,red {~YES []NO Approval date 29/85 ,, ~ jDirectional Survey required J APl number _- []YES [~LNO J 50-/ ~ ~ - ~ ~ ~' ) ~' SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISS I ON ER DATE by order of the Commission November 29, 1985 Submit Ill triplicate .~ STATE Of ALASKA ALASKA OIL 4D GAS CONSERVATION COMf ;SION I ERMIT TO DRILL 20 AAC 25.005 1 a. Type of work. DRILL ~] lb. Type of well EXPLORATORY [~ REDRILL [] DEVELOPMENT OIL [] DEEPEN [] DEVELOPMENT GAS [] 2 Name of operator Amerada Hess Corporation _ 3 Address 4. Location of well at surface 316' FNL, 406' FWL, Sec. At top of proposed producing ~nterval Same At total depth Same 5. Elevation in f~-t (~-cate KB, DF etc.) GL 9' 550 West 7th, Suite 1400, Anchoraqe__,_Alaska 32,T13N,R6E,U.M. I 6 . Lease designation and serial no. ADL-364475 SERVICE E~ STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE 99501 9. Unit or lease name Colville Delta 10. Well number Colville Delta 32-13-6 #1 11. Field and pool Wildcat 12. Bond ~nformanon (see 20 AAC 25 025) Type Blanket Suretyand/or number 948498 13. Distance and direction from nearest town 14. D~stance to nearest property or lease I~ne Nuiqsut 17.5 miles 4964' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 6689'MD 6689' TVDfe~t '~' ,"~7'~ ~ acres 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT NA feet. MAXIMUM HOLE ANGLE NA Ol (see 20 AAC 25.035 (c) (2) Amount $200,000 15. O~stance to nearest drdl~ng or completed we~ Gulf Col ville feet ~8. Approx~/~t;~d~l;i~e 21,000 March 1. 1986 Z 89U ~ ps,g@_ Surface 3400 _ps,g@ 6689 ft. TD (TVD) ZI Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT _ Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (~nclude stage data) 26" 20" 92 A36 Weld 80' 80' I NA NA I NA Permafrost concrete 17 1/2113 3/8 72 N-80 BTC 300' 300' NA NA ' I NA 500 sk Arcticset est. It 47 N-80 BTC 2500' 2500' NA NA I NA 1625 sk Arcticset est". 12 8 ] / 9 5/8 1/2 7" 26 I N-80 BTC 6689' 6689' ~ NA NA I NA 450 sk Class G blend '] ~ ~ See program for detail .... \ ~ i,~ I .. 22. Describe proposed program: See attached' Drilling program, diverter schematic, diverter line location, BOP schematic, schematic of surface location and well course, survey plat of proposed location. 23. I .h.p,.by-celery that the foregoing is true and correct to the best of my knowledge SIGNED ..... _~-_]_ ..... -_ __ R.J. Mead TITLE Dri 11 i n§ Mana§er The space below for Comm~ss~En use DATE 11/8/85 Samples required ~YES [--]NO Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Mud tog required [~y, ES [-']NO , Approval date CONDITIONS OF APPROVAL D~rectlonal Survey required [ .APl number I []]YES [~NO 50' 103-20055 SEE COVER LETTER FOR OTHER REQUIREMENTS ! ,COMMISSIONER DATE by order of the Commission 1985 Submit .1 triplicate AMERADA I 20'ANIVULAR 2000 I~ ~. 20 ' ~000 I~. 20 "2000 I~. IO"OPERATOR 20.2000 HESS CORPORATION TO WEST CORNER COLVlLLE DELTA GENERALIZED 20" DIVERTER ARRANGEMENT 10 "VALVE 10" VALVE TO. EAST CORNER NOTE: THE 10' PNUEMATIC VALVE RIGGE[ )P SO THAT IT AUTOMATICALLY OPb .,,, WHEN ANNULAR IS CLOSED THE 10"MECHANICAL ~#~,LVES TO BE LINKED TOGETHER SO THAT ONE IS OPEN AT ALL TIMES. THIS DIVERTER SYSTEMWILL BE USED ON BOTH THE 20" CONDUCTOR AND 13 3/8" SHORT SURFAk. AMERADA HESS CORPORATION TO WEST CORNER COLVILLE DELTA GENERALIZED 20" DIVERTER ARRANGEMENT ! I 20"ANIVULAR ~ 200 016 ~. ~ '1 20 "2000 II~s. 20 "2000 I&s. 20 "2000 i&s. I 10" OPERATOR 10 "VALVE 10" VALVE TO. EAST CORNER NOTE: THE 10' PNUEMATIC VALVE RIGGF- iUP SO THAT IT AUTOMATICALLY WHEN ANNULAR IS CLOSED THE IO"MECHANICAL ~#kLVES TO BE LINKED TOGETHER SO THAT ONE IS OPEN AT ALL TIMES. THIS DIVERTER SYSTEMWILL BE USED ON BOTH THE 20" CONDUCTOR AND 13 3/$" S~ SURFAICE. AMERADA HESS CORPORATION COLVILLE DELTA TYPICAL DRILLING PAD WITH DIVERTER LINE LAYOUT ICE PAD 500'X500' CELLAR BOX 500' 500' C-1 AMERADA HESS CORPORATION COLVILLE DELTA TYPICAL DRILLING PAD WITH DlVERTER LINE LAYOUT ICE PAD 500'X500' CELLAR BOX 500' 500' AblERADA HESS CORPORATION FLOW LIN E COLVILLE DELTA GENERALIZED BOP ARRANGEMENT i ANNULAR //~35/~ $000/~~ PIPE RAMS ~ J /3 -" ooo/~,. J T~KE ~IFOLD I (~ ~/~ ~~, I ............. ~"~o~/~.~ PiPE RA~ ~ DRILLING SPOOL ADAPTOR 11" 5000psi. x 13 5/8'5000p$i. FOR NIPPLE UP OF 9$/8"CASlNG AND 71/16" 5000 psi. x 13 5/8' 5000psi. FOR NIPPLE UP OF 7" CASING COLVILLE DELTA WELLHEAD TUBING SPOOL 71/16" 5000psix 11" 5000psi INTERMEDIATE SPOOL 11"5000psL x 135/8"3000psi. STARTER HEAD 13 5/8"3000psi. x 13 3/8 SLIP ON WELD Alaska /]ii & Gas anchorage AblERADA HESS CORPORATION FLOW LIN E COLVILLE DELTA GENERALIZED BOP ARRANGEMENT I A~,, NULAR PIPE RAMS DRILLING SPOOL ADAPTOR 11" 5000psi. x 13 5J8"50OOpsi. FOR NIPPLE UP OF 9 5/8" CASING AND 71/16" 5000 psi. x 13 5/1~' 5000psi. FOR NIPPLE UP OF 7" CASING COLVILLE DELTA WELLHEAD TUBING SPOOL 71/16" 5000psix 11" 5000psi INTERMEDIATE SPOOL 11" 5000 psi. x 13 5/8 "3000psi. STARTER HEAD 13 5/8"3000psi. x 13 3/8 SLIP ON WELD · k,,.. STAKED LOCATION NO OTHER WELLS NEARBY ICE PAD - 500'X500' WITH 40'X70' EXTENSION _~ ~ '~, Alaska 0il & 6as Goris. Anchorage AMERADA HESS CORP. COLVILLE DELTA 32-13-6 NO. 1 316' FNL,406' FWI_, SEC 32, T13N, R6E, U.M. SURFACE LOCATION WITH WELL COURSE SCALE: 1'-50' · ~,-- STAK ED LOCATION NO OTHER WELLS NEARBY ICE PAD - 500'X500' WITH 40'X70' EXTENSION AMERADA HESS CORP. COI.¥11_LE DELTA 3E-$3-6 NO. 1 316' FNL,406' FWL, SEC 32, T131~ R6E, U.M. SURFACE LOCATION WITH WELL COURSE SCALE: 1'=50' HA RR! SON ~ 8AY ~ N 0 ~ T M 7 t Ig PROPOSED W Lat. = 70°26~ =,7.487! Long.= 150°$9' 50.955' Y:6,0 i 2,344.47 ZONE~tl X= 418,570.67 EL.'- 0.0' = EXIST. EA LEVEL. i L NO. 32-15-6 35 ALASKA 8 IT ~ 16 , : LOCATED WITHIN PEOTEACTED S ! U¥1AT 18 i IDIAN ALASKA CERTIFICATE OF' SUFtVEYOR: I ME~:aY CE~T,rY THA'r , AM ~O~E~LY I~L~3~aTEI~ E D .&NO L. ICENSED TO III~ACTICE LANO lllSSIIG, ~UIIIVE y IN(i IN '1"HE ~TATE 0t1~ AI,_A ~ KA AP40 THAT MA~ IY THAT ALL SURVEYED FOR' AMERADA HESS °ATE .-,,-e~ C0LVILLE DELTA o.... ~ECKEO GMS FIELD ~K 33a0 Arct~: 8outeva~f. Suite 20 l. Anchorege. Ala~a 99503 Ic.,~t.g I"= I a igjl ,~ GaS Ifil I'.N~ COLVILLE DELTA 32-13-6 DRILLING PROGRAM #1 A · Short Surface Hole (0 - 300') - 17 1/2" Hole · · · · · · · · Complete ri g up of Nabors 1ES over 20" conductor. Two (2) jts of 20" casing will be pre- set wi th cement in a dry drilled hole. With ~20" conductor in place weld on 20 1/4" - 2,000# flange' Install diverter spool and nipple up to 20" - 2,000# annular preventer. See divert- er assembly diagram. Suspend 20" annular from rotary beams for support. Test annul ar for closure on 5" drill pipe. (Notify AOGCC 48 hours in advance·) Mix spud mud and rig up Dowell cementing equip- ment. Pick up 17 1/2" bit, bit sub, 1-8" monel drill collar, 8-8" steel drill collars, crossover, drillpipe. Drill 17 1/2" hole to _+300'. Take single shot survey @ TD of 17 1/2" hole. Circul- ate bottoms up. Pull out of hole. Visually inspect casing and drift to 12.25". Dowell to test cement using rig water, require four hours thickening time. Prior to running casing (48 hours) notify AOGCC to witness job (279-1433). Run 13 3/8" 72# N-80 Buttress casing a. Dowell fl oat shoe. b. One (1) joint 13 3/8" casing. c. Dowell stab-in float collar. d. 13 3/8" casing to surface. as follows: Pipe lock bottom two joints. Run 10' above shoe and on first two centralizers and one stop collar). centralizer' s collars (three Stab 13 3/8" circulating head and circulate at least 350 bbls. mud before running stab-in tool. Pickup stab-in tool on 5" DP (no HWDP). Stab into fl oat col 1 ar and before cementing. break circulation ~\n;;horage B · 10. 11. 12. Surfa · · · · · Estimated volume of cement between 13 3/8" casing and 17 1/2" OH is 420 cubic feet including 100% excess. Have 800 sacks Dowel l Arcticset cement on location. Mix weight 14.9 ppg. Yield .95 cu.ft./sk. Pump 10 bbls. water ahead of cement. Mix and pump cement until returns are _+14.7 ppg. Displace with one (1) bbl. water ahead of mud to the fl oat collar. Check float and pull drillpipe out of hole. (WOC 12 hours before cutting 13 3/8"). Nipple down 20" diverter system. Wash out 13 3/8" x 20" annul us to _+5' below ground level and place nonfreezing fluid in the top 5' of annulus. With 13 3/8" casing in place, weld on 13 3/8" starter head and test weld to 700 psi. Install diverter spool and nipple up annul ar preventer. Test for closure on 5" drillpipe. See diverter diagram. Notify AOGCC 48 hours in advance for witnessing. ce Hole (+300' to 2500') 12 1/4" Hole Condition spud mud and rig up mudloggers. loggers operational below 13 3/8" casing. Mud - Pick up 12 1/4" bit, bit sub, 1-monel, 8 D.C., XO, jars and HWDP. Drill 12 1/4" hole to +2500'. Take single shot survey every 500' and on dulls. Make sure cellar is pumped out at all times. Circulate and condition hole for logs. Rig up Schlumberger and run following logs from TD to surface. a · ISF/LSS/GR Digital sonic tool (DST) Visually inspect casing and drift to 8.5" I.D. Dowell to test cement using rig water, require four hours thickening time. Prior to running casing (48 hours) notify AOGCC to witness job (279-1433). Calculate cement volume from open hole caliper logs. Estimated volume between 9 5/8" and 12 1/4" hole is 785 cubic feet. Should have +2500 sacks Arcticset on location. Mix weight 14.9 ppg. Calculate volume from caliper log +25%. RECEIVED C · · Circulate and condition hole for casing. 9 5/8" 47# N-80 Buttress as follows' Run a. Dowell fl oat shoe. b. Two (2) joints 9 5/8" casing. c. Dowell fl oat collar. d. 9 5/8" casing to surface. Pipe lock bottom two joints with centralizer 10' above the shoe and the next three (3) collars. (Four centralizers and one stop collar). Fill casing every five joints. Have circulating head available. · Circulate at least 500 bbls. of mud before cement- i ng. Precede cement wi th a 20 bbl. water spacer. Maintain pumping and displacing rate at _+8 bpm. Keep cellar pumped out. · If no cement returns job. Drain head and head. Washout 9 5/8" below ground level. annulus. to surface, perform a top Hydril and flush out well- x 13 3/8" annul us to _+5' Place nonfreezing fluid in · Install casing hanger and set slips with available casing load. 10. Cut off 9 5/8" casing, set back Hydril and install wellhead assembly. Nipple up BOP as per attached diagram and test as follows- a. 13 5/8" flanges 3,000# b. 11" flanges 5,000# c. Hydril 2,500# d. BOP 5,000# e. Kelly cocks, standpipe 5,000# f. Choke manifold 5,000# Rig up flare and blow down lines. Fill choke manifold with nonfreezing fluid. AOGCC may witness testing procedure. Intermediate Hole (2,500'-_+6,689') - 8 1/2" Hole · Install wear bushing. Run 8 1/2u bit with slick assembly· Strap in hole to float collar. Check against casing tally· ,Pressure test casing to 2000 psi. (Burst 9 5/8' 47~ N-80 is 6870 psi. Collapse 4750 psi). If cement job was question- able a CBL/VDL/GR/CCL log may be ~r~..~Fi~.~ ~?~]~ Anchora§e ~ Drill hole as fo out float collar and shoe and 20' of new with slick BHA. Run formation leak off test llows- a · Rig up Dowell - fill hole and pipe. Close pipe rams, install continuous recording pressure gauge. b ~ Pump down drill pipe in one-fourth barrel increments at lowest possible pump rate. After displacing each one fourth barrel, shut down pump and record pressure and volume. Continue this procedure until the pressure rise is no longer proportional to the volume increase. C · When formation starts to take fl uid, shut pump down and record pressures. Rel ease pressure and measure the backflow. Use the leak off test forms for recording the data. · · Pick up 8 1/2" BHA as follows: Bit, 6 1/4" monel, 6 1/4" dc- stb, 6 1/4" dc- stb, 6 1/4" dc- stb, (8) 6 1/4" dc - jars - HWDP. Drill ahead as directed by wellsite geologist. Drill an formation gist. A above the requi red. 3 / 4" x 4" 8 1/2" hole to top of the Nuiqsut Sa at_+6389' as directed by wellsite geol MWD tool may be run approximately 100 zone. Circulate and condition hole Pick up 8 1/2" coring assembly with x 60' standard core barrel with stab lizers. Install pump out sub and pick up drilli jars. Continue coring as directed by wellsi geologist. 60' cores will be cut. After cori is complete drill ahead as directed by wellsi geologist. Drill enough rat hole to ensure 1 pickup over the lowest zone of interest. nd 6 i- ng te ng te og · · After coring the Nuiqsut Sand and drilling rat hole, condition the hole for logs. Run the ist' the following electric logs from TD back to 9 5/8" shoe. Coordinate wi th wellsite geolog- a. ISF/LSS/GR/CAL b. Digital sonic tool c. LDT/CNL/NGT/GR d. EPT/PCD/GR e. SHDT f. RFT/GR (DST) available at District Office · · · g. Sidewall cores as directed by wellsite geologist and logging engineer (90 shots available) h. VSP Visually inspect casing and drift to 6 1/4". Dowell to test cement using rig water. Want five hours pump time. Notify AOGCC prior to casing job. After logging is complete, trip in to circulate and condition mud for casing· Install 7" rams. Prior to running casing, check with office for additional D.V. collar locations if required. Run the 7" casing as follows: (Burst-7240#, collapse- 5410#) a. Remove top pipe rams. Replace with 7" rams. b. Pull wear brushing. c. Run test plug on D.P. Close annular and test BOP to 2000 psi. d. Retrieve test plug. e. Dowell 7" buttress fl oat shoe. f. Two (2) joints 7" 26# N-80 casing. g. Dowell 7" buttress fl oat collar. h. 7" 26# N-80 buttress to surface. Caliper last five joints of 7" to insure O.D. size will accommodate slips. Run one (1) centralizer 10' above shoe, and next five (5) collars. Thread lock bottom three (3) joints. Run centralizers on every collar from T.D. to 5,500'. Hook up circulating head and circulate as required to clean hole. Circulate at least 500 bbls. Plan program to bring cement back to _+4,000' Estimat- ed cement required is 450 c.f. using ~5% excess· Calculate cement volume from caliper log. Cement with Class "G" with 3% KCL, 0.8% D60, 0.2% D46. Slurry weight 15·8 ppg. Yield 1.15 cf/sack. 4.97 gal/sack· Precede cement wi th a 50 bbl water flush and displace wi th mud at 10 BPM. Do not exceed 1,500 psi when pumping and 2,000 psi when bumping plug· Do not exceed 10 placement. 10. 11. 12. After cementing is complete and floats are checked land casing with available hook l#oad. Install tubing spool. Test packoff to 5,000 . Pressure test the BOP as follows. AOGCC may witness BOP. testing. a · All rams, valves, cno~e m~nifold Annular preventer- 2 500 _ 5000# Prepare to pressure test casing to 3000 psi and drill out casing and run CBL/VDL/GR log and gyro survey. Completion program to follow. DRL-3545 COLVILLE DELTA 32-13-6 DRILLING PROGRAM //1 A. Short Surface Hole (0- 300') - 17 1/2" Hole · Complete ri g up of Nabors 1ES over 20" conductor. Two (2) jts of 20" casing will be pre- set wi th cement in a dry drilled hole. · Wi th .20" conductor in place weld on 20 1/4" - 2,000~ flange. Install diverter spool and nipple up to 20" - 2,000# annular preventer. See divert- er assembly diagram. Suspend 20" annular from rotary beams for support. Test annul ar for closure on 5" drill pipe. (Notify AOGCC 48 hours in advance·) 3. Mix spud mud and rig up Dowell cementing equip- ment. · Pick up 17 1/2" bit, bit sub, 1-8" monel drill collar, 8-8" steel drill collars, crossover, drillpipe. Drill 17 1/2" hole to _+300' . Take single shot survey @ TD of 17 1/2" hole. Circul- ate bottoms up. Pull out of hole. · Visually inspect casing and drift to 12.25". Dowell to test cement using rig water, require four hours thickening time. Prior to running casing (48 hours) notify AOGCC to witness job (279-1433). · Run 13 3/8" 72# N-80 Buttress casing a. Dowell fl oat shoe. b. One (1) joint 13 3/8" casing· c. Dowell stab-in float collar. d. 13 3/8" casing to surface. as follows- Pipe lock bottom two joints. Run 10' above shoe and on first two centralizers and one stop collar). central i zer' s collars (three 7. Stab 13 3/8" circulating head and circulate at least 350 bbls. mud before running stab-in tool. 8. Pickup stab-in tool on 5" DP (no HWDP). 9. Stab into fl oat col 1 ar and break ci rcul ati on before cemehting. B · 10. 11. 12. Surfa · · · · · Estimated volume of cement between 13 3/8" casing and 17 1/2" OH is 420 cubic feet including 100% excess. Have 800 sacks Dowell Arcticset cement on location. Mix weight 14.9 ppg. Yield .95 cu.ft./sk. Pump ceme one coll hole Nipple down 20" diverter system. x 20" annul us to _+5' below ground nonfreezing fluid in the top 5' of level and annulus. 10 bbls. water ahead of cement. Mix and pump nt until returns are _+14.7 ppg. Displace with (1) bP1. water ahead of mud to the float ar. Check float and pull drillpipe out of · (WOC 12 hours before cutting 13 3/8"). Wash out 13 3/8" place Wi tn 13 3/8" casing in place, welcl on 13 3/8" starter head and test weld to 700 psi. Install diverter spool and nipple up annular preventer. Test for closure on 5" drillpipe. See diverter diagram. Notify AOGCC 48 hours in advance for witnessing. ce Hole (+300' to 2500') 12 1/4" Hole Condition spud mud and rig up mudloggers. loggers operational below 13 3/8" casing. Mud - Pick up 12 1/4" bit, bit sub, 1-monel, 8 D.C., XO, jars and HWDP. Drill 12 1/4" hole to _+2500'. Take single shot survey every 500' and on dulls. Make sure cellar is pumped out at all times. Circulate and condition hole for logs. Rig up Schlumberger and run following logs from TD to surface. a · ISF/LSS/GR Digital sonic tool (DST) Visually inspect casing and drift to 8.5" I.D. Dowell to test cement using rig water, require four hours thickening time. Prior to running casing (48 hours) notify AOGCC to witness job (279-1433)· Calculate cement volume from open hole caliper logs. Estimated volume between 9 5/8" and 12 1/4" hole is 785 cubic feet. Should have +2500 sacks Arcticset on location. Mix weight 14.9 ppg. Calculate volume from caliper log +25%. C · 6. Circulate and condition hole for casing. 9 5/8" 47# N-80 Buttress as follows: Run a. Dowell fl oat shoe. b. Two (2) joints 9 5/8" casing· c. Dowell fl oat collar. d. 9 5/8" casing to surface. Pipe lock bottom two joints with centralizer 10' above the shoe and the next three (3) collars. (Four centralizers and one stop collar). Fill casing every five joints. Have circulating heacl available. · Circulate at least 500 bbls. of mud before cement- i ng. Precede cement wi th a 20 bbl. water spacer. Maintain pumping and displacing rate at _+8 bpm. Keep cellar pumped out. · If no cement returns job. Drain head and head. Washout 9 5/8" below ground level. annulus. to surface, perform a top Hydril and flush out well- x 13 3/8" annul us to _+5' Place nonfreezing fluid in · Install casing hanger and set slips with available casing load. 10. Cut off 9 5/8" casing, set back Hydril and install wellhead assembly. Nipple up BOP as per attached diagram and test as follows: a. 13 5/8" flanges 3,000# b. 11" flanges 5,000# c. Hydril 2,500# d. BOP 5,000# e. Kelly cocks, standpipe 5,000# f. Choke manifold 5,000# Rig up flare and blow down lines. Fill choke manifold with nonfreezing fluid. AOGCC may witness testing procedure. Inter 1. mediate Hole (2,500'-._+6,689') Install wear bushing. Run 8 assembly. Strap in hole to against casing tally. 2000 psi. (Burst 9 Collapse 4750 psi). able a CBL/VDL/GR/CCL - 8 1/2" Hole 1/2" bit with slick fl oat collar. Check 5/8'Press~ure'N test casing to 47~ -80 is 6870 psi. If cement job was question- log may be run. · Drill out float collar and shoe and 20' of new hole with slick BHA. Run formation leak off test as follows- a · Rig up Dowell - fill hole and pipe. Close pipe rams, install continuous recording pressure gauge. b · Pump down drill pipe in one-fourth barrel increments at lowest possible pump rate. After displacing each one fourth barrel, shut down pump and record pressure and volume. Continue this procedure until the pressure rise is no longer proportional to the volume increase. C · When formation starts to take fl uid, shut pump down and record pressures. Release pressure and measure the backflow. Use the leak off test forms for recording the data. · · Pick up 8 1/2" BHA as follows. Bit, 6 1/4" monel, 6 1/4" dc- stb, 6 1/4" dc- stb, 6 1/4" dc- stb, (8) 6 1/4" dc - jars - HWDP. Drill ahead as directed by wellsite geologist. Drill an formation gist. A above ti~e requi red. 8 1/2" hole to top of the Nuiqsut Sand at_+6389' as directed by wellsite geolo- MWD tool may be run approximately 1000' zone. Circulate and condition hole as Pick up 8 1/2" coring assembly with 6 3/4" x 4" x 60' standard core barrel with stabi- lizers. Install pump out sub and pick up drilling jars. Continue coring as directed by wellsite geologist. 60' cores will be cut. After coring is complete drill ahead as directed by wellsite geologist. Drill enough rat hole to ensure log pickup over the lowest zone of interest. · · After coring the Nuiqsut Sand and drilling rat hole, condition the hole for logs. Run the following electric the 9 5/8" shoe. Coordinate ist. a. ISF/LSS/GR/CAL b. Digital sonic tool (DST) c. LDT/CNL/NGT/GR d. EPT/PCD/GR e. SFIDT f. RFT/GR logs from TD back to wi th wellsite geolog- available at District Office · · · g. Sidewall cores as directed by wellsite geologist and logging engineer (90 shots available) Iq. VSP Visually inspect casing and drift to 6 1/4". Dowell to test cement using rig water. Want five hours pump time. Notify AOGCC prior to casing job. After logging is complete, trip in to circulate and condition mud for casing. Install 7" rams. Prior to running casing, check with office for additional D.V. collar locations if required. Run the 7" casing as follows: (Burst-7240#, collapse- 5410#) a. Remove top pipe rams. Replace wi th 7" rams. b. Pull wear bruslqing. c. Run test plug on D.P. Close annular and test BOP to 2000 psi. d. Retrieve test plug. e. Dowell 7" buttress fl oat shoe. f. Two (2) joints 7" 26# N-80 casing. g. Dowell 7" buttress fl oat collar. h. 7" 26# N-80 buttress to surface. Caliper last five joints of 7" to insure O.D. size will accommodate slips. Run one (1) centralizer 10' above shoe, and next five (5) collars. Thread lock bottom three (3) joints. Run centralizers on every collar from T.D. to 5,500'. Hook up circulating head and circulate as required to clean hole. Circulate at least 500 bbls. Plan program to bring cement back to +4,000' Estimat- ed cement required is 450 c.f. using ~5% excess. Calculate cement volume from caliper log. Cement with Class "G" with 3% KCL, 0.8% D60, 0.2% D46. Slurry weight 15.8 ppg. Yield 1.15 cf/sack. 4.97 gal/sack. Precede cement wi th a 50 bbl water flush and displace wi th mud at 10 BPM. Do not exceed 1,500 psi when pumping and 2,000 psi when bumping plug. Do not exceed 10 bbls of overdis- placement. 10. 11. 12. After cementing is complete and fl oats are land casing with available hook l~oad. tubing spool. Test packoff to 5,000 . checked Install Pressure test the BOP as follows. AOGCC witness BOP testing. a · All rams, valves, cnok, e m~nifold - Annular preventer - 2 500 5000~ may Prepare to pressure test casing to 3000 psi drill out casing and run CBL/VDL/GR log and survey. Completion program to follow. and gyro DRL-3545 RECEIVED OiJ & G85 CONS, Comm~ssior~ Anchoraoe CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1)Fee ~--,~~t h~uru (2) .oc 8 3. 4. e (3) ~dmin~,~'L/" / / .'"V'~ '_~ 9. () thru 12) 10. '(lo hh~ 12) 12. (13 thru 21) 13. 14. 15. 16. 17. 18. 19. 20. 21. (22 thru 26) (6) Add: 22. 23. 24. 25. 26. 27. YES NO . Is the permit fee attached ........................................ ..~~__ Is well to be located in a defined pool ................ .. '~~' Is well located proper distance from property line ..... Is well located proper distance from other wells ......... i ~~ Is sufficient undedicated acreage available in this pool . ~-~f--' Is well to be deviated and is wellbore plat included .... Is operator the only affected party .................... Can permit be approved before ten-day wait ............. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... /t~ Is conductor string provided ................ Is enough cement used to circulate ~ ~;~t~ ~d ~~ i.ii..i. Will cement tie in surface and intermediate or production strings .. Will cement cover all known productive horizons ............. Will surface casing protect fresh water zones ...... ~...i~..ii.i.~ Will all casing give adequate safety in collapse, tension and burstl 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 ........................... REMARKS Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating - Test to ~O~DC) Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: /~*~ ~ ~ ' z/- o Geology: H~ ~ LCS ~ rev: 03!13/85 011 Engineering: BEW ~ HJIt · . INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE