The URL can be used to link to this page

Home My WebLink About186-038MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3I-06 KUPARUK RIV UNIT 3I-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2023 3I-06 50-029-21935-00-00 189-038-0 W SPT 6064 1890380 1516 2840 2840 2840 2840 60 200 200 200 4YRTST P Brian Bixby 7/16/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3I-06 Inspection Date: Tubing OA Packer Depth 240 1820 1765 1760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230718164421 BBL Pumped:1.2 BBL Returned:1.2 Tuesday, September 12, 2023 Page 1 of 1          Image 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 RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [3 Grayscale items: D Other, No/Type D Other items scannable by large scanner [] Poor Quality Originals: ~ Other: P~{~..~ OVERSIZED (Non-Scannable) [3 Logs of various kinds [] Other TOTAL PAGES: J 5 NOTES: ORGANIZED BY: ~ERL~Y REN VINCENT SHERYL MARIA LOWELL Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ PAGES; I~-----~ (at the time of scanning) SCANNED BY: BEVERLY ~ VINCENT SHERYL MARIA ~si LOWELL DATE: j{~. I,~ ' 0~.- ~ RESCANNEDBY'- BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked {done) RevlNOTScanned.wpd MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Memorandum State of Alaska Oil and Gas Conservation Commission Re: Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 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 multilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (welibore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Steve McMains ' ~ '~'- Statistical Technician February 6, 1986 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 TELECOPY NO. 276-7542 Re: Kuparuk River Unit 3I-6 ARCO Alaska, Inc. Permit No. '86-38. Sur. Loc. 262'FSL, 84'FWL, Sec.31, T13N, R9E, UM. Btmhoie .Loc. 1419'FSL, 2013'FWL, Sec.31, T13N, R9E, DM. 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 governmental 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 Commqission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere 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. Ver~AY~ t ru lY ~Y~U~ ~rs' ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION dif 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 'i215 January 27, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3I-6 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk 3I-6, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o Proximity plots ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on February 10, 1986, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, - B ~.J ~<e~i n Regional Drilling Engineer JBK/JFB/tw ,, PD/L217 ~ ' Enclosures ARCO Alaska, Inc. is a Subsidiary of At ant cRichfieidCon~pany STATE OF ALASKA ALASKA ~.' AND GAS CONSERVATION CO,,~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~]X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRA'ITIGRAPHIC L-] SINGLE ZONE ~( MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 262' FSL, 84' FWL, Sec.31, T13N, R9E, UM At top of proposed producing interval 1293' FSL, 1802' FWL, Sec.31, T13N, R9E, UM At total depth 1419' FSL, 2013' FWL, Sec.31, T13N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 71', PAD 40' 6. Lease designation and serial no. ADL 25521 ALK 2557 9. Unit or lease name Kuparuk River Unit 10. Well number 31-6 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20AAC25.025) t-ederal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $5007000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 31-5 well 25' ~ surface feet 16. Proposed depth (MD & TVD) 18. Approximate spud date 7373' MD, 6545' TVD 02/10/86 2751 psig@__8~0°F Surface 3162 psig@ 6204 ft. TD (TVD) 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3430 feet. 21 14. Distance to nearest property or lease line miles 3267' ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 44 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program SIZE -- Hole Casing 24" 16" 1:2-1/4" 9-5/8" 8-1/2" 7" Weight' 62.5# 36.0# 26.0# CASING AND LINER Grade Coupling Length H-40 / Weld l 80' -55/HF-EIW BTC / 7342' MD SETTING DEPTH TOP TVD 32' I 32' 32' I 32' MD BOTTOM TVD 112t 112' 32811 3281' ' 31 ' I 31 ' 7373 I 6545' I QUANTITY OF CEMENT (include stage data) + 200 cf 1150 sx CS III 260 sx Class G 400 sx Class G 22. Describeproposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7373'MD(6545'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 2751 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, 31-6 will be 25' away from 31-5 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 ce?ill, hat the foregoing is true and correct to the best of my knowledge ......... TITLE Regional Drilling Engineer DATE Th e space b~v~f~)r ~8~/m i~ on use ~-- CONDITIONS OF APPROVAL Samples required Mud log required [YES ~¢NO []YES Approval date Permit number ¢L'"3~ ~__ ~ ,.02/.,06./86 APPROVED BY__ /~//Z~//'~// "-' Form 10401 (J~"~)~ 'PD/P~'zfi¢ t' ! / Rev. 7-1-80 Directional Survey required / APl number ~IYES []NO I 50- ~'L ~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSI ON ER DATE by order of the Commission February 6, 1986 Submit in triplicate PERMIT TO DRILL 31-6 (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. I IUi\ ,I,, J~ll I1~iII I · I : SOALE 1: IN. - 1000 FEET SURFACE LOCATXON~ 262' FSL, 84' FNL SEC. 31, T13N, RgE z PAD 3I. WELL' NO, 6 PROPOSED KUPARUK FIELD,., NORTH SLOPE,..ALASKA EASTI1AN WHIPSTOCK' [Nc' :', ~ 1000 3000 ~ WEST-EAST 0 1000 2000 3000 ,', ; , TD LOCAT 1419' FSL. 2013' FI,/L SEC-- . , TAROET LOOATION · .. 1 SEC. ;~1. TI~N. RgE 2000 _ 1000 _ 1000 SURF._j~ TARGET CENTER TVD=6345 THD=7096 DEP-2057 NORTH 1058 EAST 1764 N 59 DEO 3- HIN E 205T' (TO TARGET) ARCO ALASKA, INC - - PAD 3I, WELL' NO, 6 PROPOSED KUPARUK FIELD, NORTH SLOPE, ALASKA EASTHAN WHIPSTOCK. INC. _ ,_~ .... ._ .. 1000 ................... ' BASE PERMAFROST TVD:I 641 2000 ....... TOP UGNU SNDS TVD=2236 .. m 3000._ . ~._4000 ...... 5000 TOP W SAK SNDS TVD:2831 -'v=12. .... TVD~3081 ....... 5/8" 0S0 PT TVD=3281 - . KOP TVD=3430 TMD=3430 DEP=O g 15 BUILD 3 DEG ............................... 21 PER 100 FT _ 33~, K-$ ...... TVD=4TOl--TMD=4821-~DEP=454 EOC TVD=4751TMD=4889 DEP=530 . .. ................. 6000 .............. 7000 . _ _ 1000 2000 VERTICAL SECTION AVERAGE ANGLE 43 DEG 46 'MI N . . ...... T'/-'-ZONE O "TVD=6171 -TMD=6855 DEP=1890 " T/ ZONE C TVD=6204 TMD=6901 DEP=1922 T/ ZONE A TVD=6289 TMD=7018 DEP=2003 TAROET.-CNTR TVD=6345 TMD=7096 DEP=2057 B/ KUP SNDS TVD=6401 TMD=Z1T3 DEP=2111 TD (LO0 PT) TVD=6545 T~D=7373 DEP=2249 3000 00_ 00_ 00_ O0 :oo · \ ~ \ \ N \ 100 o ioo i , 200 I 300 I ! / / ! 867 1 867 ' / 400 500 600 POOl 48 / /. / 355 \ \ ~ "~ ; ~'.,'~ ,~.'1'./ / /~990 / / · ~ .'~1455 ~, ~ ~'1~4/:/L'~ ~1090 ,: I 1,455 ',,1,,090 ""22~2 KUPARUK R]:VER UN]:T 20" .DIVER'TER SCHEMATIC DE S CR I PT I ON Iii i i i i i i i [l~lWi~ . 2 RECEIVED I. 16" C~CTOR. 2. TAI',a(O STARTER MEAD. 3. TANKO SAVER SUB. 4. TAI~O LOWER QU!CK-C~CT ASSY. 5. TANI~O UPPER QOICK-C~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/I O' OUTLETS. 7. I0' HCR BALL VALVE~ W/I O" DIVERTER LIN~. VALVE,~ OPEN AUTOmaTICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI At',t~LAR PREVENTER. MAINTENANCE & OPERATION I. UPON INITIAL INSTALLATIO~ CLOSE PREVENTER A~) VERIFY THAT VALVES " HAVE OPENED PROPERLY. 2. CLOSE AN'AJLAR PREVENTER AND BLOW AIR THROUGN DIVERTER LINES EVERY 12 HOURS. CLOSE Aha"lJLAR PREVENTER IN THE EVENT'THAT AN I~FLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY, CLOSE APPROPRIATE VALVE TO ACHIEVE DOi'ItC~IND DIVERSION. DO INK)T SHUT IN ~E:LL UNE)ER ANY CIRCUMSTANCES. i ~' .'"'. "" i"2 1 6 5 4 3 Ij 2 DIAGRAM #1 13-5/8" ~ PS~ RSRRA BOP STAC~ I. 16' - 2000 PSI TAh/<CO STARTING F.E. AD 2. 11" - 3000 PSI CASING HE. AD 3. t1' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOCL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8' - ,5000 PSI DRILLING SPOOL W/CH(~ Ar, D KILL LINES 6. 13-5/8' - ,5000 PSI DOUBLE RA~ W/PIPE RAIv~ ON TOP, 7. 13-5/8' - ,5000 PSI ~ ACCLMJLATOR CAPACITY TEST I. CHE~ AhD FILL A~TCR RESERVOIR TO'PREPER LEVEL WI'TN HYDRAULIC FLUID. 2. A~ THAT ACCLI~T(]R F>~ESSlJRE IS 3000 PSI WITH 1500 PSI ~TREAM CF TFE REGJLATOR. (3BSE. RVE TI~E, TkE. N CLC~?_ ALL UNITS SI~EJl. TAh~Y AhD RECCRI) ~ TI~E AN2 PRE~ R~']~AINING AF'~ER ALL UNITS ARE CLOSED WITH CHARGING PLIvP CFF. 4. RE~ CN NADC REPCRT, TFE ACCEPT~E LO~ER LIMIT IS 45 SECOq]S CLOSING TI~ AN~) 1200 PSI REI4AINING PRE~. 13-5/8" BOP STAC:X' TEST 1. FILL BOP STAQ< AI',,D Q-t(;;I<E MANIFOLD WITH ARCTIC DIESEL. 2. Q-ECX THAT ALL LOQ< ~ ~ IN NEL. LFE. AD ARE FULLY I~TRACTED. SEAT TEST PLU6 IN WE]_LJ-EAD WITH Rt~ING JT AhD RUN IN L~ SCRE',~. 3. CLOSE A~ PR~-VE3qTER A~ MANU~ KILL AND C~ LINE VALVES ADJA(~ TO BCP STACX. ALL OTHER VALVES AN] Q-tO<ES SHOJLD BE OPEN. 4. PRE~ UP TO 250 PSI AhD HOLD FOR I0 MIN. IN.- CI~>EASE PRE~ TO 30C~ PSI A, hD HCLD FOR 10 MIN. BLEED PRE~ TO 0 PSI. 5. OPEN ~ PREVENTER AN2) MANJAL KILL AN2 CHO<E LINE VALVES. CLOSE TOP PIPE RAMS AN] HCR VALVES ON KILL AN] CHO<E LI~,ES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP '7. CCNTINJE TESTING ALL VALVES, LINES, AN;) Q-OKES WITH A ~ PSI LC~ AhD 3000 PSI HIGH. TEST AS IN STEP 4. DO NDT Pf~E~ TEST ANY CHCKE THAT IS NOT A FULL CLOSING POSITIVE SEAL Q-K]KE, CI',LY FUNCTION TEST CHCKES THA'T DO NOT FULLY CLOSE. 8, CPEN TCP PIPE RAMS AN:) CLOSE BOTTCM PIPE RAMS. TEST BOTTC~ PIPE RAV~ TO 250 PSI AhD 3000 PSI. 9, OPEN BOTTC~ PIPE RAMS, BAQ< OUT RUNqING JT AN2 PULL OUT CF HOLE. .10. CLOSE BLIN2 RAMS AN] TEST TO 250 PSI AN] .3000 PSI. 11. (;PEN BLIN] RAMS At~) RETRIEVE TEST PLUG. MA~E SURE MANIF~ AhD LIN~S ARE FULL. CF NCN-FREEZING FLUID, SET ALL VALVES IN DRILLING POSITICN. 12, TEST STAN]PIPE VALVES, KELLY, KELLY CCX;XS, DRILL PIPE SAFETY VALVE, AN~ INSICE BOP TO 250 PSI AN] 3000 PSI. , 13. RECORD TEST Ihi-"CRV, ATION ON BLCWOUT PREVENTER TEST FOG~, SIGN, AN2 SEN] TO DRILLING SUPERVISDR. 14. PF_RF~ CQd:~ETE BCPE TEST AFTER NIPPLING UP AN] WEEKLY THEREAFTER FUNCTIONALLY CPERATE BCPE DAILY. 510084001 REV. 2 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 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, d. Gruber Associate Engineer JG/tw GRU13/L06 Enclosure RFCFIVFD J'F.t, 2 4 ! 86 Alaska OtJ & Ga~ bu~]$, ummnission Anchorage If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany NOTES I. COORDINATES ARE A.S.E, ZONE 4. 2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BASEDON ON-PAD CONTROL PER L.H.D. ~ ASSOC. 4. VERTICAL POSITIONS BASEDONTBM 3[-4 PER LHD ~ ASSOC. 5. O.G. ELEVATIONS INTERPpLATED FROM S/C DWG. CED- RIXX- ~O50 rev. LOCATED IN PROTRACTED SEC. 3I,TI3 N, RgE, U. MER. LOCATED IN PROTR~TED SEC.~,TI3 N~ E SE, U. MER. 1- Y= 6,007,285.50 LAT. 70°25'52.0592" 9- Y= 6,007,121.00 LAT. 70°25'50.4432" X= 508,056.44 L0~G. 149°56'03.596'' X= 507,867.91 LONG. 149°56'09. 134" 179' F~L, 345' FSL 0G. 33.6', PAD 39.9' 180' FSL, 10' FEL OG. 35.0', PAD 39.9' t 2- Y= 6,007,~69.06 LAT. 70°25'51.8978" 10- Y= 6,007,104.59 LAT. 70°25'50.28~1" X= 508,037.66 L0~G. 149°56'04.148" X= 507,849.11 LONG. 149056'09.686" 160' F~L, 328' FSL OG. 33.7', PAD 39.9' 164' FSL, 29' FEL 0G. 35.0, PAD 40.0 3- Y= 6,007,~52.70 LAT. 70°25'51.7370'' 11- Y= 6,007,088.16 LAT. 70°25'50.1206'' X= 508,018.80 LONG. 149°56'04.702'' X= 507,830.23 LONG. 149°56'10.240'' 141' F~L, 312' FSL 0G. 33.7', PAD 40.0' 147' FSL, 48' FEL 0G. 35.0, PAD 40.1 4- Y= 6,007,236.23 LAT. 70°25'51.575Z'' 12- Y= 6,007,071.76 LAT. 70°25'49.9595" X= 507,999.99 LONG. 149~56'05.255 X= 507,8!1.32 LONG. 149°56'10.796'' ~ 122' F~L, 295' FSL OG. 33.8', PAD 40..0' 131' FSL, 66' FEL 0G. 35.0, PAD 40.1 i 5- Y= 6,007,Z19 81 LAT 70°~5'51.4139'' 13- Y= 6,007 055.32 LAT. 70°25'49 7981" j X= 507,981.16 LONG. 149o56'05.808" X= 507,792.36 LONG. 149°56'11.353'' , 104' F~L, 279' FSL 0G. 33.9', PAD 40.0' 1t5' FSL, CS' FEL 0G. 35.0', PAD 40.1' 6- Y= 6,007,203.20 LAT. 70°25'51.2507'' 14- Y= 6,007,038.82 LAT. 70°25'49.6359'' X= 507,962.12 LONG. 149°56 06.367" X= 507,773.63 LONG. 149°56 11.903" 85' F~L, 262' FSL 0G. 34.0', PAD 39.9' 98' FSL, 104' FEL 0G. 35.0, PAD 40.1' 7- Y= 6,007,186.78 LAT. 70°25'51.0895'' 15- Y= 6,007,022.42 LAT. 70o25'49.4749" X= 507,943.27 LONG. 149°56'06.920'' X= 507,754.83 LONG. 149°56'1Z.455'' 66' F~L, 246' FSL OG. 34.2', PAD 39.8" 82' FSL, 123' FEL 0G. 35.0', PAD 8- Y= 6,007,170.37 LAT. 70~25'50.9282'' 16- Y= 6,007,006.02 LAT. 70°25'49.3137'' X= 507,924.40 LONG. 149°56'07.475'' X= 507,736.04 LONG. 149°56'13.007'' 47' F~L, Z30' FSL 0G. 34.5', PAD 39.8' 65' FSL, 142' FEL 0G. 35.0', PAD 40.2' CErTIfICATE O~ SURVEYOR: ; ~E~E~Y CERTifY ~T I AM ~RO~ERLY ~EGIStERED AND LICENSED tO ~ACTICE LAND ~ ~ ~ M~DE BY ME OR UN~R MY SUPERVISION AND ~.e' . ~ ~_.-. THAT ALL DIMENSIONS AND OTHER DETAIL~ ~ ~ -' '~ ~ __11-,.~ ~URVEYED FOR: ~ ARGO Alaska, Inc. - -- ~. //x i ll ~WN wa DEILL SITE 5[ CONDUCTOE ...... ', ~, ._ ..,o~ . ~~, ~ ~ .~ ~ AS-bUilt LOCATION~ o,} ~ ~ ' ~- ~ -.~ .. ..... ................. , , , ~ _. - . , ~ "~ ~- ;' ~' 11DwG.NO. NsK 85-36 knch0ran6 q ~_ ~,:.~t,:o~v ~GA~ct/c Bouievard, Suite 201. Anchorage, Alaska 99503 /Is~LE As SHOWN ~ ~1 i i i i ii _oR NEW WELL PERMITS Company Lease & Well No. (1) Fee (2) Loc APPROVE DATE '~2 thru 8) (3) Admin ~ q-. ~ ~'ff& 9. (9~thru 121 / ~ 10. (10 and 12): 12. (4) Ca sg~..,~. (13 thru 21) (5) (22 thru 26) 1. Is 2. Is 3. Is 4. Is 5. Is 6. Is 7. 8. 13. ~14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is operator the only affected party ................................. ~ Can permit be approved before ten-day wait .......................... YES NO the permit fee attached ......................................... well to be located in a defined pool ............................. well located proper distance from property line .......... well located proper distance from other wells ....... ' ....... sufficient undedicated acreage available in this pooi' ' .' well to be deviated and is wellbore plat included o. . REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ............................. Is enough cement used to circulate on conductor and surfac Will cement tie in surface and intermediate or production WilI ~cement cover all known productive horizons .......... Will surface casing protect fresh water zones ............ Will all casing give adequate safety in collapse, tension 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 ................. e eeeeeeeee strings ...~ eeeeeeee and burst eeeeeeeeeee eeeeeee,eee Is a diverter system required ....................................... Are necessary diagrams of dtverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to 3CPO~ psig ..~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ,... Additional requirements ............................................. Additional Remarks:/9~w ~-~o7~;,v / >,so' o-O . l-d .-/ooo kop. Geology: Engineering: WVA~ MTM~ HJH JALC_p._...~o · , rev: 03/13/85 6.011 ..... INITIdL G'EO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE