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Home My WebLink About186-059Image 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. RESCAN DIGITAL DATA E] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: .,.~" Other: / PAGES:~,~ ~ NOTES: TOTAL ORGANIZED BY--PEN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other ~^TE:/0--/ ¢"- 0 .'Z ~S~ [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY.' BEVERLY BR~SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: //O/Z/O '~- Quality Checked (done) MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL IS PAGE Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: ~-- (~~ DATE Cancelled or ExPired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 Re: This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to 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 AP! number and in some instances the well name reflect the number of preexisting redriils and or muitilaterais 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 (weiibore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. St-eve McMa~ns ' ~ Statistical Technician March 24, 1986 Mr. J. B, Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy .' (907) 276-7542 Re: 3I-I1 ARCO Alaska, Inc. Permit No. 86-59 Sur. Loc. 147:FSL, 48'FEL, Sec. 36, T13N, R8E, UM. Btmhole Loc. 1461'FNL, 1356'FEL, Sec. 6, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated March 10, !986, accompanying the original approved permit are in effect for this revision. 5k~ry~ tru~g~/~o~qrs, ~ /' '.i.-~/P' :L,'~ Z/" C. V. chatte~0n Chai~an of: Alaska Oil and Gas ConserVation Co~ission BY ORDER OF THE CO~{ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery .--. STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C PERMIT TO DRILL 20 AAC 25.005 AMISSION la. Type of work. DRILL [~( REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL X~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~(X MULTIPLE ZONE [] REVISED 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 147' FSL, 48' FEL, 5ec.36, T13N, R8E, UH At top of proposed producing interval 1286! FNL, 1272' FEL, 5ec.6, T12N, RgE, UN At total depth 1461' FNL, 1356' FEL, Sec.6, T12N, RgE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 31-11 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71', PAD 40' I ADL 25631 ALK 2564 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14: Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 3819' L~ TD feet 31-12well 24' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7066'MD, 6528' TVD fe~.t 2560 03/30/86 19. If deviated (see 20 AAC 25.O50) t20. Anticipated pressures 2739 psig@ 80°F Surface KICK OFF POINT 3450 feet. MAXIMUM HOLE ANGLE 36 oI (see 20 AAC 25.035 (c) (2) 3148 psig@ 6177 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE cASING AN'D LINER SET:TING DEPTH QUANTITY OF CEMENT Hole I Casing Weight I Grade Coupling Length MD TOP TVD MD BOTTOMTVD (include stage data) 24;~ ii i(~" 62.5#I H-40 Weld 80' 32' I 32' 1i2'1 112' +200 cf 12-1/4"ii 9-5/8" 36.0# J-55 BTC 3229' 32' Il 32' 3261' ti 3261' 1"125 sx AS Ill & . HF-ERW I ~ I 275 sx Class G 8-1/2" ! 7" 26.0#~,i J-55 I BTC 7035" 31' I 31' i 7066' ] 6528' 400 sx Class C ,, 22. Describe proposea program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well. A 20", 2000 psi annular diverter be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack installed on the 9-5/8" surface casing will be tested to 3000 psi g upon installation and weekly thereafter. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Production casing will be tested to 3500 psi prior to releasing the drilling rig. Reserve pit fluid will be disposed of by pumping them down the 7" x 9-5/8" annulus this well. Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack The well will be completed.by the workover, rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perfOrated within the KuPardk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. . 23., hereby:/~hat the foregoing i~nd correct to the best of my knowledge SIGNED//'----/,J~(-/~-- TiTLE ' Regional Drilling Engineer DATE~.~//~ CONDITIONS OF APPROVAL Samples required []YES m~be~ O Permit nu APPROVED BY/ Form 10-401 ~JFB) PD/PD91 Mud log required I Directional Survey required I APl number EZYES ~No I I~YES []NO iS0_ 029-21_564 Approval date 03~,1~/86,.,.// I SEE COVER LETTER FOR OTHER REQUIREMENTS ./._//./-j/ ,., r.//~.-- ~-/~_ ~ ,COMMISSIONER DATE March 24, 1986 /7/~~~ by order of the Commission / Submit in triplicate KUPARUK FIELD,-NOR H SbOPE, ALASKA ......... . BASE PERMAFROST TVD=1 641 "::'TOP:. UGNU;-'SNDS...TVD=21 91. ' ........ __ ................ - . .............. . TOP W SAK SNDS TVD=2791 30.O.O..2~_.:K_.12...:TvD"306.i -~-'5/8 'csG PT-"--Tv~';326i KOP TVD=3450 TMD 3450 .............. o ...... 21 27 PER 100 FT - - EOC .... TVD=4572 THD=4649DEP=364 ..... K-5 - TVD=4621 TMD"'471 0 DEP'"400 AVERAGE -ANGLE ..... .3_5..__D'EG. 518 ..... HI.N · '.-T /---ZONE - D.' .... TVD=61 5 t .T-MD-6600 DEP- t 510 .............. - ._ _' ...,. . T/ ZONE C TVD=6177 TMD=6633. DEP=1529 ........... ~ ~, ~: T/ ZONE~A TVD=6260 TMD=6735 DEP=1590 - ................. " - ": ~ET:: CNTR ..... T.¥D=631 3 TMD=6801 DEP=1628 .......... .............................. ~ ...................... ~ .... B/ KUP SNDS .... TVD=6366 TMD=6866 DEP=1667 ..... ,, .................. ~. ................... : .......TD (LOG'PT)._. TVD=6528 TMD=Z066 DEP=1784 ............ ~ ......................... , .... N'ERTICAE~'-SECT-ION ...... ~ ............ ::. ..... '-_-.._:--_ :.'..~'- .... :'~__ ~:_:__: , : . . ........ ! ! : _:...2 0 3000 ' ......... ..T.A._R(~E T CENTER: mvu 6313 . ~.~.QE..p 1628 _i SOUTH 1467' ....... ) ' ~ =- ~ .... : ~ ': ' -; ' ' ' ' I i ...... ; LOCAT'ION, -~ ! ,' ........... i- - - ? : -: ..... ' 1320' ,FNL, 1288" FEL ........ i: ............. : ...... .'.._'.:...: ......... : ......... ._~_. ! ,- i . , . . .SEC. 6, T I2N, RgE ' ' 'i ~-: : ; t': ~ , TD L~ATiON~ ~. , - ......... , . 1~1 FNL, 13~6' FEL ,~ . ~C. 6,'TI2N, :R~ ..... .- S 25 DEG 421MIN W 1628' (TO TARGET) l , . :300 i 200 , i i 100 . , 600 I :~ 500 ~ 400 300.- 200 100 0 100 200 :300 ~ __ ,~____, , ~ ~ ~ ', . .i ~-. .: ............... x, \ , ,.> ,': :;i. I . ,!,'", ! % · · - , . . ' I , · k k ' ' ..... .4~,.~: ~;~ I ~ " ~ ' ' ~ ' ' : I I ; -',...-~.-,.:.. I.. [ '. ' ' [ - I b I ~ '. ~ ) ! i.,.; I :! : .... .......... '. ~-' 1~00 ~ ' ' ' ""' 1 44 : ~ · . ' '': ~ : ' / / 1 94 ' ' '{' · ~'l ::" i ~ '~"" ' ~061 ~! ~ : 11090 I/ : , ~' .-' ', , '/ : ; , /' '. ~ '~ -.:.1 :-~: .... , ........ _ . ..~ ......... : . . / .~ . ~,43~z ., . , ~ , . . , ~ . . , / I00 .... .......... ~ .~ ~..,.. , ....... · , 1877 ~1867 2 , . ~'.. ~w~ ~ . , .... ' ~ ', : , ' ~ , / , .' , · · " ; .. ~ ~ , . ' : t ' , * ' · ~ ...... t. , , , / / .,I ~>~ ' ~ ~ r · . ~ ' , ' , >00, ¢U.;:~[,, ~. t, ,.,. . ., . / , ../. , ';.,: ~ ........ ; , , ~ i.~ .... ·.', ~ , ~ · ~" ~ . :! ..l, ,., 600 o ~-.~.{-~,500~ ~',400 ....~00 200 100 KUPARUK VER UNIT 20" D~ VF__BTER SCHEMAT ~ C DESCR ! PT ! ON I. Ir:," CONDUCTOR. 2. TAI',,i<OSTARTER l-lEAD. 3. TANKO SAVER SUB. 4. TANKO LOVER OUI CK-C~CT ASSY. S. TAI'~O UI:::~ER (:XJICK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPCX:L Vi/! O' CXJTLETS. '7. I0' HCR BALL VALVES W/lO' DIVERTER LINES, VALVES OPEN AUTCNATICALLY UPON CLOSURE OF A~AR PREVENTER. E~. 20" 2CK:X:) PSI AKt~LAR PREVENTER. 6 '1 MAZNTENANCE & OPERAT.]O_N Io UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY, 2. CLOSE Ah, i',~LAR PREVENTER 'AND BLOW AIR THROUGH DIVERTER LIhES EVERY 12 HOURS. CLOSE A~LAR PREVENTER IN THE EVENT 'THAT AN Ih.c'LUX OF FLUIDS OR GAS IS DETECTED. IF NECESSARY, MA~ALLY OVERRIDE AND CLOSE APPEllATE VALVE TO ACHIEVE DO~tN/WlND DIVERSIOt~. DO NOT SHUT IN ~EL_L Uh, DER ANY CIRCUMSTANC:ES. 7 6 ~ DIAGRAM #1 13-5/ 5000 PS]] R~;RRA BOP ~T,ACK 6. 13'-5/8' - 5000 PS! ~ RAM W/PIPE RAk~ CIN TOP. 7. 13-5/8' - 5000 RS! ~ ACCLM.~ATOR CAPAC~rTY Ti~ST I. ~CX AND FILL AC~TCR RF.~OIR TO-P~ LEVEL WITH HYDRAULIC FLUID. ASSLR~ THAT A~TCR ~ IS ~ PSI WITH Q~SERVE TINE,, ~ CLOSE ALL t. INITS SII~IJLTAAE~Y 4. REQ;RD CIN NADC REPCRT. T~E ACCEPTABLE LOAER LIMIT IS 45 SE~ CLOSING TINE AN:) 1200 PSI RE~AINING 5 4 3 2 .I O. I1. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AhD CHOKE MANIFOLD WITH ARCTIC DIESEL. 2.. Q-ECK THAT ALL LOC3< DONN SC~ IN ~ A~ FLt_LY I:~-'TRACTED. SEAT TEST PLUG IN WITH Rtt~INING JT AhD ELIN IN LC~ SCR~. LIhE VALVES ADJACENT TO BO= STAOQ ALL OTi-F.R 4~ PRE~ UP TO 250 PS_~T~AMi~HO.D FOR I0 MIN. IN-- ~ PEE~ TO~DO0~ AAD HOLD FCR I0 MIN. BLm~r3 F~~ TO O~I. - 5. OPEN Aht~ PREVENTER AhD MANJAL KILL AAD C~E LINE VALVES. CLOSE TOP PIPE R~ AND HCR VALVES (3N KILL AhD CHCKE 6, TEST TO 250 PSI Ahi~--3OOO_P.S~I_AS IN STEP 4. ?. CCNrFINI~ TESTING ALL--~-VALVESo LIAF_S, AAD CHCKES WITH A 250 PSI LO~ AAD 3000 PSI HIGH. TEST AS IN STEP '4. DO NDT PR~ TEST. ANY. CHOKE~THATy')$ NOT A F1JLL CLOSIN~ POSITIVE SEAL CHOKE. F~ION TgST QHCKE$ THAI DO NOl FLLLY CLOSE. 8, C~ 'TOP PIPE RAI~ AhD CLCE~ ~OI'TC~4 PIPE RA/~. TEST BOTTC~4 PIPE RAMS TO 250 PSI AAD 3000 PSI. 9, CPI~N .BOTTOm4 PIPE P,A~o EiACX OUT RLt~NG JT AAD CLOSE BLIhD RA~ A~D TEST TO 250 PSI AhD .3000 .PSI. ' ' 'OPEN BLIND RAMS AhD RETRIE~ .TEsT PLUG. ~AqE '. SURE MANIFCI_D AhD LINES ARE FI~L. OF FLUID. SET ALL VALVES IN DRILLING I P-'TEST STANCPIPE VALVES, KELLY, KELLY C~So DRILL' PIPE SAFETY VALVE, AhD INSICE~ BCP TO 250 PSI A~D 3000 PSI. 13. RECCRD TEST IhF(~TICN ON BLCI~ ~ TEST FCIC, SIGN, AN:) SEAD TO DRILLING SUPERVISe. 14. PERFCI~ (~E BCPE TEST AFTER NIPPLIhI3 UP AhD VIF_EKLY THEREAFTER F1JNCTI~LY CI:~TE BOPE DArLY. II II March 10, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 ~Telecopy: (907) 276-7542 Re: 31-11 ARCO Alaska, Inc. Permit No. 86-59 Sur. Loc. 147:FSL, 48'FEL, Sec. 36, T13N, R8E, UM. Btmhole Loc. 1368'FNL, !305'FEL, Sec. 6, T12N, R9E, UM. Dear Mr-. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other goverr~ental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours' prior to commencing installation of the blowout prevention 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 commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~z-~ ~ru~~gr s, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMM~ISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc Post Office ...~x 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 31-11 Dear Mr. Chatterton' Enclosed are' We estimate spudding this well on March 21, 1986. questions, please call me at 263-4970. An application for Permit to Drill Kuparuk 31-11, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment If you have any Sincerely, Regional Drilling Engineer JBK/tw PD/L235 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 DRILL REDRILL DEEPEN SERVICE [] S T R ~TJ G R A P F~I~C,,,~,~ SINGLE ZONE ~ MULTIPLE ZONE 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 147' FSL, 48' FEL, 5ec.36, T13N, R8E, UN At top of proposed producing interval 1310' FNL, 1277' FEL, Sec.6, T12N, RgE, UM At total depth 1368' FNL, 1305' FEL, Sec.6, T12N, RgE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 31-11 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71', PAD 40' I ADL 25631 ALK 2564 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 3453' ~ TD feet 31-10well 26' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 6926' MD, 6562' TVD feet 2560 03/21/86 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2739 psig@__80°F . Surface KICK OFF POINT 2364 feet. oI (see 20 AAC 25.035 (c) (2) psig@ 6177 ft. TD (TVD) MAXIMUM HOLE ANGLE 28 3148 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing 24" 16" i'2-1/4" 9-5/8" '8-112" 7" 22. Describe proposed Weight 62.5# 36.0# 26.0# J program: CASING AND LINER Grade Coupling Length H-40 ~ Weld 80' -55/HF-E1W BTCI 3266' MD TOP TVD 32' I 32' 32' I 32' 31' I I 31' I t MD BOTTOM TVD 112i 112' / 32981 3261 , 6926'1 6562' I (include stage data) ± 200 cf 1125 sx AS III 275 sx Class G 400 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6926'MD(6562'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2739 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 31-11 will be 26' away from 31-10 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) · 23. I hereby c~e/rrtif¢ that the foregoing is true and correct to the best of my knowledge SIGNED //~,,~//¢,¢_,~(~'~ ~_~.,~,¢,~- TITLE Regional Drilling Engineer DATE The sp ace,,~6v~_ f o r/,C ~Frn r~sicsion use CONDITIONS OF APPROVAL Samples required Mud log required []YES ,~,,N O []YES /[~qO Permit number Approval date o¢/~-..f'_~ ,, I 03/1,.0/8,.6 APPROVED BY~"/--'"'~//~"'~/////~"'"'// // ' / - //-~~/ ~ ,/'~-/<. Form 10401 (JFB) PD/PD235 Rev. 7-1-80 Directional Survey required ]~YES []NO APl number 5o-~ ~ q' -Z/,.:-~ ¢ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Mar~h ~_0, 1986 by order of the Commission Submit in triplicate PERMIT TO DRILL 31-11 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO~ PERMIT TO DRILL 20 AAC 25.005 DRILL ~ lb. Typeofwell EXPLORATORY ~ SERVICE REDRILL ~ DEVELOPMENT OIL ~A SINGLE ZONE DEEPEN DEVELOPMENT GAS ~ MULTIPLE ZONE la. Type of work. 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 147' FSL, 48' FEL, Sec,36, T13N, RSE, UN At top of proposed producing interval 1310' FNL, 1277' FEL, Sec.6, T12N, R9E, UN At total depth 1368' FNL, 1305' FEL, Sec.6, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71', PAD 40' J ADL 25631 ALK 2564 12. Bond information (see 20AAC25.025) t~edera] Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 31-11 11. Field and pool Kuparuk River Fi eld Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 31-10well 26' ¢ surface feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 3453' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 6926' HD, 6562' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2364 feet. MAXIMUM HOLE ANGLE 28 oI (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 03/21/86 2739 psig@__80°F Surface 3148 . psig@ 6177 ft. TD (TVD) 21 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 (include stage data) 24" 16" 62.5# H-40 Weld ~0'" 32' I 32' 112i 112' + 200 cf 12-1/4" 9-5/8" 36.0# .-55/HF-EF:W BTC 3266' 32' 32' 3298! 3261' 1125 sx AS Ill ~ ) 275 sx Class G 8-1/2" i 7" 26.0# ~-55/HF-EFW BTC 6895' 31' II 31' 6926'1 6562' 400 sx Class C 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6926'HD(6562'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2739 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 31-11 will be 26' away from 31-10 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby c/ert~ that the foregoing is true and correct to the best of my knowledge SIGNED"/'"h , //~../~/../~¢.~', ',~"/ ~ ~ ~f~C~C/"f..4ZA./ /I ~ TITLE Regional Drilling Engineer DATE T e space/~w foC.,,Cbl~//sion use ' CONDITIONS OF APPROVAL Samples required ~L~YES [~JO Permit number86_ $9 APPROVED __ Form 10401 (JFB) PD/~b!%, . Mud log required Directional Survey required I APl number E~YES E~NO ~~YES E::]NO I 50- 029-21564 Approval date i SEE COVER LETTER FOR OTHER REQUIREMENTS m 03/10/86 t ~ / / ,COMMISSIONER DATE Ma,:ch 10, 1986 by order of the Commission Submit in triplicate PERMIT TO DRILL 31-11 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. HOR I'~']NT ^L PROJECTION SCALE I IN. = 1000 FEET ARCo' ALASKA, INC. PAD 3,. WELL NO, 11 PROPOSED ,//~~.~. KUPARUK F[ELD, NORTH SLOPE. ALASKA EASTMAN WH[PSTOCK. INC. 3000 1QO0 _ z C~ , 1 000 - 2000 _ 3000 _ TD LOCATION, 136~' FNL, 1305' FEL SEC. 6. T I2N. RgE WEST-EAST 2000 1000 0 ! , I , I SURFACE, 1000 SURFACE LOC&T [ OH ~ 14Z' FSL, 48' FEL SEC. 36. T IE~t. RSE TARGET CENTER TV~I3 TI"ID=~7'2 DE'P= 1628 SOUTH 1467 WEST 706 TAROT LOCATION, 1320' F#L. 1288' FEL SEC. 6. T12N. RgE S 25 DEI~ 42 MI N W 1628' (TO TARGET) ..... AROO' ALASKA' INC" ~ ' PAD 3I. WELL NO, 11 PROPOSED KUPARUK FIELD, NORTH SLOPE. ALASKA EASTHAN ~HIPSTOCK. INC. 2000 _ m 3000_ 4000_ m 5000 _ 6000. BASE pERMAFROST TYD-1641 TOP UGNU SNDS TVD-2191. KOP TVD-2364 TMD-2364 DEp=o 3 BUILD 3 DEO PER 100 FT 9 TOP W SAK SNDS TVD-2791 THD'2795 DIP'"48 K- 1 2 TVD~3061 THD-307-7 DEP-t 32 - 27' EOC (9 5/8' CSG PT) TVD-3261 THD'":3298 DEP-,224 AVERAGE ANGLE 28 DEG Kr5 TVD=4621 TtID=4838 DEP=947 27' 24 21 18 1-5 7000- 'm .......... 0 1000 VERTICAL SECTION BEGIN ANGLE 'DROp TVD-5151 THD-5438 DEP-1229 DROP 1 1/2 DEe PER 100 FT END ANGLE DROP (T/'ZONE D) TVD-6151 THDm6506 DEpm1594 T/ ZONE C TYD"6177 TtqD-65~3 DEP-!599 T/ ZONE A TVDm6260 THD-6618 DEP-1617 TARGET CNTR TVD-6313. THD-6672 DEP-1628 BASE KUP SNDS TVD-6366 THD-6726 DEP-1639 TD (LOG PT) TVD-6562 THD=6926 DIP-1 681 I TARGET ANGLE 2000 1 2 DEG O0 _ O0 _ 400 ' : · 3oo 200 ~ ~1 O0 100 20O I · :4oo' i 500' ' -i .... ;-: {"'-4 -..x :.;',4602:! :- : ' '- '-'-~ .... :-':% ' '~-'F~"?: ...... ~" ':-":- .... I' ~' ; ~': ; : , I"r i' : J i"t J' ' I i,: ,.,,,.i,:;~ ..., .... ,,.<.., ........ l,~.x,,.;ii:'~.,_.~_._. ,,,:lJl.,...~.., ,.._:_.:il L ' i "" ? I~O°i=i'~j :1~,oo,~!. ~. ,,.:. / .'.:"!"}'i ? :' · :? ....... i"~ : :':"i ~ 1 ;': : .... i"' I' 1 I 00. _ ... · I : , J : : . i ~ . : . : , , I I '. ', ' ' ....~ , 'l ! .... ~00 ''l : i ' i 300' t :'1i 200' ~ ' ' ". | : : ' : i : '~ : ': :-i ...... ~ i ' · , .'.t-:-.~. ', ,-: ,-,-.:..:--i-i-:-.~-~.. KUPARUK RI VER UNIT 20' DI VF_J:~TER SCHEMAT I C DE S CR ! PT ! ON I. 16" C~CTOR. 2. TAI',,I,(O STARTER lEAD. .'5. TAI~O' SAVER SUB. 4. TANKO LOWER. OUICK-C~CT ASSY. 5. TANKO UPPER OU I CK-C~CT ASSY. 6. 20' 2000 PS I DRI LLI NG SP(:X3L W/lO" · OUTLETS. 7. I0' HCR BALL VALVES W/lO" DIVERTER LINES, VALVES OPEN AUTOMAT I CALLY UPON CLOSURE OF ANN. JLAR PREVENTER. 8. 20" 2000 PSI A~LAR PREVENTER. 6 7 ~v',AINTENANCE & OPERATION 4 I. UPON INITIAL INSTALLATIO~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AhI~LAR PREVENTER At,I) BLOW AIR THROUGH DIVERTER LIhES EVERY 12 HOURS. 5 CLOSE AhlNULAR PREVENTER IN THE EVENT ·THAT AN Ih~'LUX OF WELLBCRE FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE AbE) CLOSE .APPROPRIATE VALVE TO ACHI EVE DOt~NWI ND DIVERS I ON. .. DO NOT SHUT IN ~ELL UNC)ER ANY CIRCUMSTANCES. 6 iiii I ii i i i ii DIAGRAM #I 13-5/8" 5CX20 PSI RSRRA BOP STA(~< I. 16' - 2000 PSI TAN<~ STARTING NE. AD 2. I1' - 3000 PSI CASING ~ 3. Ii' - 3000 PSI X 13--5/8" - 5000 PSI SPACER SPOOL 4. 13--,~/8' - 5000 PSI PIPE ~ 5. 1~..-5/8' - 5000 PSI DRILLING SPOOL W/~ AN:) KILL L I hF_.S 6. 13-5/8' - ~ PSI ~ ~ W/PIPE ~ ~ TOP, 7. 1D--5/8' - 5000 PSI ~ ACQJMUL, ATOR CAPAC]T,Y, T, gST I. C~CX At~D FILL ACCL~TOR RE~OIR TO PRCPF_R LEVEL WI~ ~~IC ~UID. 2. ~ ~T A~T~ ~ IS ~ ~I I~ ~I ~T~ ~ ~ ~~T~. '3. ~~ TI~. ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~l ~INI~ I3 2 13-5/8" BOP STAC~ TEST 1. FILL BCP STACK AAD ~ MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK ~ SCREYIS IN W~I.LFF_AD ARE F~Y RETRAC'T~. SF_AT TF_ST PLUG IN W~LL~ WITH RU~IN~ J'~ A~D RUN IN LO~ SCA~. LINg VALVES ADJACENT TO BOP STACK, ALL 4. PRESSURE UP TO 250 PSI ~ NOD FOR I0 MIN. IN- CREASE: PRE~ TO 3000 PSI AN:> HOLD FOR I0 MIN. BLEED PRE~ TO 0 PSI. 5. OPEN AN~ULAR P~EVENTER mN:> MANJAL KILL LINg VALVES. CLOSE TOP PIPE RAMS AN~ HOR VALVES ON FILL AN:> O-O<E LINgS. G. TEST TO 250 PSI AN:> 3000 PSI AS IN STEP 4. 7. 03NTINUE TESTING ALL VALVES, LI~_S, ~ CNO<ES WITH A 2.50 PSI L~W A~D 3000 PSI HIGH. TEST AS IN STEP 4. DO NDT PRE~ TEST ANY O-E]<E THAT IS NOT A FULL CLOSIF~ pOSIT~V~ SEAL ~ (3~.Y ~ION TEST ~S THAT DO NOT FULLY CLOSE. 8. (:PEN TOP PIPE ~ AAD CLOSE BOTTO~ PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI AN3 3000 PSI. 9, CPEN BOTTO~ PIPE RAMS, BACK OUT RUNNING JT mN:) .10. CLOSE BLIhD R/VaS ~ TEST TO 250 PSI mN:).3000 PSI, · Ii. CPEN BLIAD RAMS AI~ RETRIEVE TEST PLUG. MAKE'.SURE MANIFOLD At~ LINgS ARE FULL. OF NCN-FREEZING- FLUID. SET ALL VALVES IN DRILLING POSITICI~L I;~. TEST STAN:~PIPE VALVES, KF~_IY, KELLY COCXSo DRILL' PIPE SAFETY VALVE, mN:) INSIDE BCP TO 250 PSI AAD 3000 PSI. 13. RECCRD TEST IhF(~4ATION ON BLO/IOUT PREVENTER TEST FCR~, SIGN, mN:) SEN:) TO DRILLING SUPERVISOR. I I 51 (~384001 REV. 2 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-L,360 Telephone 907 276 1215 january 17, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3I Pad (Wells 1- 16) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, j. Gruber Associate Engineer JG/tw GRU13/L06 Enclosure RECF!VFD Alaska Oil & ~a~ bunS. ~u~.mission Anchorage If ARCO Alaska, Inc. is a Subsidiary of Atlanticc :hfieldCompany ~ , iiii ii i , i i , i,, ~'~ ~ i ~ i .... ii iii ~_ ~ ,111 i iii =l= ~ '~ ~URVEY 'SC~L~:i':I~'L~ NOTES I. COORDINATES ARE A.S.E, ZONE 4. 2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON ON-PAD CONTROL PER L.H.D. ~ ASSOC. 4. VERTICAL POSITIONS BASED ONTBM 3[ - 4 PER LHD ~ ASSOC. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED- RlXX- 3050 rev. ~ LOCATED IN PROTRACTED SEC. 5I,TI3 N~ R9E, U. MER. LOCATED IN PROTR~TEDSEC.~,TI3 N~ R8E~ U. MER. , [- Y= ~,007,235.50 LAT. 70°~5'5~.059~' 9- Y= 6,007,[2[.00 LAT. 70°25'50.443Z" X= 50~,056.44 LONG. [49°56' 03. 596'' X= 507,867.9[ LONG. [49°56'09. ~34" [79' FWL, 345' FSL 0G. 33.6', PAD 39.9' [80' FSL, [0' FEL 0G. 35.0', PAD 39.9' ~- Y= 5,007,269.06 LAT. 70°25'5[.~978'' [0- Y= 6,007,[04.59 LAT. 70°~5'50.~8Z[" X= 508,037.66 LONG. [49~56'04.[4S'' X= 507,849.~[ LONG. [49°56'09.686" [60' FWL, 328' FSL 0G. 33.7', PAD 39.9' [64' FSL, 29' FEL 0G. 35.0, PAD 40.0 3- Y= 6,007,252.70 LAT. 70~25'5[.7370'' [[- Y= 5,007 ,0S8. [6 LAT. 70°~5'50.[206'' X= 50~,018.~0 LONG. [49°56'04.70~'' X= 507,~30.~3 LONG. [49°56'[0.240'' [4[' FWL, 3[Z' FSL 0G. 33.7', PAD 40.0' [47' FSL, 48' FEL 0G. 35.0, PAD 40.[ 4- Y= 6,007,236.23 LAT. 70°25'5[.575~'' [2- Y= 6,007 ,07[.76 LAT. 70°25'49.9595'' X= 507,999.99 LONG. [49~55'05.255 X= 507,~[[.32 LONG. [49°56'[0.796'' [22' FWL, 295' FSL 0G. 33.S', PAD 40,0' [3[' FSL, 66' FEL 0G. 35.0, PAD 40.[ 5- Y= ~,007,~[9.~[ LAT. 70°25'5[.4139'' [3- Y= 6,007,055.32 LAT. 70~25'49.79~'' X= 507,9S[.[~ LONG. [49°56'05.~0~" X= 507,792.3~ LONG. [49~5~'[[.353'' [04' FWL, 279' FSL 0G. 33,9', PAD 40.0' [[5' FSL, ~5' FEL 0G. 35.0', PAD 40.[' ~- Y= 5,007,203.20 LAT. 70°25'5[.2507'' [~- Y= 6,007,03S.S2 LAT. 70°~5'49.~359 X= 507,962.[2 LONG. [49~56'06.3~7'' X= 507,773.53 LONG. ~49°5~'[[.903'' ~5' FWL, 2~2' FSL 0G 34.0', PAD 39 9' 9~' F~L, [04' FEL 0G. 35.0, PAD 40 7- Y= 5,007,[~5.7~ LAT. 70°~5'5[.0S95''' [5- Y= 6,007,022.42 LAT. 70°~5'49.4749'' X= 507,943.~7 LONG. [49°56'06.920'' X= 507,754.S3 LONG. [49°5~'[~.455'' 66' FWL, Z46' FSL OG. 34.~', PAD 39.~" S2' FSL, [23' FEL 0G. 35.0', PAD S- Y= 6,007,[70.37 LAT. 70~25'50.9~S2'' [6- Y= 6,007,006.02 LAT. 70°25'49.3137'' X= 507,924.40 LONG. [49°55'07.475'' X= 507,73~.04 LONG. [49°5~'[3.007'' 47' FWL, ~30' FSL 0G. 34.5', PAD 39.~' 55' FSL, [42' FEL 0G. 35.0', PAD ~1. iii i i iii ii ~ ii ii i i ii i i i,. CERTIFICATE OF S~ RVEYOR: ~ ~E~[gY CERTIFY THAT I AM PROPERLY .... ~ · · ......~q~ , ,, _/ ........ , :;,. ,~ ~ ~-~~. - ~~;... ..11'~:.~' SURVEYED FOR' ~ A~CO Alaska, Inc.''~ ~ '- '~ ~ ,/~7 ~~/~ ~ ~~~ECKEDG~ AS--BUILT LOCATION~sk~ ~t."~ % ,~...,.~ " ~ '~ ~uli~, ~k,~,~. ,~e~~ ............................ ffDWG. NO. NSK 85-36 Anch0r~ne ~ ~,,c.~s::,,ou~v ~Arcr/c Boulevard, Su/r~ 20 ~, Anchorage, ~laska ~9503 JlS~E AS SHOWN : IJlJOb i i i i i { i iii CHECK LIST FOR NEW WELL PERMITS ITE~ APPROVE DATE (2) Loc (~J~'" ~-~ L4'~ ( ¥2 thru 8) (3) Admin ~-'~ ~'~ ~ 9. ':: Y~-thru 12) 10. (10 and 12) 12. (13- th~u 21) (5) BOPE~ i--u 26) 1. Is the permit fee attached ........................... 2.. Is Well to be located in a defined pool ........... iii°°ii 3. Is well located proper distance from property line 4. Is well located proper distance from other wells .. 5. Is sufficient undedicated acreage available in this pool . 6. Is well to be deviated and is wellbore plat included ... 7. Is operator the only affected party ....... ~ 8. Can permit be apProved.before ten-day wait ~i~i~~..~ 13. -14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Does operator have a bond in force ...................... Is a conservation order needed eee®e®eeee,eeeeeeeeeeeeeee Lease & Well NO. _~ ~ '~// YES NO Is administrative approval needed ................................... Is the lease number appropriate ................................. ~- Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings --'z~_~ Will cement cover alt known productive horizons ................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to .7000 psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS o ~ 0 mm Geology: Engineer in g: LcS WVA ~ MTM~HJH rev: 03/13/85 6.011 INITIAL GEO'. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, , · '' CHECK 'LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No.. YES NO REMARKS Fee (2 thru 8) (8) <3> Adm:[Ln ~,)l~ ,,.~_zf_~?/_m 9. < 9 thru 1jn~__fg// 10. '.~ 11. (10 and 12)~ 12. (4) Ca sg ,~/z~/~ ~/~/ff,~ (13 thru ~1)' (5) '(22 thru 2'6) (6) Ad d: //z7-// ?,/~//~ .1. Is the permit 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 available in this po°l ............ 6. Is well to be deviated 'and is wellbore plat included ................ 7. IS operator the only affected party ............................... -..~ 8. Can permit be'approved' before ten-day wait ....... ' ...... ~ ............ 13. 14, 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. ~ · Is a conservation order needed ...................................... , , Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~--x~-- Is conductor string provided ........................................ Is enough cement u~ed to circulate on conductor nnd m!rfnco ,,,,,,,., Will cement tie in surface and intermediate or production Strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................ Is a diverter system required .................................... Are necessary diagrams of diverter and BOP equipment ;ttach;d ~. . ~/f/ ' Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb. 78) .................. Is the presenca of H2S gas probable .................................. Additional requirements ............................................. f~f_ O Geology: Engin~ering: JAL ~ ~ rev: 03/13/85 6.011 " INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO, SIIORE ,,