Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
182-149
WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Correlation Record: 1G-03 Run Date: 8/8/2019 182149 3 135 3 October 16, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1G-03 Digital Data in LAS format, Digital Log Image file 50-029-20824-00 RECEIVED OCT 2 3 1019 AOOCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: b /� Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT €' 9 21019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ ' ter. �+�,�❑ Performed Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WHIPSTOCKD 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development C] Stratigraphic❑ Exploratory ❑ Service ❑ 182-149 3. Address: P. O. Box 100360, Anchorage, 6. API Number. Alaska 99510 50-029-20824-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25640 K RU IG -03 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool it. Present Well Condition Summary: Total Depth measured 8,489 feet Plugs measured None feet true vertical 6,951 feet Junk measured None feet Effective Depth measured 8,464 feet Packer measured 3,650 feet true vertical 6,929 feet true vertical 3,250 feet Casing Length Size MD TvD Burst Collapse CONDUCTOR 78 feet 16 108' MD 108' TVD SURFACE 2,274 feet 10 3/4 " 2,303' MD 2216' TVD PRODUCTION 8,436 feet 7 8,464' MD 6929' TVD Perforation depth: Measured depth: 3669-3826 feet True Vertical depth: 3264-3378 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 3,633' MD 3,238' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -BAKER FP S3 PACKER 3,650' MD 3,250' TVD SSSV - None 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments (required per 20 MC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development PI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPK 1110 • SPLUG ❑ 17. 1 hereby certify that the foregoing is true and Correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-327 Authorized Name: James Ohlinger Contact Name: Ryan McLaughlin - contact Email: ryan.mclaughlin@cop.com Authorized Title: Staff CTD Engineer Authorizetl Signature: Date: /a Contact Phone: (907) 265-6218 Form 10-404 Revised 4/2017 /r �7-�Submit Original Only /9 t�/z��� 9 MMS�w nrT 1 , 9n1n IG -103 Proposed CTD Schematic 76" 65R H-00 shoe @ 108' MD KSS shoeoe @ @ 2303 M0, 2216' ND Arctic Pack cement "2100'-2500' via CBL 10- 3-82 (RA tracer) A CTD KOP 3808' MD Top of good quality cement behind the 7" at -7380' (CBL of 8-21-84) 1G-103 TD: 11,960 MD 3-1/2" solid liner w/sealbore deployment sleeve 3790'967' 2-7/8" solid liner 3967'5690', 5626'-7079- 2-7/8" slotted liner 5690'-6526', 7079'-11960' cowcomillips Alaska, Inc. KUP INJ WELLNAME 1113-03 WELLBORE 113-03 1cm,+.,a, 35x30 -M Last Tag etiwlsMnmec Isthmi v.HANGER/us----_..... .-tatien GpIn MKS) I End Date welloore .IMod., bj ........................ ............., Last Tag: RKB Drdr5.OwJwZ119 113-03 fama Last Rev Reason Annual End Data wellbore Last Mode, Rev Reason. Set Liner Top Packer 9/1212019 1G-03 bwonM1i Casing Strings Casing oeemilmA CONDUCTOR Do (in) lo(..) 16 1525 17 15:1: see Gpm (nnal set oepm Ovol... Mian V... Grade TOPTnreaa 30.0 108.0 108.0 65.00 H-40 WELDED conoOCTOR; x.o-taeo Gsinp oescriplion SURFACE OD(NI to Urn 10314 9.952,302.8 Top (Itl(al Set Depin(I %t Depth"D1... WULen R -Gads Top ThreAd 2,216.1 45.50 K-55 IBTC Casing Description PRODUCTION OD fin) ID(In) 7 6.28 Tmp IXNB) 1H Depth (IIKB) Bel inn INo)... WIILen 11... Gretle Top Tnreatl 2]5 8,4636 6,928.8 26.00 K-55 BTC Tubing Strings SURFACE', 23.02.3020, GASUFT, 2653.2 1LNm1 Description 4.5 "HYD 503 COMPLETION a[ring Ma... 41/2 to lin) 3.96 Top (MUN 24.5 Sel oepm ln. 3,633.3 5e+ Depth (No)(..,W1(bin) 3,2383 12]5 Grade L-00 Top Cmnnection HYD 503 Completion Details GAS -Err al 'no(TV D) T•. me (nKD) liv1') Nominal Ilam Dec Com ID (Inl 24.5 24.5 O.W HANGER Hanger FMC Gen IV 71/16"A420- AM FJL BXP 3958 LOCATOR 309.0 SEA- Assn; 03823.7 PSR. 3.82-07 3,623.0 3,230.9 1 4467 1 LOCATOR Bakerlo0ator 3.980 3,623,7 3,231.4 44.65 EAL gSSV Baker seal assembly H off no-go) 3.980 PACKER, 3,3ws Tubing Dsscrlp+bn 40541 SCAB LINER Sbing Ma... 412 Si3.99 p (XKB) Bel Oepin (n., 5e[OeINnIND11... WIDb1111 Gade Top ConnMion 3,6247 3,951.3 3,468.4 12.60 L-80 BTC Completion Details NIPPLE,eros /PERF', GO 0.3B90 a� �^ t- Top (fNtB Top(ND) ) MIKE) Top Incl Nominal 1"1 Ilam Des Goth U,Rm 3,624.7 3,232.1 44.63 PBR Baker 412" x T' 2RH Liner Seting Sieve 4,190 cometh sgurm;aEb].DnKa ,3 TANDEM WEDGE a nae % 3,649.6 3,249.9 44.03 PACKER Baker412"xT'FPS3Packer ur I'S %IBTPin 3.920 3,6755 3,2686 43.14 INUTILE X Nipple HES 3.S T DTCM Ban 3.813 NON RETRIEVABLE LINER TOP PACKER: 3,]05.0 NIPPLE: a.las.e • 3,]]6.8 3,3425 42.93 WEDGE Northern Solutions 4-12"Ta than Wedge 3.958 3,795.8 3"Go.3 42.93 NIPPLE %Nipple 4112" x 3.813"BTCM BXP 3.813 4809.6 3,jr.o 43.10 TANDEM WEDGE NOMem Solutions 4-12"Te.... ,,dg 3.958 WHIPSTOCK: 3.8030 LINER; 3 AUS1I-1 i f 3,820.9 3,3]4.7 4330 NIPPLE XNi le 4-12'x3.813"BTCM BXP pp ,813 TANDEM WEDGE: 3.. X -LOCK ASSEMBLY: 30N 0 ` I� \ 3,8642 3,406.0 43.96 LANDIN COLLAR 41/2"Lantling Collar 3.830 NIPPLE: 3.8ID9 3,949.6 3,467.2 44.45 FLOAT BHOE I Float shoe BTCM 0.000 UNDIHG COLONS: 3,8303 Tubing Description TUBING LEFT IN HOLE Btring Ma... 10 (in) 3112 2.99 Top MRIN 4,8000 BH Depth M. 7,]39.2 Set Deptn IN01 (... 6,308.4 W+(IMq 9.20 Gade L Top Lonnedbn BTCABMOD FLOAT SHOE, OUR Completion Details LI8P;3.0d,5 Top(ND) Top RXIS MIKER I Topinml (1 I Idem Des Nominal Co. ID(In) 7,340.3 5,974.6 33.33 PER BAKER PER 250 JETCUT;4.003.0 Cemanl Plug; 6.603.0 RVa Prumcbnc am CemerK a.40MG CEM2 ENTRSTAINER:7.0.O C.nem Plus l 79tsnxe 7,3M.7 5,986.6 33.32 PACKER BAKER HB PACKER 2.890 7,498.9 6,107.4 3263BLAST JTS BLAST JOINTS(OAL=704) 3.000 7,720.1 Q2925 334) SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.985 7,720.6 6,292.9 33.43 PACKER BAKER FS- PPACKER 4.000 GAS LIFT; 7x94.3 77239 6,295.7 3344 SBE BAKER 8040 SEAL BOR 'EXTENSION 4000 CMT.QI 7,3+501,31]0 7,7329 6,303.2 )3.48 NIPPLE CAMCO D NIPPLE NO GO 2.]50 ],]384 6,307.8 3348 BOS CAMCO SHEAR OUT SUB, ELMD TTLea 772'tluring lPR Fon 3.016 051141200] veR, 7.3803 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) PACKERn.350.7 1348 LIFT: 7.N2.G00 ToH FF/W Top lnl<B) MKM Top incl ("1 Des Co. Run Data ID (in) 3,821.0 3,3]4.]43.30 X -LOCK SSE AMBLY Set% -Lack B Flow Fre Ilsembiv for Whipst0Dk. 19" 8152019 00 IAL. Gas LIFT, 7.01a 3,958.5 3,4735 44.48 CIBP eddge PlugPermanent Bl412m9 0.000 4,800.0 4,065.6 45.]0 JETIUT Jet Cut 51302019 O.00D IPERr. 7,40.0-[.x50- 7,2600 5,90].6 33.]0 CEM RETAINER WEATHERFORD 35" -CEMENT RETAINER WQ2019 .000 77180 6,290.) 3343 CIBP WEATHERFORD 312" CIBPOAL I' MAX 00275" 3012019 0.000 /PERF;ir W0 75gul perforatlone 8. Slots SM1OI GAS IEFT; 1.670.1 Top (dd{al Bal 1 Top(NDI Btm(NDI (flNBI (M(B) Den (snoKM Linked Zone Oita 1 Wm 3,619.0 3,826.0 3,2639 3,378.4 6/42019 12.0 PERE RE 7,315.0 7,317.0 5,8534 5,955.1 4IT2019 4.0 CMT SOZ 2" ubing Punch deg cieP; g7teD phasing 4spf. sEAILKER:7,79.1 PACKER;7,121,6 ],495 ],52 .0 5.0 6,104.1 6,129.3 C-3,113-03 825/1984 12.0 /PERF ],5400 7,563.0 6,1419 6,161.2131,1113-03 82571984 12.0 (PERF seE; A>9.a 7,]]2.0 7,8250 5,335.8 6,3]9.9 Ad, A-3,11393 812511984 12.0 /PERF Cement Squeezes NIPPIE; 7,732,8 sos 1,7364 BIm Top lNo) Top lnKB) IttHB) MRS) St. av") MKBI Oa Stan Data Com 7,261.5 7,7180 5,908.8 6,290.7 CEMENTPLUG 52412019 1688E OF 15.8PP LASSG EMEN B W RETAINER INTO C SAND SELECTIVE Q682.a 7,260.0 5,441-0 5,90].6 CEMENTPLUG 5242019 LA IN 5BBL$ 5. DEC CIA 0CEMENT ABOVERETAINER. CONTAMINATED DOWN TO ESTIMATED TOC OF 6682' IPERFv,n2e-TREZ 0-� 6,854.0 ],354.0 5,576.5 5,986.0 CEMENT PLUG 57242019 BBL OF 1 PPG CLASS EM CIRCULATED UP IA THRU TUBING PUNCHES 3,669.0 3,828.0 3,2639 3,3714 EMENT SQUEEZE 6152019 queezetl in PP cass Cement wiN Archer Stronghold Barricade too. PRODUCTION, Y7.Ba.,PMS� KUP INA) WELLNAME 1G-03 WELLBORE 113-03 Cmoci;Fhil6ps-' Alaska, Inc. 1GO3,IWKfAIe II:x:34 AM Mandrel Inserts V —I wh—UG RI st as N T1RK0)0j Pa;'ize T0.05 T -'(--R Mak¢ MI ODlin) $Bry Tyles ryes )e^ qun Oats Lam 1 2,663.2 2,510.6 Camm 1R12 1 INJ GLV BK 0.166 1,41]0 ]252019 2 3,596.3 3,212.0 CamcO ." 1 INJ OV BK 0313 0.0 ]252019 Notes: General & Safety Eoa Daie AnnMailon NOTE: E -LINE FOUND CSAND LEAK @ ]5]9519 r4124i2003 N :FIAPER BROK N NTRS V --MUST MAINTAIN PSI ON NTROL LINEWH NO SLEEVEISINSTALLED 019 NOTE: View S[M1emabc w/Alaska SCM1ematl[10.0 SURFACE: ffi02,aR8� CAS LIFT; 2EG02 GAB OFT', SEGS LOCATOR;3,MO BEALASBY: C-1 PER; B,BNT PACKER; 38035 �r NIPPLE: 3.W5.8 l IPERF', SJOES) L.L. 66\ / I CII-WAR—:3a86.9N'GB I TANDEM WEDGE: SM8 NON RETRIEVABLE LINER TOPPACKER;3T850 NIPPLE, SMS— )858 WHIPSTOCK WHIPSTOCK, 3865.0 LINER, 3,]31.6119W,0 !� TANDEM WEDGE: SEES r— %- LOCK ASSEMBLY; 3631A HIPPLE:3..E VWOING COLLAR: 3.8&.] FLOAT SHOE, 3605.8 CI.P, 3,659.8 JET CUT', A,M0 .. Pke: B,BB20 M(B PPAI Geig Cem.Ml G..DRKa CEMENT RETAINER, T,AI.O Cenwnl Plug; 7,M15KKa GLB.1,1,CFA3 CMTSW;i,3156].31]O PEC7,340.3 PACKER:]304.] GAS LIFT, 7 3820 GAS LIFT; 7,481S PERP>4CEO-7605 (PERF: T.980.OT,R1.0� GAS LIFT; ]8]01 CIBP;].]180 BEOLAEGIT.TA.1 PACKER; T,. EI T,TZ.B NIPPLE: 7,T329 BOS;T,T3&4 PERF 7,P2.O7,925B. PRODUCTION, 27 SJLOe38� KUP PROD WELLNAME 1G-03 WELLBORE 1G-103 i aiocorrnwps ml nunuua03 Max Angle & MD TD 1" Aiaska,lllc. Flele Name W¢II,-Is APgLIWI Wellbore Sirens Icl ('I PIP(ryKaj Anl Blm (flKBI 11.960.0 SSSVet Militant Deb Annahxon Ene Orb KB-fiM (p Lest W0: 33.98 Rig Releaze pale 10/811982 1G-rro,taar201a n:ae:zsau Last Tag .anina serracpabwl HANGER: 20.5 ������������� Annoleaon LastTag:1G-183 Depth PP, no... .,I.. Lev,ed By �Gnndt Last Rev Reason Ann¢hnrn Rev CTO SIDETRACK Ene Deb wmbrm 91302019 1G-103 emelum By jennalt ng S Casing t86gs Call,, 0.¢cripEon --01) ohs) LINER 2]/8 2.44 TIP(flNBI s¢t Geym (nxa) Del Oepen(rvoL.. wnL¢n Q.. Grrea 3,]906 11,960.0 fi50 L -BO roP Tnreae H533 Liner Details Top YETO ToPpVDLftKIV ToPmcq') 3,790.6 Ibmpea Com SBR Deployment seel with 6' seal bore xominalm Ont 2.90 coxoucioR; 30.o-ff9.0 3]9].6 IA BNK Tl12%!L ff, L-80, wedge aH51 (/ Solid Liner 6 nes entered as bol lengeh) 2.990 3,966.5 C VER- X03 REDUCING -12"-2-0IB" 2391 3,987.2 BLANK 2-0/8", 6.5N, L-80, H533, Blank line' (Cover faults) 2441 SORPADB4 OZA2. S� 6,525.0 5iTPL-UY—MrN7 Dissolvable bull nose - note,L A.44'witlt .48T SLEEVE swallowed io DCLL 2375 8,526It BLANK 2-]IB",.Sp, L-80, H133, Blank liner- cover $.C,.n tldllad out of zone) 2.441 GAS LIFT. 2a W.2 7,529.1 BLANK 2-]/8", 6.59,L-00, H533, Blank liner 2.41 8,640.1 BLANK 2-7/8", 6.5N, L-80, H533, Blank liner 2.4,1 9,745.5 BLANK 2 -)IB", 65#, L-80, H533, an liner 2,441 GAS LIFT ;3maa 9,8355 DEPLOYMENT OR Permanent OCLL SLEEVE 2.375 LOCATOR; 3,823.0 10,848] BLANK 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, 0sh, etc.) DEAL Aesv: s.M PER. 3,82/] Top(i1Ke) 3,785.0 TIP (ftKGP (nKB) TOP Ind rI De. NON RETRIEVABLE Com Baker 45 Flo-GuaN Packer L-811 w/Nolihere Solutions PTSA. DAL 9.84' Max OD 3.70" Run Data 9112/2019 In (in) 2.310 LINER TOP PACKER; 360.96 PACKER 3805.0 WHIPSTOCK - I "Northern Solutions Inner Wedge, SE10 Dg HS, w/ We PIP tags. 6/6/2019 1.000 Perforations & Slots NIPPLE: 3.6]5.5 i IPEFeaIs. .0$8280 GmeN Squxx.: 36W.Onl(0 � Top(TVD)Bim (IND) Top690.. Bim (flKBI n(KB) (flKBI Dens IJnkeE Zone pab (SnobM 6698.9 sszs.6 TSCo. snrz0ls stors TANDEM WEDGE. 3.]]ee—i`¢ ],0]90 ],529.0 9012019 SLOTS a NON NET WEMBLE DNER TOP PACKER: 3.705D a 7,623.0 8,640.0 W12019 SLOTS 8,]30.0 9,7460 WQ019 SLOTS 9,837.0 7849.0 90/2019 SLOTS 10,9370 11,959.0 992019 SLOTS NIPPLE; 3 M —y Notes: General & Safety j End Data Annan 9!302019 NOTE: View Schematic w/ Alaska Schematid 0.0 PRODOGTION; 27.5IL,438 S WRIrange C 3 de 0 J DLOT$ 5,6YJ.09,S250��IFL SLOTS', 1,0]fi.0.],5SPO IIir I SLOTS, 7,BY}p8,dead J SLOTS, B, 7XGL9708.0� j SLOTS: EAST bIDENS .0 SLOTS', 10,937611,9&90 I I LINER; 3.MG-1 r96e,0� 1G-03 WHIPSTOCK DTTM JOBTYP SUMMARYOPS START 8/5/19 ANN BRUSHED X -NIPPLES @ 3676', 3796', 3821' RKB & TAGGED @ 3846' COMM RKB. DRIFTED 3.79" & 3.68" x 18.5' DMY WHIPSTOCK TO 3846' RKB. SET 3.81" X -LOCK W/ FLOW THRU SUB @ 3821' RKB & CONFIRMED W/ CHECK SET. JOB COMPLETE & READY FOR ELINE (SET INNER WEDGE). 8/6/19 ANN SET WEDGE ON X -LOCK @ 3821', TOP OF WEDGE @ 3805.1', WEDGE COMM ORIENTATION = 1° LOHS, CCL TO TOP OF WEDGE = 14.1', CCL STOP DEPTH = 3791'. ATFER FIRING UNABLE TO RELEASE FROM WEDGE, UNABLE TO GET FREE. TOOLS LEFT DOWN HOLE. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1 G-03 Permit to Drill Number: 182-149 Sundry Number: 319-327 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.009c c. o las ka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jessie L. Chmielowski Commissioner DATED this IL day of July, 2019. RBMiNJUL 12 204 STATE OF ALASKA JUL 10 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPL ION REPORT ADSC 1 a. Well Status: oil E] Gas❑ SPLUG❑ Other ❑ Abandoned Mn/ Suspended 0 20AAC 25.105 .V/�. 20AAC 25.110 GINJ ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: ib. Well Class: Development ❑ Exploratory ❑ Service E] Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 6/10/2019 14. Permit to Drill Number / Sundry: 182-149/318-§§fi' , 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 9/20/1982 15. API Number: 50-029-20824-00-00 4a. Location of Well (Governmental Section): Surface: 1129' FSL, 264' FWL, Sec 29, T12N, R10E, UM Top of Productive Interval: 1102' FSL, 3517' FEL, Sec 30, T12N, R10E, UM Total Depth: 1335' FSL, 3981' FEL, Sec 30, T12N, R10E, UM 8. Date TO Reached: 10/1/1982 16. Well Na/me and Number: KRU V -0-5 17. Field / Pool(s)-,, Kuparuk River Field , - kOil Pool P ;: 9. Ref Elevations: KB:92 GL BF: 10. Plug Back Depth MD/TVD: 3664/3406 18. Property Designation: ADL 25640 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540037 y- 5981775 Zone- 4 TPI: x- 536256 y- 5981729 Zone- 4 Total Depth: x- 535790 y- 5981959 Zone- 4 11. Total Depth MD/TVD: 8489/6951 19. DNR Approval Number: ALK 2571 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MDfIVD: 1500/1493 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑� Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary CCL/CBL 23. CASING, LINER AND CEMENTING RECORD AMOUNT WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 30 108 30 108 24 325 sx AS II 10314 45.5 K-55 29 2303 29 2216 13112 1400 sx AS III, 250 sx AS 1 7 26 K-55 27 8464 27 6929 83/4 900 sx Class G, 250 sx AS 1 41/2 12.6 L-80 3625 3951 3232 3468 N/A 61sx 15.8ppg Class G 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 41V PERFORATION PLUGGED @: S� Q 1,1� 3669.3626 MD and 3264-3378 TVD .... 6/5/201 G{I (.t\'l` DATE WV �y 'V 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDrrVD) 31/2 7739 73545/5987 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3669-3826 143 bbls 15.8ppg Class G 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 VT1, 10/A3//CONTINUED ON PAGE 2 Submit ORIGINIAL only /Of 1/0-0/7 RBDMS JUL 1 12019 CJ( 28. CORE DATA Conventional Core(s): Yes ❑ No 21 • Sidewall Cores: Yes ❑ No ❑� ' If Yes, list formations and intervals cored (MDfI VD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q ` If yes, list intervals and formations tested, briefly summarizing test results. Permafrost- Top Surface Surface Permafrost - Base 1500 1493 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval NIA NIA information, including reports, per 20 AAC 25.071. Formation @ TPI - Formation at total depth: NIA 31. List of Attachments: Daily Operations Summary, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, oaleontolooical report production orwell test results,AAC 25 070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Ty Senden Contact Name: James Hayes Authorized Ttle. Wells Su ervisor Contact Email: James.C.Ha es co .com Authorized Contact Phone: 265-6927 Signature: Date: 7 INSTRUCTIONS General: This form d the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 1 07 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only KUP INJ WELLNAME 1G-03 WELLBORE 1G-03 9QIFK Well Attributes Max Angle&MD TD ConoeoPh(lhpsaI-11-IIAPOUW WellEorea tus Ilncl ('I MD flKB) ptBIm6 HB) Alaska, IncUPARUK RIVER UNIT 500292082d00 IN.I BNJ RNnn nn Repo. 1 Gd3, 8Rarel 8CSM AM I Last Tag -we evennew no ) AnnoteEon Depth ROCIS I End Date We11Mre taste. By ............................ Nangp;2as ............. ............... Last Tag: RKB Q695.0 5/302019 1G-03 famaj erv: Sae Last Rev Reason Annotation End Data Wellbore Last Mad By Rev Reason; Tag, Jet Cut, Hold Open Sleeve, BEV. 51302019 1G-03 tamaj Casing Strings canine Dascription OG (in) l0 (in) Top IRKS) set De Pan RKER SetDeptn(TVO-WULen U.,Iminea Top Thread CONDUCTOR 16 1525 30.0 108.0 108.0 65.00 H-40 WELDED Owing DescrlpWn OD(in) IO on) Top(ung net part. Soar) set norm(TVD)... Vftnam(I 1. nn Top TMW SURFACE 10314 995 29.0 2,3028 2,2161 4550 K-55 BTC Casing OsscNptlan ICU (in) ID pn) Top MKB) eat Oent'lom) Set DepMnvD)... WOten IT Gentle Top Th -O PRODUCTION 7 628 21.5 8,463.8 6928.8 26.00 K-55 BTC CONDUCTOR I MJ Nb.0 Tubing Strings SURFACE;R0.2,3rR.B� Tubing Oaaanpllon stnnB Ma._ ON HYD503 4112 (,'cur"CtI On m (In 3.96 T. ("I" 24.5 set Depen M.. 3,633.3 set Oepm (TVD) (... 3,238.3 WtQTom 1215 Ionian L-80 TOP UPS... an HYD 503 Completion Details MVMnI: 2,Ma2 rop(Too) Topincl all Tep(-No) MKS) (°) IN. Des Coen ID (in) 24.5 24.5 007 Hanger Hanger FMC Gen IV71116"x0la" VAM FJL B%P 3.958 Aaaat3gii 3,623.0 3,2309 44.67 Locator Baker locator 3,980 mWmn 3 S0 3,623.7 3,231.4 44.65 Seal Assembly Baker seal assembly IT ox nogo) 3.980 SP4Ayynyp36RT PBR LPnklM anre Tubing DeaaipEon U.S. M. ID(In) Top MKn) et (R. Set DelNn jNO)(... Wt(Idfl) Orad¢ Tap Cannecxon 4,5" Scab Liner 412 399 3,624] 3,951.3 3,4684 12.60 L-80 BTC m-innalit 9.M.7 Completion Details FP 53 PacXen a618.b Top(WI I Topincl Nominal Top phot (fiK91 fl Hem Oes Cam to (in) 3,6241 3232.1 44.63 PER (Polished Baker4112"x7" 2RH Liner Sening Sieve 4.190 Bore loop. -x'. sa/as wERF; a.eae O3aR0 c.W.m SRuxre: saig.otne�-C renwW wasgllffie ve Llan 3.ei47ese Receptacle) 3,649.5 3,2499 44.03 FP S3 Packer Baker 412"x7" FP S3 Packer VT Pin x IBT Pin 3.920 3675.5 3,2686 43.74 NMPIe-X XNipple RES 3813"BTCM B.P 3.813 3]]6.8 3,3425 42.93 Tantlem Wedge Northern Solutions 4-112" Tandem Wedge 3.958 MpPla-x;;res.¢ Spi 3,795.8 3,356.3 42.93 Nipple - X %Nipple 0.112"x3.813"ETON BxP 3.813 X' + mines. We]pe:3B09.6 1�. 3,809.6 3,366.5 43.10 Tandem Wedge Nortbem Solutons 4-1Q" Tandem Wedge 3.958 3820.9 3,3]4.] 43.30 Nipple -X XNipple 4-12"x3813"BTCM BxP 3813 p oei x;3,M. \' 3,8642 3,4080 43.96 Landing Collar 1412"Lending Collar 3930 3,949.6 3,461.21 P'T'm 1 Float Shoe Flootshoe BTCM 0.000 Lading Can, 3%4.2 .rel sn.., am.. Tubing Deseripeen String MP. -ID (m) T.CRININ 50Deptn(SLIEST Depub DVO) I...Wt Lord) GRtle Topconnece, Tubing Tubing left in hale 312 299 4,8000 ],]392 6,3084 920 J55 BTCABMOD Details an" Pas - Pannon, t a"�E Top (IVOI Top led Nominal 'P ('No) MKB) C) Item Cas Co. 10(1.1 Jnac4.eboo 1,340.3 5,974.6 33.33 PBR BAKER PBR 4,260 cwnam P.B; a,ae2olxa Trial Casing C.-.'. 1,35 7 5,886.6 3332 PACKER BAKER HB PACKER 2.890 "5"N" Ceme. Ratione;],IDJO 7,498.9 6,1074 32.83 BLAST JTS DUST JOINTS (OAL=70.4') 3.000 cement Pep: 491a 7,720.1 6,2925 33.43 REAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.985 1,120.6 6,292.9 33.43 PACKER BAKER FB -1 PACKER 4.000 CAS uFr:7D4.a 1,723.9 6,295.7 33.44 SBE BAKER 8p40 SEAL BORE EXTENSION 4.000 con SOc 731SO7,31ZO ],]329 6,3032 33.46 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,7384 6,3078 33.48 505 CAMC HEAR OUT SUB, ELMO TTL 77 'tluring PROF on 3015 PBR; 7a40 3 1 1 1 10511412007 11 Paauamcvintanenn Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.I 7"s0 We PACKER: 7354.1 Top INO) Topincl ISie(B) ("i I°) Dea Cam Run Data ID (in) 24.5 24.5 007 BPV Type H BEV 611012019 0.000 INJECOON; 73ce 3958.5 3,4735 4448 Britlge Plug- CIBP 6142019 0,000 Permanem INJECTION; ]V1.B 4, 00. 4,065.6 4570 Jet Cut Jet Cut 5)302019 0.000 7,260.0 5,907.6 33]0 Gement WEATHERFORD 35"CEMENT RETAINER 51242019 0.000 IPENF;7°496.0,7,050� Retainer 7,718.0 6,2991 33.43 CIBP WEATHERFORD 312" CIBP GAL IMAX OD 275" 302019 0000 Perforations & Slots (PERF: 7EM. S-7,583.0 Snot Den rather.) BtmKB Top BIW ITVD) (an..M ) 'fl .) We) LinkM Zone Dana ) Type Can INJECTION; 7,510.1 3,669.0 3,826.0 3,2639 3,378.4 6/42019 120 IPERF 1,315.0 1,3170 5,9534 5,955.1 1912018 4.0 CMT SGZ 2'TuBing Punch tleg phasing 4spt. CMP:71Nao 7,495.0 7,525.0 6,104.1 8,129.3 G3, iG-03 82511984 12.0 IPERE .UL ASSY, 7 M 11 7,5400 ),563.0 6,141.9 6,1612 7-1, 1G-03 82511980 12.0 (PERF PACKER; 7,CC. 7,772.0 7,8250 6,3359 7,3799 74,A -3,1G-03 81251984 12.0 IPERE SBE; 7,Cd. Cement Squeezes Top U D) Buri Top(MIS Btm MKB) RULE) MKB) Das sdn Oae Co. xIPPLB;;jus 7,2615 1,118.0 5,908.8 51290.7 Cement Plug 5124/2019 16 BBLS OF1 P IHSS G CEMENT BELOW RETAINER INTO C SAND SELECTIVE sos; 7,7 A 7,355.0 7,720.0 5,986.9 6,292.4 Fmdlodion 72412019 Casing Cement 6,682.0 1,260.0 5,4414 5,907.6 Cement Plug 51421119 LAV DIN 5B BLS 15.8 PPG LASS M N ABOVE RETAINER. CONTAMINATED DOWN TO ESTIMATED TOC OF 6682' wERF.7.mw,e2s.o- 6,854.0 ],354.0 5,5765 5,966.0 Cement Plug 9242O18 14 BB F15.8 PPG LAS GC M N CIRCULATED UP IA THEM TUBING PUNCHES 3,669.0 3,826.0 3,263.9 3,378.4 Cement 6152019 Squenced in 15,8 PPG Cass cement WON Archer Squeeze Stronghold Barricade No. PRODUCTIONI37Se.4l KUP INJ WELLNAME 1G-03 WELLBORE 113-03 ConocoPhfllips Alaska. fr1c. I I 1.20, flp3p0isER..I AM Mandrel Inserts v.rdsimw.ax l.cmll S1 mon IT ......._.... Nsam; ............... M.S BPV; ¢i.5 N TopIVO)OI halve Lekh Patl Slze Run Top WE Mahe MWeI ODlinl dery Type Type (In) (psp Run Oab Com 2,6632 2,510.8 amco KBG-2 1 DMV BK fi2S2019 2 3,596.3 3,212.0 CamcO KBG2 1 SOV DGK-2 61&2919 INOV shear Id Notes: General & Safety Em DareARnohuon 41242003 NOTE. E -LINE F0UND CSAND LEAK V TS)9' CONDUCTOR, 3e.a-103.0 911542010 NOTE: View Schematic W Alaska Schema4c9.0 318/2019 DJOHOIJEN ONTR55 V ->MUST MAINTAIN 5000 PSI ONCO LLNEWHEN NO JNLUE:FLAPDN SLEEVE IS INSTALLED SURFACE,MOG.a32a. MaMnl: 2.0632 Manonal 35633 aealpwgnNy', 3B23.7 PER (Pa "ape N—Ap a'et; 3,ata1 FP 53... 3,6A9.5 Nyle -X',30]55 IPER03,66963,8MO CenenlaW�era:3�.0 XI[a Y TeMam We'9e', 3, 718.6 * LFerCp 3,RaTraa NIpGp e 3,]958 I.M., 3PA9.8 1• NWW%:3820.0 Anam Caller; 3aG.2 FIw1aIm;3,9496 Bn'a. PNp-'OnaamK 30565 J,n CA4,e0oo CNnon Pep: 3'02.0 m(E Pro MICaslrq CvrmS E,851.0 KKB Ca. R.. . ].$800 C,n. PNp', T,2'1.a. GAS U".],Ra.3 CMT90[7,3150U312.Y PBI: I'M .3 ...en cawp cemem 7,36S.O'HB PACKER,73S47 INJECTION', 7,3$0 INJECTION. ],W1A (PERF; 7,GSO-1.T25O� IPERF:].Stl.Oi,5St0� INJECTION; 7,6101 CIBP, T, 718.0— sEnLAaar:7..1 PACKER, TMO8 58E: 7Ma. NIPPLE: T, 232.9 'C': 7,23B.9 IPERF: 2,72 P] UDEIG PRODUCTION', 22.3E.4a3n� Operations Summary (with Timelog Depths) 1 G-03 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur (hr)Phase Op Cotle Acimty Cotle Time P-T-X Operator Start Depth (ftKB) End Depth(ftKB) 5/31/2019 6/1/2019 18.00 MIRU MOVE MOB P Move Nabors 7ES F/ 1R-03 T/ 1G-03 06:00 00:00 Sub Base Pits 6/1/2019 6/1/2019 6.00 MIRU MOVE MOB P Continue Moving Shop and office to 00:00 06:00 1 G-03 6/1/2019 6/1/2019 3.00 MIRU MOVE RURD P Continue rigging up. Secure burming. 06:00 09:00 Install elevators, secure rig floor. Fill mud pits with 9.0 ppg brine. 6/1/2019 6/1/2019 0.50 MIRU WELCTL MPSP P Pull Cameron BPV No pressure 09:00 09:30 observed on either IA or OA. 6/1/2019 6/1/2019 2.00 MIRU WELCTL CIRC P Displace 116 bbls of diesel out of 09:30 11:30 tubing and IA with 9.0 ppg brine, pumping down tubing and taking returns up the IA to the flowback tank. Approximately 184 bbls pumped to displace well, circulated until good 9.0 ppg brine observed on surface. 6/1/2019 6/1/2019 1.00 MIRU WELCTL MPSP P Install Cameron BPV Test BPV 11:30 12:30 punping through IAto 1000 psi for 10 minutes. Test good. 6/1/2019 6/1/2019 2.50 MIRU WHDBOP NUND P Nipple down production tree. Inspect 12:30 15:00 hanger threads, threads good. Set test dart. 6/1/2019 6/1/2019 4.00 MIRU WHDBOP NUND P Nipple up BOP, DSA and install 15:00 19:00 secondary IA valve. 6/1/2019 6/l/2019 1.50 MIRU WHDBOP ROPE P R/U testing equipment w/ 3 1/2" Test 19:00 20:30 Joint and 4 1/2" Test Joint Attempy to M/U test joint Had issues call Cameron. 6/1/2019 6/2/2019 3.50 MIRU WHDBOP ROPE P Attempt to test BOP against blind 20:30 0000 rams, leadked on low test. Continue testing choke manifold valves 250/3000 PSI (AOGCC witness is waived by Jeff Jones) by E-Mail 6/2/2019 6/2/2019 4.00 MIRU WHDBOP BOPE P Continue testing bop All Choke 00:00 04:00 Manifold and pipe rams,annular 250/3000 psi Blind rams failed Due to top seals.draw down tested All good W/ 3 1/2" Test joint 6/2/2019 6/2/2019 3.00 MIRU WHDBOP RGRP T Lay down 3-1/2" test joint. Due to 04:00 0700 Blind rams seals leaking by and lower pipe Rams hydralic door hang leaking Repair and retest blind rams and hydralic seal. 6/2/2019 6/2/2019 1.50 MIRU WHDBOP BOPE T Attempt to test blind rams several 07:00 08:30 times, continually leaking out low pressure test of 250 psi. Trouble shoot surface test equipment, surface test equipment good. Bleed air out of system and re-test. Unsuccessful test. 6/2/2019 6/2/2019 3.50 MIRU WHDBOP BOPE T Pick up 4-1/2" test joint and fill with 08:30 12:00 water, purge air. Attempt to test lower pipe rams, leaking at low pressure test. Observed leaking test maniold. Repair manifold. Attempt to test again (2x's) and observed connection on test joint leaking both times. Tighten connection and re-test. Able to get successful test on lower/upper pipe rams 250/low for 5 minutes and 3000/high for 5 minutes. Test annular to 250/low 5 minutes and 2500/high for 5 minutes. Good test. Page 116 ReportPrinted: 6/28/2019 Operations Summary (with Timelog Depths) Ain 1G-03 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End T. Dur (hr) Phase Op Code Agrviry Cotle Time P -T -X Operation Staff Depth (Wl) End Depth(ftKB) 6/2/2019 6/2/2019 4.00 1 MIRU WHDBOP RGRP T Empty BOP stack and open blind ram 12:00 16:00 cavities. Inspect blind rams and wear plate in ram cavity. Observed wear on wear plate in blind ram cavity. Change out wear plate, close blind doors and re -torque. Test blind Rams T/ 250-3000PSI All good 6/2/2019 6/2/2019 2.00 MIRU WHDBOP BOPE P RID testequipment amd Pulled Test 16:00 18:00 dirt L/D same R/U landing joint and RIH and BOLDS 6/2/2019 6/2/2019 1.50 COMPZN RPCOMP THGR P P/U on String unset hanger PUW 65k 18:00 19:30 Pulled hanger to Floor and L/D same R/U 3 1/2" Tubing Euipment 6/2/2019 6/3/2019 4.50 COMPZN RPCOMP PULL P POOH LID 3 1/2" Brd Completion 19:30 00:00 -3 string 6/3/2019 6/3/2019 50 COMPZN RPCOMP PULL P Continue POOH L/D 3 1/2" 8rd 00:00 03:30 Completion string Tot L/D 152 Full joints, joint 153 cut joinl,l SSSV and Hanger w/ Pup joint .Clean up Floor RID Tubing Equipment Hold PJSM 6/3/2019 6/3/2019 2.00 PROD? RPCOMP FLOG P R/U SLB E -line W/ GR -CCL w/ CIBP 03:30 05:30 #1 RIH 6/3/2019 6/3/2019 2.50 PROD1 RPCOMP ELOG P RIH with Weatherford Big Boy 1 KK 7" 05:30 08:00 CIBP on E -line. Correlate to previous logged markers via GR at 3170', 3233', and 3329'. Make 6' correction and set 7" CIBP. CCL stop depth 3954'.3', set depth 3965' to mid element (CCL offset 107), Top of CIBP 3964'. Observed approximately 365 lbs of tension lost when plug set. Tag plug and confirm set. POOH with E -line. 6/3/2019 6/3/2019 1.50 PROD1 TPGOMP P Break down tools and layout. 08:00 09:30 Pressure test CIBP at 3965'to 1500 psi for 10 mins. Good test. Pick up and make up E -line tools and 2nd 7" CIBP. 6/3/2019 6/3/2019 1.50 PROD1 RPCOMP ELOG P RIH with Weatherford Big Boy 1 O 7" 09:30 11:00 CIBP on E -line. Correlate to previous logged markers via GR at 3170', 3233', and 3329'. Make 0.5' correction and set 7" CIBP. CCL stop depth 3848.7', set depth 3859' to mid element (CCL offset 107), Top of CIBP 3858'. Observed approximately f 360 lbs of tension lost when plug set. Tag plug and confirm set. POOH with E -line. 6/3/2019 6/3/2019 1.00 PROD1 RPCOMP NUND P Drain BOP stack and verify no 11:00 1200 pressure on OA. No pressure on OA. Nipple down BOP stack, and pull riser. 6/3/2019 6/3/2019 6.00 PR0D1 RPCOMP NUND P Nipple down old McEvoy Gen 3 12:00 18:00 tubbing spool and Nipple up new 7- 1/16" x 11" C -bawl tubing spool. Energize secondary seal with packing and test. Test void to 250 psi low for 5 mins and 3000 psi high for 5 mins. Test goad. N/U BOPE 6/3/2019 6/3/2019 1.00 PROD1 RPCOMP BOPE P Close blind rams and Test 7"x13 5/8" 18:00 19:00 Flange on the BOP Stack T/ 250/3000 PSI 5 mins each Low/High All good Page 2/6 Report Printed: 6/28/2019 Operations Summary (with Timelog Depths) 1 G-03 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Tame End Tune Dur(hr) Phase Op Code Acnviry Code Tuna P -T -X Operation Start Depth (flKB) End Depth(ftKB) 6/3/2019 6/4/2019 5.00 PR0D1 RPCOMP PULD P PJSM w/ Crew P/U 3 1/2" HT 38 work 19:00 00:00 String U 2000' Due to the right elevators ship over from BOT for Halliburton lifting sub to P/U the guns 6/4/2019 6/4/2019 3.00 PROD1 RPCOMP PULD P Continue P/U 3 1/2" HT 38 work- 2,000.0 0.0 00:00 03:00 String U 3600' POOH and Stand Back in derrick 3 1/2" D.P 6/4/2019 6/4/2019 1.50 PROD? RPCOMP BHAH P M/U and P/U Halliburton 5 3/4" 0.0 160.0 03:00 04:30 perforating guns Tot 160' XO D.P w/ 7" casing scraper 6/4/2019 6/4/2019 2.50 PROD1 RPCOMP TRIP P RIH F/ Derrick T/3800' 160.0 3,800.0 04:30 07:00 6/4/2019 6/4/2019 3.00 PROD1 PERF PERF P Tag up @ 3856' DPM and Space out 3,800.0 3,856.0 07:00 10:00 place bottom shot @ 3829' top shot @ 3669' Circ @ 2 bbls w/ 150 psi Through -Choke manifold and drop ball and Hold PJSM , Pres up or. Guns and Fre off guns w/ 1850 psi No Flow and No Pres CBU @ 3 bbls w/ 175 PSI open up Well bore and Monitor well 30 mins no flow Blow Down lines 6/4/2019 6/4/2019 2.00 PROD1 RPCOMP TRIP P POOH and Stand Back 3 1/2" Ht 38 3,856.0 179.0 10:00 1200 Work- string T/179' 6/4/2019 6/4/2019 0.50 PROD? RPCOMP SFTY P PJSM with Halliburton on laying down 179.0 179.0 12:00 1230 pert guns 6/4/2019 6/4/2019 1.50 PROD1 RPCOMP BHAH P L/D casing scraper and pert guns. All 179.0 0.0 12:30 14:00 guns fired. 6/4/2019 6/4/2019 0.50 PROD1 RPCOMP BHAH P M/U Archer cup tool 0.0 17.0 14:00 14:30 6/4/2019 6/4/2019 1.50 PROD1 RPCOMP TRIP P RIH F/ Derrick T/3699' 17.0 3,669.0 14:30 16:00 6/4/2019 6/4/2019 3.50 PROD1 RPCOMP DHEQ P Set Archer cup Tool @ 3699' and Test 3,669.0 16:00 1930 1500 PSI Bleed down 1000 Psi in 5 in Several Attempt @ 3551', working cup Up and down No go POOH t/ 2500' Attempt to Test cup pres up to 2000 lost 30 psi in 8 mins Still leaking by very slow RIH !/3000' retest leaking by @ 1500 psi U 900 psi in 5 mins. Decision was made POOH Check Archer cup and P/U Archer spare 6/4/2019 6/4/2019 3.00 PROD1 RPCOMP TRIP P POOH Standing Back HT 38 3 1/2" 19:30 2230 Work -String Checking every Connection 6/4/2019 6/4/2019 1.00 PROD1 RPCOMP BHAH P C/OArcher oil tool It Seems to be no 22:30 2330 damage from the external side of the tool 6/4/2019 6/5/2019 0.50 PROD1 RPCOMP TRIP P M/U The Archer spare wash cup tool 23:30 00:00 and RIH T/500' Test Cup Tool 1200 PSI lost 20 PSI 5 mins All good 6/5/2019 6/5/2019 3.00 PROD1 RPCOMP TRIP P Continue RIH W/Archer oil tool f/ 00:00 03:00 derrick 3 1/2" D.P t/ 3636' Page 3/6 Report Printed: 6/28/2019 Operations Summary (with Timelog Depths) IG -03 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our (hr) Phase Op Cede Activity Code Time P -T -x Operation Stan Depth (flKB) End Depth(flKB) 6/5/2019 6/5/2019 5.50 PROD1 RPCOMP CIRC P PUW 87K SOW 74K test T/1000 PSI 03:00 08:30 good and establish circ parameters @ 7 BBLs min w/1000 psi @ 10 bbls min w/1500 psi. Wash perforations F/36667/ 3826' @ 9 BPM pressure ranging from 1300-1400 PSI. Sand returns at shaker throughout wash down. Decrease in string weight @ 3826' cup depth indicating tool exited per's at expected depth. Decision was made to wash perts on up stroke. Wash F/3826' T/3666' with diminished cutting returns at shaker. 6/5/2019 6/5/2019 1.50 PROD1 RPCOMP CIRC P Pull cups up above top parts and 08:30 10:00 shear out solid seat at 2970 PSI. RIH past bottom of parts with end of tool @ 3838' circulate bottoms up X 1.5 @ 100 RPM, 9 BPM 1570 PSI. 6/5/2019 6/5/2019 1.00 PRODI RPCOMP RURD P R/U SLB cement truck and rig floor 10:00 11:00 circulating equipment. 6/5/2019 6/5/2019 0.50 PROD1 RPCOMP SFTy P PJSM with rig crew, SLB cementers 11:00 11:30 and Archer reps. on cement job 6/5/2019 6/5/2019 0.75 PROD1 RPCOMP CMNT P Pump and pull, 5 Bbls H2O, Pressure 11:30 12:15 test lines to 4000 PSI. Pump 43.6 Bbls G -blend @ 15.8 PPG cement, followed by 5 Bbls H2O, and 12.1 Bbls of 9.0 PPG brine. Cement in place at 12:15 PM. Shear 1.375" ball seat. 6/5/2019 6/5/2019 0.75 PRODi RPCOMP TRIP P POOH 7 stands T/3045' 12:15 13:00 6/5/2019 6/5/2019 0.50 PROD1 RPCOMP CIRC P Circ bottoms up X2 @ 10 BPM, 1545 13:00 13:30 1 PSI. Drop Nerf pipe wiper and circulate surface to bit. 6/5/2019 6/5/2019 2.00 PROD1 RPCOMP TRIP P POOH F/3045' T/17' racking work 13:30 15:30 string back in the derrick. 6/5/2019 6/5/2019 0.50 PROD1 RPCOMP BHAH P LID Archer Barricade tool. Wash tool 15:30 1600 off on rig floor. 6/5/2019 6/5/2019 2.50 PROD1 RPCOMP CLEN P Service Rig and PIU BHA #4 and strip 16:00 18:30 same 6/5/2019 6/5/2019 1.50 PRODI RPCOMP BHAH P M/U BAH #4 and RIH 500' break circ 18:30 20:00 All good 6/5/2019 6/5/2019 2.00 PROD1 RPCOMP TRIP P Continue RIH T/ 2858' 20:00 22:00 6/5/2019 6/6/2019 2.00 PROD1 RPCOMP SLPC P Break Circulating,cut and Slip drilling 22:00 0000 line and Clean up Rig 6/6/2019 6/7/2019 24.00 PROD? RPCOMP WOC P Continue WOC And Service Rig Hold 00:00 00:00 Evacuation Drill with crew response time 2. mins Inspections ,fire ext,Air pack,eye wash stations ,wire rope slings and SRL's, service pipe skate, repair bine tank transfer line, air compressor room door, paint long bails. 6/7/2019 6/7/2019 4.00 PROD1 RPCOMP WOC P Continue WOC. F/500 PSI Comp. 00:00 0400 Clean Rig Floor and drawworks ,IR, C/O Heater cores in pit complex and painting in pipe shed and pump room , CBU @ 3 bbls w/ 180 psi All good 6/7/2019 6/7/2019 13.50 PROD? RPCOMP DRLG P RIH tag up @ 3070" and Start 04:00 17:30 Washing Down (/3070 U 3085' Frim Cement F/ 3085' U 3616' WOB 8-10K PUW 80K SOW 65K Rot 75K @ 6 BBIs min w/ 611 PSI RPM 80 Tq 2900 Ib Page 416 ReportPrinted: 6/28/2019 Operations Summary (with Timelog Depths) 1G-03 Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTime End Time our (hr) phase Op Code Ac" Code me P -T -X Time Operation Depth (HHB) End Depth (111<13) 6/7/2019 6/7/2019 1.00 PRODi RPCOMP PRTS P CBU @ 6 bbls min w/ 750 psi Shut 17:30 18:30 Down and test casing @ 3616' Pres up to 900psi EMW @ 14.2 No loss 6/7/2019 6/8/2019 5.50 PROD1 RPCOMP DRLG P Continue drlg F/ 3616 T/ 3856'-9-6 18:30 00:00 bbls min w/ 780 psi WOB 8-1 OK Rot 80RPM PUW 95K SOW 68K Rot Wt 86k P/U 10'@ 6 bbls W/ High Vis SweepAround Shut Down. 6/8/2019 6/8/2019 1.00 PROD1 RPCOMP FIT P Performed Fit lest pressure up and 00:00 01:00 attempt to 880 no go 680 PSI Break down EMW13.0 @ 2 bbls Bleed down to EMW of 10.1 PPG 20 mins T/ 200 psi Bleed off recover 1 BBIs 9.0 brine Call Town discuss with James Hayes Results Good to Ddg Head . 6/8/2019 6/8/2019 6.00 PROD1 RPCOMP DRLG P Continue drilling on CIBP @ 3854' 01:00 07:00 DPM W/ 4-12 K Rot 30-80 RPM w/ 2- 6 BbIS min w/ 150-550 PSI Tq- 3200U4000f/lbs 6/8/2019 6/8/2019 1.00 PROD1 RPCOMP WASH P Push upper CIBP F/ 3854'T/ 3958.5' 07:00 08:00 W/ no rotation 5 BPM 550 PSI. At kelly down kick in rotary back ream stand and ream down 45 RPM Tq- 3000-3200. 6/8/2019 6/8/20191.00 PROD1 RPCOMP CIRC P Pump 30 Bbls 300 vis sweep and 08:00 09:00 chase out of hole. Observe well for flow for 10 min.- No flow. B/D top drive, remove blower hose. 6/8/2019 6/8/2019 1.50 PROD1 RPCOMP TRIP P POOH rack 3 1/2" DP back in derrick 09:00 10:30 6/8/2019 6/8/2019 1.00 PROD1 RPCOMP SHAH P UD drill collars and BHA. 10:30 11:30 6/8/2019 6/8/2019 0.50 PROD1 RPCOMP SFTY P PJSM with Schlumberger and rig crew 11:30 12:00 on rigging up to run E -Line 6/8/2019 6/8/2019 1.00 PROD1 RPCOMP RURD P Rig up Schlumberger E -Line. 12:00 13:00 6/8/2019 6/8/2019 3.50 PROD1 RPCOMP ELOG P RIH with CBL and log F/ 3958'T/ 13:00 16:30 1900' POOH. R/D E -Line. 6/8/2019 6/8/2019 0.50 PROD1 RPCOMP SVRG P Service top drive, and drawworks. 16:30 17:00 6/8/2019 6/8/2019 2.00 PROD1 RPCOMP SHAH P PJSM R/U lower completion 17:00 19:00 Equipment 6/8/2019 6/8/2019 1.50 PROD1 RPCOMP RCST P M/U41/2" Lower completion W/ 19:00 20:30 tandem Wedges 4 1/2" 11.6 L-80 BTCM tubing Check Float shoe All good 6/8/2019 6/9/2019 3.50 PROD1 RPCOMP TRIP P Continue RIH w/ 3 1/2" H.T.38 Work - 20:30 00:00 String Fill pipe every 1000' as go and Tag up @ 3956' Top of #2 CIBP and Space out 7.2' PUW 90K SOW 70K 6/9/2019 6/9/2019 3.00 PROD1 RPCOMP CIRC P Continue Space out and M/U Baker 00:00 03:00 Cementing head and Circ @ 3 bbls 285 psi R/U SBL Cement Equipment, 6/9/2019 6/9/2019 2.50 PROD1 RPCOMP CMNT P Hold PJSM and Start Cementing Job 03:00 05:30 Pump 5 BBLS H2O Ahead and Test Lines T/ 4800 PSI Good Test, Pump 10 bbls 12.5 spacer chase w/ 12 bbls class G- Cement 15.8 Ib, wash up and v drop drill pipe dart chase w/ 26 bbls and bump plug and pressure up to 4500 psi 10 mins set PKR. Float shoe depth 3951.3'. Top of PBR depth 3624.71' Page 516 Report Printed: 6128/2019 Operations Summary (with Timelog Depths) 1G-03 Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTime End Time Dur (hr) phase Do Code Activity Code Time P-T-X Dperaflon Start Depth (flKB) End Depth (flKB) 6/9/2019 6/9/2019 1.00 PROM RPCOMP RURD P R/D casing equipment, B/D top drive 05:30 06:30 and choke manifold 6/9/2019 6/9/2019 4.00 PROM RPCOMP PULD P LDDP T/ liner running tool 06:30 10:30 6/9/2019 6/9/2019 0.50 PROM RPCOMP BHAH P UD linerrunning tool 10:30 11:00 6/9/2019 6/9/2019 1.00 PROM RPCOMP RURD P Remove wear bushing. Function rams 11:00 12:00 1 and jet slack. 6/9/2019 6/9/2019 0.50 COMPZN RPCOMP SFTY P PJSM W/ Baker completions, 12:00 12:30 Weatherford and rig crew on running completion. 6/9/2019 6/9/2019 5.50 COMPZN RPCOMP RCST P M/U and RIH w/ 4 1/2", 12.6#, L-80, 12:30 18:00 563 tubing. M/U to 4600 ft/lbs torque. Tot joints Run 111 + 4 pups and hanger 2 GLM amd Baker Seal Assy 6/9/2019 6/9/2019 2.50 COMPZN RPCOMP THGR P Engage Baker seal bore assembly w/ 18:00 20:30 locator no go and space out 1.5' off no go PIU pups and M/U Cameron Gen 1 V Tubing Hanger. 6/9/2019 6/9/2019 2.50 COMPZN RPCOMP CRIH P R/U and swap well over V corrosion 20:30 23:00 1 1 inbibited Cl 9.0 Brine 6/9/2019 6/10/2019 1.00 COMPZN RPCOMP THGR P RIH and RILDS PUW 701k SOW 60K 23:00 00:00 set in hanger bowl w/ 30K string wt 6/10/2019 6/10/2019 1.50 COMPZN RPCOMP THGR P Test tubing 1:13000 psi 5 mins All 00:00 01:30 Good and Bleed down tubing t/ 1800 psi,Test [At/ 3000 psi Hold 30 mins no loss Bleed Down tubing to 0 and shear out SOV R/D landing joint& lines and Install BPV and Test 1000 PSI f/ below All good 6/10/2019 6/10/2019 3.50 COMPZN WHDBOP NUND P N/D BOP and NIU tubing head 01:30 05:00 adapter and install dart in BPV w/ Cameron hand 6/10/2019 6/10/2019 2.00 COMPZN WHDBOP THGR P Test tree and hanger packoff V 05:00 07:00 250/5000 psi 10 mins each All good Pull BPV and Dart UD same 6/10/2019 6/10/2019 4.00 COMPZN WHDBOP FRZP P R/U LRS pump down IA and Displace 07:00 11:00 w/60 bbls diesel and U-tube 6/10/2019 6/10/2019 1.00 COMPZN WHDBOP THGR P R/D lines and set BPV and Release 11:00 12:00 Irig F/ 1G-03 T/ IG-16 @ 12:00 Page 616 Report Printed: 6128/2019 STATE OF ALASKA JUL 0 1 Lfl�9 ALASKA OIL AND rAR CnNSFRVOTlnKl rnneneiceinru WELL COMPLETION OR RECOMPL TION REP, RT AND�,.I C 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned M Suspendec - 1b. WeII Class: z0nnc 25.105 � z0nnc z5110 I Development EJ Exploratory ❑ GINJ E]WINJ❑ WAG❑ WDSPL❑ No. of Completions: Service Q Stratigraphic Test ❑ 2. Operator Name: 16. Date Comp., Susp., or Ir' ConocoPhillips Alaska, Inc. 5/30/2019 14. Permit to Drill Number/ Sundry: 182-149/318-540 3. Address: P.O. Box 100360 Anchorage, AK 99510.0360 7. Date Spudded: 9/20/1982 15. API Number: 50.029-20824-00.00 - 4a. Location of Well (Governmental Section): Surface: 1129' FSL, 264' FWL, Sec 29, T12N, R10E, UM ' Top of Productive Interval: 1102' FSL, 3517' FEL, Sec 30, T12N, R10E, UM Total Depth: 1335' FSL, 3981' FEL, Sec 30, T12N, R10E, UM 8. Date TD Reached: 1011/1982 16. Well Name and Number: KRU 1G-03 . 9. Ref Elevations: KB:92 GL: BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool - 10. Plug Back Depth MD/TVD: 6695/5451 18. Property Designation: ADL 25640 - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540037 y- 5981775 Zone- 4 TPI: x- 536256 y- 5981729 Zone- 4 Total Depth: x- 535790 y- 5981959 Zone- 4 11. Total Depth MD/TVD: • 8489/6951 - 19. DNR Approval Number: ALK 2571 12. SSSV Depth MD/TVD: 1804/1777 20. Thickness of Permafrost MD/TVD: 1500/1493 5. Directional or Inclination Survey: Yes ❑ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: NIA 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 30 108 30 108 24 325 sx AS II 10 314 45.5 K-55 29 2303 29 2216 13 1/2 1400 sx AS III, 250 sx AS I 7 26 K-55 27 8464 27 6929 83/4 900 sx Class G, 250 sx AS I 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; PeOorati^ ` Size and Number; Date Perfd): /O �� ed PERFORATIONS PLUGGED BACK l�-301 7495-7525... squeezed... 5/24/2019 DATE 7540-7563... belowsqueeed.......6/2 /20 57 7772-7825...below CIBP....5/24/2019 !y VE (FIE 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 112 7739 73545/5987 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6695-7720 16 E 15.Sppg 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10-407 Revised 5/2017 M 10/;3 1CONTINUED ON PAGE 2 ROMSI✓JUL 0 81019 SuRIGINST AL on� float' 28. CORE DATA Conventional Core(s): Yes ❑ No (] Sidewall Cores: Yes ❑ No 0 - If Yes, list formations and intervals cored (MD/TVD, Fromrro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1500 1493 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation @ TPI - Formation at total de the N/A 31. List of Attachments: Daily Operations Summary, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination KNey, core analy , paleontoloQical report. productionwell test resulu,r 20 AAC 25.070 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Ty Senden Contact Name: Gary Eller Authorizedtle: t Wells Supervisor Contact Email: J.Ganr.Ellerco .com Authorized Contact Phone: 263-4172 Signature: Date: 1.40e) INSTRUCTIONS General: This form d the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 1 07 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this farm and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region W-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1 G-03 PLUG FOR RE --FRILL DTTMSTAJOBTYP SUMMARYOPS 4/9/19 DRILLING (HELD 5500 PSI ON CONTROL LINE THROUGHOUT JOB) SET 2.75" WFT CIBP MID- SUPPORT- ELEM @ 7718.5' RKB, CORRELATE TO SLP IPROF 24 -APR -2003. PUMPED 20 BBLS CAPITAL DOWN TBG @ 2 BPM 1900 PSI. PERFORATE W/2" X 2' TBG PUNC, 00 phase, 4spf FROM 7315'-7317' RKB. CORRELATE DETAIL 11/13/87. LRS TO BULLHEAD 105 BBL DIESEL DOWN IA 4/9/19 PUMPING BULL HEAD DIESEL DOWN IA TRACKING PUMP 110 BBLS DIESEL ONLY JOB COMPLETE 5/20/19 DRILLING RIH TO 7280' CTMD. PUH TO STRING WEIGHT, CT DEPTH = 7270', CORRECT TO 7275' SUPPORT- RKB. PUMP 1/2" BALL, BALL ON SEAT AT 32 BBLS. PRESSURE UP 1200 PSI, WAIT 5 CAPITAL MINS., PRESSURE UP TO SHEAR AT 3800 PSI. STACK DOWN 8K ON RETAINER, HOLDING. PUMP T X CT, 200 PSI ADDITIONAL PRESSURE GET COIL WEIGHT BACK. RIH T WITHOUT STACKING. PUMP T X CT, COMMUNICATING TO IA. CALL TOWN ENG. TO DISCUSS. ATTEMPT TO CONTINUE RIH TO PUSH TO CIBP(7718'), RETAINER WILL NOT PUSH ANY FURTHER. PUH AT STRING WEIGHT AND CONTINUE TO SURFACE. OOH WITHOUT RETAINER. RECOVER BALL. WELL FREEZE PROTECTED. RE -START NEXT DAY TO MILL RETAINER. JOB IN PROGRESS. 5/21/19 DRILLING RIH TO 7280' CTMD. PUH TO STRING WEIGHT, CT DEPTH = 7270', CORRECT TO 7275' SUPPORT- RKB. PUMP 1/2" BALL, BALL ON SEAT AT 32 BBLS. PRESSURE UP 1200 PSI, WAIT 5 CAPITAL MINS., PRESSURE UP TO SHEAR AT 3800 PSI. STACK DOWN 8K ON RETAINER, HOLDING. PUMP T X CT, 200 PSI ADDITIONAL PRESSURE GET COIL WEIGHT BACK. RIH T WITHOUT STACKING. PUMP T X CT, COMMUNICATING TO IA. CALL TOWN ENG. TO DISCUSS. ATTEMPT TO CONTINUE RIH TO PUSH TO CIBP(7718'), RETAINER WILL NOT PUSH ANY FURTHER. PUH AT STRING WEIGHT AND CONTINUE TO SURFACE. OOH WITHOUT RETAINER. RECOVER BALL. WELL FREEZE PROTECTED. RE -START NEXT DAY TO MILL RETAINER. JOB IN PROGRESS. 5/22/19 DRILLING SUPPORT - CAPITAL 5/23/19 DRILLING SUPPORT - CAPITAL 5/24/19 DRILLING SUPPORT - CAPITAL 5/30/19 DRILLING SUPPORT - CAPITAL RIH TO 7280' CTMD. PUH TO STRING WEIGHT, CT DEPTH = 7270', CORRECT TO 7275' RKB. PUMP 1/2" BALL, BALL ON SEAT AT 32 BBLS. PRESSURE UP 1200 PSI, WAIT 5 MINS., PRESSURE UP TO SHEAR AT 3800 PSI. STACK DOWN 8K ON RETAINER, HOLDING, PUMP T X CT, 200 PSI ADDITIONAL PRESSURE GET COIL WEIGHT BACK. RIH T WITHOUT STACKING. PUMP T X CT, COMMUNICATING TO IA. CALL TOWN ENG. TO DISCUSS. ATTEMPT TO CONTINUE RIH TO PUSH TO CIBP(7718'), RETAINER WILL NOT PUSH ANY FURTHER. PUH AT STRING WEIGHT AND CONTINUE TO SURFACE. OOH WITHOUT RETAINER. RECOVER BALL. WELL FREEZE PROTECTED. RE -START NEXT DAY TO MILL RETAINER. JOB IN PROGRESS. WAITED ON SLB CEMENT CREW FROM DEADHORSE. DIFFICULTIES DUE TO KUPARUK RIVER FLOODING AND ROAD CLOSURE. / RIH AND SET CEMENT RETAINER @ 7248' CTMD. PUMP 16 BBLS OF 15.8 PPG CEMENT THROUGH RETAINER TO FORMATION. OPEN UP IA AND CIRCULATE 14 BBLS OF CEMENT UP IA TAKING 1:1 RETURNS, PULL OUT OF RETAINER AND LAY IN 5 BBLS OF CEMENT ON TOP OF RETAINER. CLEAN OUT DOWN TO ESTIMATED TOC @ 6670' CTMD. FREEZE PROTECT WELL. READY FOR SLICKLINE IN 24-48 HOURS. (MAINTAINED 5500 PSI ON CONTROL LINE THROUGHOUT JOB) SW (BRIAN BIXBY) TAG CEMENT @ 6695' RKB (GOOD CEMENT SAMPLE). MITT TO 2200 (PASS). MIT -IA TO 2200 (PASS). GAUGED TBG TO 2.74" DOWN TO 5000' RKB. CUT TBG @ 4800' RKB. SET HOLDOPEN SLEEVE IN TRDP-1A @ 1804' RKB. PROVIDE CRANE ASSIST TO SET BPV. ConocoPhillips Kaska, If l KUP INJ WELLNAME 1G-03 WELLBORE 1G-03 1G{V, BRTTN1B936, D3 pM Last Tag Ventral wM1aus,("an) AnnolNion I 0¢pIn IXKB) End Data I Williams Last MM By ..._....................... H -N,, 05 ............. ............... Last Tag; RKB 6,995.0 SI30I2019 1G-03 Itand, 8PV. 24s Last Rev Reason Annabnan End Dale Well Gze Moa 9y Rev Redson:Tag, Jet Cut, Hold Open Sleeve, BPV. 513012619 1G-03 lound, Casing Strings Casing Desc,l,her CONDUCTOR 00 (in)) IDlin) Tap{XKBI Se[pepb {flKBI Set OeplM1{ND)... WXLen g...Gm Oe Top Tnmead 16 1525 30.0 1080 108.0 8500 H-00 WELDED Gsing Des«Ip11on0 SURFACE 0(in) I m(in) TSPRIKB) Set Oaptn IXKB) SM res pon IND)... WXL¢n (L.. Gratle iop TM1reatl 10314 9.95 29.0 2,302.8 2,216.1 45.50 K-55 BTC CONDUCTOR; 30.DililO Csame .-anPflan PRODUCTION GDllnl 10{in) Tap IXNBI 5¢+O pM {/MBI Se[OepIM1 {ND)... WVL¢n II... Orbe Top in,eatl J 628 27.5 8,463.8 6,928.8 2600 K-55 BTC Tubing Strings SLRIap Ot e-2.ag1a-. Tubing 0eecrip+ion 4.5"HYD 503 Completion String Ma... 4112 l 0 pn) 3.96 Top bKB) 24.5 SODepth IX.. 3,633.3 Set Death IN01 I... 3,238.3 Wt11On 12.35 Gmene L-80 Top Co"actlon HYD 503 Mrp,M,26 Completion Details To(.Kai Top lnel Nominal Top IIMB) {flKB) PI Item Des Cam to {in) 24.5 24.5 0.0) Hanger Hanger FMC -Gen 31116" x 4112" VAM FJL BXP 3.958 RrMN; Reaes 3,823.0 31230.9 44.67 Locator Baker locator 3.980 Inmmm', sers.o 3,623.7 3,2314 44.65 Seal Assembly Baker seal assembly (1- off no�o) 3.980 wI Aesene. 3...T s p ithlorsnea amt a«.,6=M)',am4T Tubing 0encriptian s+nne ..,.It. 'in) To,{flleal Set -Pon Or..., -Dan Irv, .HIND Gmae Top Conn«non 4.5" Scab Liner 4112 399 3,6243 3,9513 3,4684 1260 L-80 BTC Completion Details FP 53 paces, 9,9195 Top{ND) Top Incl Nominal Top ME) In RES r Ihm Des Co. 10 (in) 3,6247 3,232.1 44.63 PER (PDlis etl Baker 412 x T' 2RH Liner Setting Sieve 4.190 Bore nape -X aarsE � 'Paul; S. r.d � cem.msw«0-e:8eee.Omae nmemMen, ...a7 SO Leer G,renL a,az4Jnxs9 Receptacle) 3,6498 7,249.9 44.03 FP S3 Packer Baker 4112' x 3" FP S3 Packer VT Pin x IBT Pin 3.920 3,6)5.5 3.288.6 43.]4 NiPPIe-X XNipDIe HES 3.813' BTCMB%P 3.813 -Wedge 3,3)6.8 3,342.5 42.93 Tandem Northern Solutions 412"Tantlem wedge 3.958 Nipple - x; k7ei 3,7958 3,3563 4293 NINPIe-X XNipple 412"x3.813"BTCM BxP 3.813 -Wedge Tvdem Wetlge; 3aW,a 3,809.6 3,3665 43.10 Tantlem NNorman,Solutions 4-1/2" Tandem Wedge 3958 A 3,620.9 33347 43.30 Nipple-% XNipple 4-12"x3813'BTCM BxP 1813 Nlppb�x;3,9aW ! 3,8'N 3,406.0 43.9fi lB.Jing Col lar 112 Landing Collar 3.93D 3,9496 346]2 44.45 Float Shoe Float shoe BTCM 0000 Lwtlinp Ctlhr; 3aF,R Fku151xre; 3.8188 Tubing 0esmlpnan Slnng Ma... 10 {in) Top IXNBI Set OapM {fl.. aet GpN INO)(... WI pWq ad. lop Connecllon Tubing left in M1Dle 3112 298 4,8000 3,3392 6,308.4 9.20 J-55 BTCABMOD Completion Details BMameFtp- 9BY .Inc.', 4sdo.o Top{ND) Top mel Nominal Top MIS Sake) {') Ihm Des Com 10 (in) 3,340.3 5,974.6 33.33 PER BAKERPBR 4.250 cement p.p: Duds Resistance ..einem 3,354.] 5,986.6 3332 PACKER BAKER HIS PACKER 2.890 .-me Rd®¢¢7x0.0 7.498.9 6,10)4 3283 FUST BLAST JOINTS (DAL=304') 3000 amine Plug', 7.SUE dol 3,320.1 6,292.5 3343 SEALASSY BAKER LOCATOR SEAL ASSEMBLY 2.985 GAs uFr', 7pR1.a 3,320.6 6,292.9 3343 PACKER BAKER FBA PACKER 4000 3,723.9 Q2953 33.44 SBE BAKER 80-00 SEAL BOREEXTENSION 4000 CRT Sc; 73150-73170 7,732.9 8.303.2 3346 NIPPLE CAMCO D NIPPLE NO GO 2.750 71738.4 6,30].8 33.48 SOS CAM GO SHEAR UT SUB, ELMD TTL @ 7726during lPROF on 3.015 PBR;,,a1Ds 1 0511412003 Petl«mn calms tenant Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) T.355a Son pnCKER. 7SA1 To'lNol Top nor Top MR) IXKB) fl Oea Cam Run Date ID (in) 24.5 24.5 0.07 BPV Type H BEV 611612019 0.000 INJECTION173m.o INJECTION: 7.1e18 3,958.5 3,4735 4448 Britlge Plug- CIBP 6/412019 0000 PGrmdnen( 4,800.0 4,065.6 45)0 Jet Cut Jet Cul 5I302019 0.000 IPERF: 749E.0.7,52s,O� 3,260.0 5,903.6 33]0 ement WEATHERFORD 3.5" CEMENT RETAINER 5/242019 0000 Ratdlner 7,7180 6,290.7 33.43 CIBP WEATHERFORD 3112" CIBP OAL I' MAX OD 2]5" Y32019 0000 Perforations S Slots IPERF', 7,E40o75sa it SM1ot TOPgMO) BWMKB) top Unum Blue "lo Dens ME) IXNBI LiakadZone gate 1..."6X1 Np tom INJECTION 7eTo.1 3,669.0 $826.0 3,253.9 3,378.4 6/42019 12.0 IPERF _,315.0 7,380 5,9534 5,955.1 4/912019 4.0 CMTSOZ "Tubing Punch tleg phasing4spf. -6.-1 -041 cap:Tp+8o3.495.0 7525.0 8,129.3 C-3, 1G-03 825/1984 12.0 IPERE SEAL Assr; 77S0 7,5400 7,583.0 5,141.9 8,1612 P1,1G-03 8/25/1984 12.0 IPERF PACKER'. 7.7tes SEE; 7,723.9 3,3720 7,8250 6,3358 6,3799 74A -3,1G03 812511984 12.0 IPERF Cement Squeezes TOPINDI Blm(No) NIPPLE; 7Ts.9 Top IXKB) Bnn IXKB) MR) ME) Des MODS. I Com 3,261.5 3)18.0 5,9088 6,290) Cement Plug 5240019 Herb OF 15.8 PPG CLASS G CEMENT BELOW sos; T.nB.4 115 RETAINER INTO C SAND SELECTIVE 3,3550 ],]20.0 5,986.9 6,2926 Production 5242019 Casing Cement 6,682.0 7,2600 5,441.4 S,967,6 Cement Plug 52412019LAYE IN BBL 15.8 PP GC N ABOVE RETAINER. CONTAMINATED DOWN TO 1PERF777xa7.e250� ESTIMATED TOC OF 6682' 6,854.0 7,3540 5,536.5 5,986.0 Cement Plug 51242019 14 BBI -S OF15.BPPO LAS C N CIRCULATED UP IA THIRD TUBING PUNCHES 3,6690 3,8260 3,2639 3,3]8.4 Cement 6152019 Squeezetl ini .8P Gclass Gcement witM1 Arcner Squeeze StrOnghcdd Barric` d"No. PRODUCTION', gl.S6anri KUP INJ WELLNAME 1G-03 WELLBORE 1G-03 ConocoPhillips Alaska, Inc. MaEel SURFACE: 39.BQ3a3.8� M»]nl', 2=2— u... 2—u... 35%3 Lac M', 3.6C1.0— el Pott Y; 3833] PEN IPNY BamL RxepNCY); 3,631 ]� FP 53 PackeC 3819.5 Nyle -X 3S]55— (PERF: 3 a�.0.iS. am3Rucna;36B3.BnNe1— Tanaemw ,S776e— imnm nt, S,s34 7KKS Nippy-%; 3,]BS.8� NpP4 X 3SA.8— nnMM Cale: 3.1603 FImt8�w: 3N8.8— SMpa PLS- Pemunou. 3,...— M ,RA5M Cal: 4.11000 mant MLC 85820 Po(S a nn Lmne Cum[ 895aCKKB— m tlUnn,7,MBOL .nam wLg 1331 SnNB— GA3 LIFT:7 3— INJECTION. 7,3R2 0— INJECTION,7,1019— IPERF;1d95.b],R80� IPERF 7.5 W.D].SW.0 INJECTION; TIRE 1— CIBP;],]180— 3EALA35V; i,]301— PALNER;],]ZI.S SBE: ].]2i.9— NIPPLE:].]329— SOS;],]39A— IPERF7,MC-7,@ O0 PRODUCTION; 0.5 483.8 Run OeR I Gam STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 iter• �a non ECEIVE® JUL 0 9 2019 Jz15 7 oil[? AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill El Perforate New Pool EJRe-enterSus P Well ❑ Alter Casing 11Other:—Whipstock—El2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ElDevelopment EJ 182-149 ' 3. Address: Stretigraphic ❑ Service ❑ 6. API Number: , PO Box 100360, Anchorage AK 99510 50-029-20824-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/p, KRU 1G-03 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25640 Kuparuk River Field /West Salk Oil Pool 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8489' 6951' 8464' 6929' 1179 3959' N/A Casing Length Size MD TVD Burst Collapse Conductor 108' 16" 108' 108' Surface 2302' 10-3/4" 2302' 2218' Production 8464' 7" 8464' 6929' Scab Liner 326' 4-1/2" 1 3951' 3238' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3669'-3826', 7315'-7317', 7495'- 3264'-3378', 5953'-5955'.6104'- 953'-5955', 6104'- 7525', 7540'-7563', 7772'-7825' 6 6129', 6142'-6161', 6336'-6380' 4-1/2 L-80 3633' Packers and SSSV Type: Baker FB S3 Pecker Packers and SSSV MD (ft) and TVD (R): 3650' MD / 3250' TVD Baker HB Packer 7355' MD / 5987' TVD Baker FB -1 Packer 7721' MD/ 6293' TVD 12. Attachments: Proposal Summary ❑� Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/22/2019 OIL ❑ WINJ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Ryan Mcl-aughlir� Authorized Title: Staff CTD Engine Contact Email: an. mclaU hlin CO .COm Contact Phone: 265-6218 Authorized Signature: Date: %/ti /f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 314-3Qi Plug Integrity E] BOP Test l� Mechanical Integrity Test ❑ Location Clearance ❑ Other: QO 7 ft -,S /1 f0 J P� `S 5-00 1 Il T /ITn n L/ ]a t -P r-2- V ', Vt-,, ✓ i�� 51 %i sU D P S -t-5 Post Initial Injection MIT Req'd? Yes ❑ No � RBDMS ��JUL 12 2019 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 1,9-404— / APPROVED BY Approved by: Z COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 4/2017 Approved applicatio, 0- R -1 _G I N A L - prova]. Submit Form and Attachments in Duplicate MB 7,11orig KRU 1G-03 (PTD #182-149) CTD Summary for Sundry Summary of Operations: KRU well 1 G-03 is an injector that was recently worked over to be set up for CTD operations. During the workover, 4-1/2" tubing was installed with tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge within the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 3812' MD. After that the 1G-103 lateral will be drilled to the north targeting the West Sak B -sands. The 4R--t2&lateral will be completed with 2-7/8" slotted liner in the lateral and 3-1/2" liner in the build, with a deployment sleeve on top. t 6-103 C) Pre -CTD Work otojkA, 1. RU Slickline: Drift, set X -lock 2. RU E -Line: Set inner wedge at 3812' MD 3. Prep site for Nabors CDR3-AC rig. ig or 1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPE, test. 2. 1G-103 Lateral (West Sak B -sand - north) a. Mill 3.80" window at 3812' MD s —mob. Drill 4-1/4" bi-center lateral to TD of 10,100' MD. c. Run 2-7/8" slotted liner and 3-1/2" solid liner with deployment sleeve from TD up to 3800' MD. \– 3. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 4. Return well to production. Page 1 of 1 7/8/2019 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 8, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set an Inner Wedge in KRU 1G-03 (PTD #182-149) in order to drill one CTD lateral using the coiled tubing drilling rig, Nabors CDR3-AC. Attached to this application are the following documents: - 10-403 Sundry Application for KRU 1 G-03 - Operations Summary in support of the 10-403 sundry application - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin ConocoPhillips Alaska Coiled Tubing Drilling Engineer IG -03 Proposed CTD Schematic J Arctic Pack cement ^'2100'-2500' via CBL 10- 3-82 (RA tracer) CTD KOP 3812' Whipstock set @ 10° ROHS 108' MD E " 45.5#hoe @ 2303' MD,VD 1G-031-1 wp02 - 7° DLS Plan TD 10,100' MD WOB Models 2500' MD Top of good quality i '.;( :;.:.::; ;:•: cement behind the 7" at s "'7380' (CBL of 8-21-84) WELL LOG TRANSMITTAL #905728611 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jet Cutter, Plug Setting, and Tubing Punch Records: 1 G-03 Run Date: 04/09/2019 and 05/30/2019 182149 30 92 3 June 26, 2019 JUN 2 7 2019 A®GCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1G-03 Digital Data in LAS format, Digital Log Image file 50-029-20824-00 I CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: 1:: PTD /9'2-149 Loepp, Victoria T (CED) From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Saturday, June 8, 2019 10:26 PM To: Loepp, Victoria T (CED) Subject: Re: [EXTERNAL]Re: 1G-03 Update Follow Up Flag: Follow up Flag Status: Flagged Thank you. At this point I can speculate that they will attempt a squeeze and try again but I will circle up with my CTD group on Monday and get you a more solid answer. Thanks, James Hayes C: 918.914.9609 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Saturday, June 8, 2019 10:15:49 PM To: Hayes, James C Subject: Re: [EXTERNAL]Re: 1G-03 Update James, Approval is granted to proceed as outlined below with running/cementing the liner. I would like to know what will be proposed during drilling if the FIT out of the window is not adequate. Thanx, Victoria Sent from my iPhone On Jun 8, 2019, at 8:30 PM, Hayes, lames C <James.C.HavesPconocophillips.com> wrote: Victoria, I have attached a lot of information but I'll start with FIT we performed. Our goal was to achieve a 14.2 ppg FIT however we were only able to achieve 13.3 ppg equivalent. After 15 min the pressure bled down to a 10.2 ppg equivalent and remained for the duration of the test. During this test there was no pressure seen up the OA due to the Artic pack cement job that was done some time before. This cement can be seen in the CBL (CPAI_1G-03_SCMT) from about 2,100' MD to 2,450' MD. Looking at the perforated section from 3,669' MD to 3,829' MD in (1G-03 CBL.pdf) you can see that we did have good cement placement like the last 2 wells 111-26 & 1R-04. There is a possible section at the bottom of the perfs that might indicate poor cement placement, but it is tough to tell because 111-26 had similar results. My plan forward that I would like to suggest is to allow us to run our liner like planned and once we are on depth and ready to pump the cement job. We will pump the cement job, which was planned for 30 bbls but we will pump 12 bbls, holding an additional 50 psi on the back side. This should allow us to squeeze any cement into formation while the cement job is being pumped. As it sits we will be pumping a 10 bbl 12.5ppg spacer followed by the 12 bbls of 15.8 ppg cement. The hydrostatic column of this plus the 9.0 ppg brine on top is already greater than the 10.2 ppg we achieved from the FIT. So we should be squeezing cement with just the hydrostatic column of fluid but I feel and extra 50 psi with help. I feel we have more that plenty excess to squeeze cement and still cement the entire liner. Please read and work through this email, if you have any questions please feel free to reach out to me in an email or even call me at the number below and I can answer anything you need. Once you have everything can you please let me know if you approve of this plan? Thanks, James Hayes C: +1918.914.9609 From: Loepp, Victoria T ]CED) <victoria.loepp@alaska.eov> Sent: Saturday, June 8, 2019 4:08 PM To: Hayes, James C <James.C.Haves@conocophillips.com> Subject: [EXTERNAL]Re: IG -03 Update Please send schematic. Have you pressure tested? Sent from my Whone On Jun 8, 2019, at 3:25 PM, Hayes, James C <James.C.Haves@conocophillips.com> wrote: Victoria, Just wanted to update you, we had issues drilling out the bridge plug which has put us behind a few hours. We have logged and from a field level it looks to be the same quality as the previous wells but I'm waiting for the town guys to process the info. So it might take me about an hour or two to reach out to you. Thanks, James Hayes C: 918.914.9609 <CPAI 1G-03 SCMT 08Jun19 Field Print.Pdf> <1G-03 CBL.pdf> <1G-03 Proposed Schematic.pdf> <1G-03 Schematic.pdf> <1G-03 csg FIT—Ver 1-3.pdf> 1G-031 Present Well Condition AWk Pack eemeM -2100'-25 WCBL 10. 322 (U. treu]) PE FS Gema7a05'4ww Cu�q 7SIO-7e3' M sera®2MIce5a m Top of goad peal&r [ meM Whind Me)" at-i3go'Itgtofe-ri. &3/c 14. g'9.Jb5WEMp )BD0.1ReC35V a1 teDc'Iw •ze13j Fix LNre, 3 313 -ID, yfWS. NWWm1pYt) t&%mreWtl t)di' eM,m HBpskMM]]SP 1®lgkeYJlm title p)M,ib2,e ]0 BMr Fbt PdurM ]r21' a 0(2.MD)In3T TbOWIMn3B' IG -031 Workover Setup <%"8as lift � amPlellon N preperatlon for RDZMetradt Kupamk Pwd W sakfO um C agoee2e perfs:36)z'- 5' KB (160') .1, sp.eem, ddg & log, ma 4.5",12.6 L2O enerumented in x weh IDP packer @ 20' K& Shoe of fin ,M W'KB. 1G -03i CTD Completion mix PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: 1G-03 R19:1 Nabors 7c5 Date: 1 6;8/2019 volume In t Volumel5troke Pump Rate: Drilling Supervisor: K. Barr / Ronnie Dalton jPump used: at Mud Pump w Spokes IV 0.0577 Bbis/Strk 0.75 Bbl/min Type of Test- Casing Shoe Test LOT/FIT IV Pumping down anmius and DP. Casina Test Pressure Intearlih, Test Hole Size: 9-7rs- w Casino Shoo Depth Hole De th Pumping Shut-in Pumping Shut-in RK -CHF: 24.1]Ft 385. t- 3 0 . l -TVD 66 . t- 3 4.0 t -TVD Strive ps, Min psi Strike psi Min psi Casino Size and Description: 7- 26#/R J-55 STC -MOD Ca in Tet P es m In Mud Weight: ppg Mud Weight Mud 10 min Get: Lb/100 Ft2 Mud 10 min Gel: Test Pressure: psi Rotating Weight: Rotating Weight: Lbs Blocksrrop Dme Weight: Blocks/Top Detre Weight: Lbs Desired PIT EMW: Estimates for Test: 0 bins Estimates for Test: r T 9.0 w ppg Lb/100 Ft2 Lbs Lbs ppg psi OA bbls 0 4 6 0 0 60 -4-250 -8-345 0.00 680 1.00 600 .00 500 9.0 1 3 -12-425 .00 420 75000.0 35 00. 16 4 16 520 4.00 390 5 -20---60 .00 360 14.2 24 6 24 730 6.00 320 88 28 7 7.00 300 w W =Leak caesura+ u We t = 850P T 75 Secon 0.052 x TV13 0 z 33 3+ 9 Shut-in Pressure, psi EMW at 3856 Ft -MD 3300 Ft -TVD = 14.0 igpq 600 32 36 1 8 9 8.00 295 9.00 280 40 10 10.0 250 44 15 11.00 235 100° 48 20 12.00 220 52 25 13.0 210 56 30 14.00 205 60 64 15.00 200 1 16.00 200 W 8 I 1 17.00 200 72 18.00 200 w isap 76 19.00 200 80 K 2 . 0 200 1.00 2 d 0 0 5 1. 15 m n ao Shut -In time, Minutes o PITPdraPumped o + a a 5 Barrels �CASING TEST o ume I o ume Bled Beck lbals o ume PUm @d 5 o ume Bled Back l.OlBbls 5 ommants: Summary Loepp, Victoria T (CED) From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Friday, June 7, 2019 6:11 PM To: Loepp, Victoria T (CED) Subject: Re: [EXTERNAL]RE: 1G-03 Cemented Perforations Follow Up Flag: Follow up Flag Status: Flagged Victoria, Alright as it sits we should be finished drill and out of the hole by midnight. From this point the logging time and time it takes to get the data put into a log we can review, should take about 3-4 hours. So as of right now it's looking like 3 to 4 a.m. when I will have the results. Once I get them I'll put the some clear indicators of where the perfs are and then give you a shout. Sound like a plan? Thanks, James Hayes C: 918.914.9609 From. Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, June 7, 2019 9:49:17 AM To: Hayes, James C Subject: Re: [EXTERNAL]RE: 1G-03 Cemented Perforations James, Give me a timing update this evening. When you have your logs/info, email them to me and give me a call at 907-242- 9156 to let me know you have emailed them. Call me if you have any questions. Thanx, Victoria Sent from my iPhone On Jun 7, 2019, at 8:16 AM, Hayes, James C <James.C.Haves@conocoohillins.com> wrote: Victoria, Well our cement took a little longer than expected to gain the compressive strength that we required prior to drill out. Unfortunately this means that the time it's going to take to drill out cement and then log puts us at about midnight tonight (perfect timing on a Friday). How would you like to handle this once I get the logs? Would you like for me to call you so you can review and approve the information in order for me to proceed? Thanks, James Hayes C: +1918.914.9609 From: Loepp, Victoria T (CED) <victoria.loeppCa alaska ¢ov> Sent: Thursday, June 6, 2019 9:24 AM To: Hayes, James C <James.C.HaVeS conocophillips com> Subject: [EXTERNAL]RE: 1G-03 Cemented Perforations Thanx James From: Hayes, James C <James C HavesC@conocophillips com> Sent: Thursday, June 6, 2019 9:12 AM To: Loepp, Victoria T (CED) <yictoria.loepp alaska aov> Subject: 1G-03 Cemented Perforations Victoria, On 1G-03 we have already perforated our production casing and successfully cemented the perfs yesterday. I'm anticipating drilling out our cement and pushing one of the CIBP to bottom through the night. As of now I am anticipating dropping a CBL to evaluate the perfs sometime tomorrow. As soon as I get the results I will forward them to you to secure your approval. You can expect an update email from me in the morning to get you a better time estimate on the cement evaluation. Thanks, James Hayes COP - Alaska RWO Engineer C: +1918.914.9609 O: +1907.265.6927 MEMORANDUM TO: Jim Regg 2t° 5/31h P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Section: 29 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Jake Fame Casing/Tubing Data (depths are MD) State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 30, 2019 SUBJECT: Well Bore Plug & Abandonment KRU 1G-03 Conoco Phillips Alaska Inc. PTD 182-149; Sundry 318-540 12N Range: 10E Meridian: Umiat NA Total Depth: 8489 ft MD Lease No.: ADL 25640 Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Surface: 10.75' O.D. Shoe@ 2302 Feet Intermediate: Feet O.D. Shoe@ 0 Feet Production: 7" O.D. Shoe@ 8464 Feet Liner: O.D. Shoe@ Feet Tubing: 3.5' O.D. Tail@ 7739 - Feet Plugging Data: Test Data: Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing - Retainer 7320 ft MD 6691 ft MD 8.4 ppg Wireline tag OA 0 0 0 0 Initial 15 min 30 min 45 min Result Tubing 2225 2075 - 2050- 2025 ' IA 1010 1010 1010 - 1010 P OA 0 0 0 0 Initial 15 min 30 min 45 min Result Tubing 1220 1 1250 1 1250 IA 2210 2125 2100 P OA 0 0 0 Remarks: Plugback for redrill; wireline tag with a bailer - tagged at 6691 ft MD. The bailer was emptied out on surface and had hard cement in it. MITT and MITIA also witnessed - both pass. Attachments: none rev. 11-28-18 2019-0530_Plug_Verification_KRU_1 G-03_bb PTD 192 —fg Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, May 16, 2019 9:05 AM To: Eller, J Gary Subject: KRU 1 R-04 (PTD 185-178, Sundry 319-102) ;KRU 1G-03 (PTD 182-149, Sundry 318-536) Workover Revisions Approved Gary, Approval is granted as written below. Please update the approved sundry with this new approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(&a laska.goV CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepoca alaska.gov From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Tuesday, May 14, 2019 8:52 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Hayes, James C <James.C.Hayes@conocophilIips.com>; Hampton, Kyle <Kyle.Hampton@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: Revision for Workover Sundries for KRU 1R-04 (319-102) and KRU 1G-03 (318-536) Victoria — I'd like to get your approval on some minor changes in the approved workover sundries for KRU 1 R-04 (PTD 185-178, sundry 319-102) and KRU 1G-03 (PTD 182-149, sundry 318-536). In both wells, ConocoPhillips wants to make minor corrections to the depths of the squeeze perfs and the location of wedges for future CTD exit points. In both wells, we've moved the CTD kickoff points uphole to avoid placing a window in a casing collar, and the squeeze perfs are likewise being moved uphole by the same amount. Approved Squeeze Perfs New Squeeze Perfs Comment • 1 R-04: 3418'-3578' MD 3398'-3558' MD Moved 20' uphole (lower CTD exit point moved by same amount) • 1G-03: 3675'-3835' MD 3669'-3829' MD Moved 6' uphole (lower CTD exit point moved by same amount) Attached are updated operational summaries for both wells, with revisions shown in red font. Please let me know if you need any other information to help facilitate this request. << File: 1G-03 Ops Summary for Sundry - update 5-14-19.pdf >> << File: 1R-04 Ops Summary for Sundry - update 5-13- 19.pdf >> KRU 1G-03: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1G-03 (PTD 182-149) is a Kuparuk injector equipped with 3'/z" tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1G-03 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1G-03; a CTD permit to drill (10-401) will be submitted in the near future for 1G-03. The Kuparuk sand formation pressure in 1 G-03 is 3872 psi at 7700' MD, 6276' TVD, as measured on 8/22/18. For the plugging operations the maximum potential surface pressure is 3244 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1541 psi at 3368' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2358 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3500 psi • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi Kuparuk Sand Ptuaaina Operations 1. RU Slickline: a. MIT -IA to 2500 psi b. Pull frac sleeve across the SCSSV at 1815` KB i. Note: This frac sleeve has been in place since 1995 isolating a failed flapper on a SCSSV. The plugging operations given below are contingent on being able to pull this sleeve and drift through the SCSSV. ConocoPhillips will submit a revision to the plugging plan if the frac sleeve cannot be pulled or the SCSSV cannot be drifted. c. Drift tubing out the tubing tail at 7738' KB. 2. RU E -line: a. Tie in with CCL to tubing tally of 11/13/87. b. Set CIBP for 3%", 9.3 ppf tubing in the tubing tail at 7720' KB, in the middle of the 4.10' pup above the D -nipple, to isolate the A -sand perfs. c. Pump down the tubing. If fluids are not freely going into the C -sand perfs, punch holes into the 3'/2" tubing adjacent to the C -sand to allow injection into the perfs. d. Punch holes in the 3'/z" tubing at -7340' KB, above the upper production packer. Perf in the lower half of the full joint immediately above the packer to leave room for the cement retainer in the same joint. e. Bullhead 105 bbl diesel down IA to confirm that the tubing punches are clear to the perfs. Diesel will serve as an IA freeze protect fluid after cementing. i. 105 bbl = 4000' in the 7" x 3%" annulus Page 1 of 3 Updated 5/14/19 f. Set 3'/s" cement retainer at -7320' KB, below the GLM at 7303' KB but above the tubing punches. 3. RU Service Coil and cementing unit: a. RU to take returns off the IA and the tubing b. RIH with CT. Sting into cement retainer at 7320' KB and establish injection into C -sand perfs with seawater. Monitor IA pressure to establish a baseline injection pressure. c. Prepare to pump 15.8 ppg class G cement. i. This procedure calls for pumping a minimum of 35 bbl of cement to plug the IG -03 Kuparuk Sands completion, but we will blend cement on the fly in the event more cement is needed. d. Pump 15.8 ppg cement through the retainer into the C -sand perfs. Monitor pressure on IA continuously while pumping cement into the perfs. i. A minimum of 16 bbl of cement is expected just to fill the tubulars, but the intention is to pump sufficient cement to see at least a 300 psi increase in IA pressure. e. Once IA pressure has built to 300+ psi over baseline injection pressure, open up the IA to allow cement to enter the IA. Maintain 1:1 returns on the IA. Circulate a minimum of 14 bbl of 15.8 ppg cement into the IA, which is sufficient to place a 500' plug of cement in the IA. i. 500' of 15.8 ppg cement will add -175 psi hydrostatic pressure over diesel at the 1G-03 inclination of ±400. f. Sting out of the cement retainer and shut-in returns on the IA. Begin taking returns on the tubing. Lay in 5 bbl (minimum) of cement inside the 3.5" tubing, which is sufficient for a 500' plug of cement. g. Continue to POH while switching over to PowerVis to contaminate any leftover cement. Remain at 200' above calculated top of cement in the tubing until PowerVis turns the corner, and then POH while cleaning up any residual cement. 4. Slickline: a. After cement has had minimum of 24 hours to cure, RIH with slickline bailer. Tag top of cement. Pressure test cement plug to 2000 psi via tubing and IA separately. Provide 24-hour notice for the AOGCC to witness this operation. 5. E -line: a. RIH with jet cutter for 3Y2", 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±4800' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig Workover Operations to Set Up for CTD Sidetrack into the West Salk Formation Note: Well 1G -03's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at +: - KB, __ _.' TVD. 1. MIRU workover rig onto 1G-03. NU BOPE, test. 2. Pull old 3'/2" tubing down to the cut at ±4800' KB Page 2 of 3 3. MIRU a -line a. (optional) Run CBL from 4800' to surface to evaluate cement behind the 7" casing. Tie into the original CBL from 10-3-82 and look to see if there are any meaningful changes in the new log. b. Set CIBP for 7", 26# casing at ±4000' MD as abase for cement. C. RD a -line. 4. Nipple down BOPE and McEvoy Gen 3 tubing tubing head. Replace the old tubing head with a Cameron Gen 4 tubing head. Pressure test IC seals. NU BOP and retest as needed. 5. PU and TIH with ±160' of TCP guns (gun OD and shot density TBD). Tag COP to correlate depth for squeeze perfs 3669'--3829 MD (i.e. top of the N mudstone to mid West Sak D -sand). 6. Circulate hole full of ±9.0 ppg brine to overbalance anticipated formation pressure 7. Fire TCP guns. 8. Circulate bottoms up, confirming adequate overbalance to formation pressure. Adjust brine weight as needed. 9. TOH, laying down spent TCP guns. 10. PU and TIH with cup -style perf wash & cementing tool 11. Use cup -style wash tool to wash squeeze perfs 9', removing old mud, cuttings, and debris from between the 7" casing and the original 8%" borehole. 12. Prepare to pump 15.8 ppg class G cement. Use cup -style placement tool to ensure that cement is circulated through the perfs. a. Calculated annular volume between the 7" and the 8%" borehole is only 4.3 bbl for the 160' perforated interval, but be prepared to pump —24 bbl of cement (i.e. at least 2x the 8%" hole volume) to adequately squeeze this interval. 13. Pick up out of cement, circulate clean. 14. TOH, lay down cement squeeze assembly. 15. WOC as needed 16. PU drilling BHA with 6'/" mill tooth bit. Drill out cement down plus the upper CIBP at 4000' MD. Pressure test squeeze perfs to 14.2 ppg EMW (i.e. 0.74 psi/ft, or 920 psi at surface with 9.0 ppg brine in the hole). 17. MIRU a -line a. Run CBL across the squeeze interval to evaluate quality of the cement squeeze. 18. PU ±330' of 4'/i', 12.6 ppf, L-80 liner on -S liner packer. Liner will include two outer wedge assemblies spaced out for CTD exits at 3806' MD and11 -,7800' MD. TIH, space out 4'/z" liner, putting the outer wedges on depth and the ' "s liner -top packer within 200' MD of the deepest exit point (i.e. no shallower than ' MD). 19. Set liner hanger. Cement 4Y2" liner in place with 15.8 ppg Class G cement. Set packer, and pressure test IA. Circulate clean and TOH. 20. PU with 4Y" completion and TIH. Sting seals into sealbore and space out. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger. MIT -IA. Set BPV. 21. ND BOPE, NU 4-1/16" tree. RDMO. Page 3 of 3 Updated 5/14119 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Ty Senden Wells Supervisor ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU I G-03 Permit to Drill Number: 182-149 Sundry Number: 318-540 Dear Mr. Senden: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. o ogcc.o laska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Ca y H: Foerster Commissioner DATED this O day of February, 2019. RBDMS.1 FEB 1 12019 ECENED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION z/ g r / q/ J �-` APPLICATION FOR SUNDRY APPROVALS ` l 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑-' Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q 182-149 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-20824 ^00-00 7. If perforating: 8. Well Name and Number: ty g 68 What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1 G-03 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): w ADL 25640 1 Kuparuk River Field, Kuparuk River Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8489' 6951' 8371' 6848' 3244 n/a n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 16" 108' 108' 1640 670 Surface 2302' 10-3/4" 2302' 2218' 3580 2090 Intermediate Production 8464' 7" 8464' 6929' 4320 4980 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7495'-7825' MD (gross) 6104'-6380' (gross) 3-1/2", 9.2 ppf J-55 7739' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Camco TRDP-1A SCSSV, Baker HE packer SCSSV: 1804' MD, 1777' TVD. HB packer: 7355' MD, 5987' TVD 12. Attachments: Proposal Summary ✓ Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: 2/15/2019 P OIL WINJ WDSPL ❑ ❑ ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ty Senden Contact Name: James Hayes Authorized Title: WeKSupervispr Contact Email: James.C.Havesaconocophillips.com Contact Phone: 907-265-6927 fn1 Authorized Signature: Date:/ U COMIAISS16N USE ONLY Conditions of approval: Notify Comrllion so that a representative may witness Sundry Number: r ( O 1, ,�,/ Plug Integrity � BOP Test E] Mechanical Integrity Test LU Location Clearance ❑ Other: �/ Post Initial Injection MIT Req'd? Yes ❑ No L! Spacing Exception Required? Yes ❑ No Subsequent Form Required: b ,/ APPROVED BY / Approved by: `/'s"� COMMISSIONER THE COMMISSION Date: V7-7- 717 /1 ? � A M.S� FEB 1 11 F� Form and Form 10-403 Revised 4/2017 Approved application i I o 1 t r date f Attachments in Duplicate e1q,14 5 .1P.O.I-J418 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Applications (10-403s) to plug for re -drill the KRU 1G-03 (PTD# 182-149) and to perform workover operations to set the well up for CTD sidetrack in the West Sak formation. The plugging of the existing KRU 1G-03 completion in the Kuparuk Sands is in accordance with the requirements of 20 AAC 25.112(c)(1). Following plugging, workover operations will prepare 1G-03 for CTD sidetrack into the West Sak formation. Included in this workover summary is ConocoPhillips plans for achieving cement isolation behind the uncemented 7" casing adjacent to the West Sak formation. Later, a Permit to Drill (10-401) application will be submitted for the planned West Sak lateral to be drilled with Nabors CDR3-AC in mid -2019. Attached to the plugging application are the following documents: - 10403 Sundry Application for KRU 1G-03 - Operations Summary in support of the 10403 Sundry Application - Current well bore schematic - Proposed plugging schematic of the Kuparuk sands completion Attached to the workover application are the following documents: - 10-403 Sundry Application for KRU 1G-03 - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed post-workover schematic - Map of well penetrations in the West Sak formation within a quarter -mile of 1G-03 - Mechanical review of West Sak penetrations within a quarter -mile of 1G-03 If you have any questions or require additional information, please contact me at 907-263-4172. Sincerely, \G er flips Alas a Wells A&IIINk KUP INJ 1G-03 illi gle&BI TO Well Attributes MI Angle&MD t..aJl llllcT PJ AD F¢Ie same WeIIWreAPYWII WeYWres+atYs nclx IM1K81 Alaska, Inc,KUPARUK RIVER UNIT 500292082400 INJ 6.52 3,50000 8,489.0 CammeM IQS/Fpm) OXe - n t, OaIe K. -G. IX) RIB Rebase pale SSSV;TROP Laso WO'. 11/151198] 33.99 INS/1982 1.f .1a a:11. AM Last Tag Vm1-I M1emu,(..I) AnnotationEM DM OepM IXKBI IesI MW By Last Tag: FOR (Est, 13' of Filo &2312Di8 1,8120 zembaej Last Rev Reason INNCER; TaS Annotation EW Date IestMW ey Rea Reason: Updated Tag Depth 812MO18 umbeej Casing Strings caame11-r"ioo oDlml ID lint Top lnRR semePm(XKB) set Oepm(WO)... WV Len IL.. Gram IDp Thmaa CONDUCTOR 16 1535 30.0 108.0 108.0 65.00 H-00 WELDED n.ma D -option OD Bnl ID lln) Tap IXKBI SN DepN IXKB) set p!W IIv.1_. .11... GrWs Top Tbmtl SURFACE 10Y4 9.95 29.0 2,302.8 2,211 M.K-55 BTC Luing DescriptionOD (int ID lint Tro IXKBI 6e10epX, IXKB) SN Dean IIvul- When D...Glom Top ThmW PRODUCTION 7 638 27.5 8,4638 69288 26.00 K-55 BTC Tubing Strings T.1m, pcmlplbn shit M. It.(,.) Top IXKB) sed Depin M.. i set Oe soM1 ITVO) I...WIDNXI Gratle Top Connealbn TUBING 3112 2.99 245 1,739.2 6.308.4 9.20 J-55 BTCASMOD CONGL'CTOR; 3]AF1 M.0 6AFETy xLv;lmaa Completion Details sLFEVEIXV.> Top UVD) 'Pa. No -nal Top IXKB) (XKB) 1.1 Hem Du Cam 10th) 24.5 24.51 0.0] HANGER MCEVOY TUBING HANGER 3.500 1,803.6 1176.9 23.41 SAFETYVLV CAMCO TRDP-IA SAFETYVALVE(Fiappe, broke OX, frac sleeve 2.810 left iG well. See WEIR 823195) 7.340.3 5,974.6 33.33 PER BAKER PER 4.250 6uaPACE;SM13sa2e- 7,354.7 5.986.6 33.32 PACKER BAKER HB PACKER 2.890 1,48.9 6,107.4 32.83 BIASTJTS BLAST JOINTS( OAL=70.4') 3.000 6.292.5 3343 SEALASSY BAKER LOCATOR SEALASSEMBLY 2.98 GAS DET, 7..b 7,720.6 6,292.9 3343 PACKER BAKER FEET PACKER 4.000 ].]23.9 6,295.] 33.44 SBE BAKER8040S!ALBOREE)RENSION 4.000 7. 32.9 6,303.2 3346 NIPPLE CAMCODNIPPLENO GO 2.750 P. 1.340.3 7,7384 6,3078 3368 SOS CAMCO BH EAR OUT SUB ELMD TTL 726 dpa,ut,ROP pn 3.015 051141200] PAG"ER" 7 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) To=Ift Top Iota Top IXKOJ rylKGl Com RYn Osie ID I"a 1,803.7 11]7.0 2342 SLEEVE FRAC SLEEVE 812311995 2.33 INJECTION; 7X3,4 Perforations & Slots SM1W Den IwEcnpx:7K1.e 6 ToBan ITVDI IanoIH Top IXK61 Bim gtog IXKBI IXKH) (XKH) Llnkel Zone Dah ) Type Com 7.495.0 J, 525.0 6,104.1 6.129.3 C-3. 1G03 8291984 12.0 /PERF 0.0 7,563.0 6,141.9 6,161.2 C-. G-03 829 2.0 /PERF 7,77.0 7,8250 6,335.8 6.379.9 Ad, M3. 1G-03 W291984 12.0 /PERF 141Bsn1%15.0- Mandrel Inserts n N Tap W, an T(Me)) Melee MWel 013gre SM Typee palm Pa(m) TRO Run Run DM Cam 7,294.3 5,936.2 OTIS LBX 112 GAS LIFT DW T-2 0.000 0.0 1112311987 /PERP; 7,540o-754do- 2 7,392.0 6,017.8 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 111191931 Clpse d 3 7,461.9 6,076.3 CAMCO KBUG 1 INJ OMY SK 0.000 00 NM1993 Close d 4 7,670.1 6,250.] CAMCO KBUG 1 INJ DMV 6K 0.000 0.0 1011711993 Close d Iw6cnpx; 7,fi7a+ Notes: General & Safety EW Dale Annambn 4)242003 NOTE E -LINE FOUND CSAND LEAK @1579' 9)152010 NOTE; View SCKemaHC W Alaska SThema1iC90 SFAL As6Y:]TA.1 PACKER', 7,77.6 sBE. ITA9 MPPLE;].7329 ma 7.TYA .PEttF7,773.0.7,92a.- PROOVCTION,la584638 1G -03i Present Well Condition 116!'65# H40 shoe Q 108' MD shoe @ 2303' MD, Arctic Pack cement ^2100'-2500'via CBL 10- 3-82 (RA tracer) CP C -sand 7495'-7525' MD C -sand 754(Y-7563' MD -sand 7772'-7825' MD 7" 2611 K-55 shoe 8463' MD Top of good quality cement behind the 7" at ^7380' (CBL of 8-21- 84) V(ID =2.813") Frac sleeve, 2.313" ID, 11995 Retrievable777 L8X mandrel at 7294' ar HB packer at 7355' ico KBUG injection man )92'.7462', & 787(Y r FB -1 packer at 7721' pple (2.75" ID) at 7733' tail at 7739' 1G -03i Kuparuk P&A Proposal CTD KOP 3812' MD, 327GIr— SSTVD, 43 deg inc sand perfs (2) Open mandrels and/or tog ` punches adjacent to C -sand Ads (3) Open mandrel or tbg punch \ above lop packer (4) Cmt retainer set above tap ;r bg punch t - L4:Yu (5) Cmt bullheaded thin reamer into C -sand parts I(6) Cmt circulated up IA above stop packer ,(7) Cml on top of retainer in 3- 112"tbg �(8) Tubrtm cut above TOC at KRU 1G-03: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1G-03 (PTD 182-149) is a Kuparuk injector equipped with 3'/" tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1G-03 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1G-03; a CTD permit to drill (10-401) will be submitted in the near future for 1G-03. The Kuparuk sand formation pressure in 1G-03 is 3872 psi at 7700' MD, 6276' TVD, as measured on 8/22/18. For the plugging operations the maximum potential surface pressure is 3244 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1541 psi at 3368' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2358 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3500 psi • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi I-CpgLur. �2r C_) i4sf well- iS yIo %oyer Kuparuk Sand Plugging Operations�Qeo%a/ to �/�ps r �(,e Oftscr �Gt%cs/S' f0 �1uyfi�' TO wtN 70 1PAr, l/ "A i 4ip W ff � � fliOr(/e 1. RU Slickline: ,'M� oVrd corrry f2 p1 /10- -tor fe r elf a. MIT -IA to 2500 psi I/! b. Pull frac sleeve across the SCSSV at 1815' KB i. Note: This frac sleeve has been in place since 1995 isolating a failed ✓ Flapper on a SCSSV. The plugging operations given below are contingent on being able to pull this sleeve and drift through the SCSSV. ConocoPhillips will submit a revision to the plugging plan if the frac sleeve cannot be pulled or the SCSSV cannot be drifted. c. Drift tubing out the tubing tail at 7738' KB. 2. RU E -line: a. Tie in with CCL to tubing tally of 11/13/87. b. Set CIBP for 3^^/", 9.3 ppf tubing in the tubing tail at 7720' KB, in the middle of the 4.10' pup above the D -nipple, to isolate the A -sand perfs. c. Pump down the tubing. If fluids are not freely going into the C -sand perfs, punch holes into the 3'/�" tubing adjacent to the C -sand to allow injection into the perfs. d. Punch holes in the 3^^/z" tubing at —7340' KB, above the upper production packer. Perf in the lower half of the full joint immediately above the packer to leave room for the cement retainer in the same joint. e. Bullhead 105 bbl diesel down IA to confirm that the tubing punches are clear to the perfs. Diesel will serve as an IA freeze protect fluid after cementing. i. 105 bbl = 4000' in the 7" x 3'h" annulus Page 1 of 3 11/15/2018 Fwd V'�J )�G'�-) /vX f. Set 3'/i' cement retainer at -7320' KB, below the GLM at 7303' KB but above the tubing punches. 3. RU Service Coil and cementing unit: a. RU to take returns off the IA and the tubing b. RIH with CT. Sting into cement retainer at 7320' KB and establish injection into C -sand perfs with seawater. Monitor IA pressure to establish a baseline injection pressure. c. Prepare to pump 15.8 ppg class G cement. i. This procedure calls for pumping a minimum of 35 bbl of cement to plug the 1 G-03 Kuparuk Sands completion, but we will blend cement on the fly in the event more cement is needed. d. Pump 15.8 ppg cement through the retainer into the C -sand perfs. Monitor pressure on IA continuously while pumping cement into the perfs. i. A minimum of 16 bbl of cement is expected just to fill the tubulars, but the intention is to pump sufficient cement to see at least a 300 psi increase in IA pressure. e. Once IA pressure has built to 300+ psi over baseline injection pressure, open up the IA to allow cement to enter the IA. Maintain 1:1 returns on the IA. Circulate a minimum of 14 bbl of 15.8 ppg cement into the IA, which is sufficient to place a 500' plug of cement in the IA. i. 500' of 15.8 ppg cement will add -175 psi hydrostatic pressure over diesel at the 1G-03 inclination of ±400 . f. Sting out of the cement retainer and shut-in returns on the IA. Begin taking returns on the tubing. Lay in 5 bbl (minimum) of cement inside the 3.5" tubing, which is sufficient for a 500' plug of cement. g. Continue to POH while switching over to PowerVis to contaminate any leftover cement. Remain at 200' above calculated top of cement in the tubing until PowerVis turns the corner, and then POH while cleaning up any residual cement. 4. Slickline: a. After cement has had minimum of 24 hours to cure, RIH with slickline bailer. Tag top of cement. Pressure test cement plug to 2000 psi via tubing and IA separately. Provide 24-hour notice for the AOGCC to witness this operation. 5. E -line: a. RIH with jet cutter for 3%', 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±4800' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig Norkover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1 G -03's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at 3812' KB, 3368' TVD. 1. MIRU workover rig onto 1G-03. NU BOPE, test. 2. Pull old 3'/:" tubing down to the cut at ±4800' KB Page 2 of 3 11/15/2018 3. MIRU e -line a. (optional) Run CBL from -4800' to surface to evaluate cement behind the 7" casing. Tie into the original CBL from 10-3-82 and look to see if there are any meaningful changes in the new log. b. Set CIBP for 7", 26# casing at ±4000' MD as abase for cement. RDe-line. 4. Nipple down BOPE and McEvoy Gen 3 tubing tubing head. Replace the old tubing head with a Cameron Gen 4 tubing head. Pressure test IC seals. NU BOP and retest as needed. 5. PU and TIH with ±160' of TCP guns (gun OD and shot density TBD). Tag CIBP to correlate depth for squeeze perfs 3675'-3835' MD (i.e. top of the N mudstone to mid West Sak D -sand). 6. Circulate hole full of ±9.0 ppg brine to overbalance anticipated formation pressure 7. Fire TCP guns. 8. Circulate bottoms up, confirming adequate overbalance to formation pressure. Adjust brine weight as needed. 9. TOH, laying down spent TCP guns. 10. PU and TIH with cup -style perf wash & cementing tool 11. Use cup -style wash tool to wash squeeze perfs 3675'-3835', removing old mud, cuttings, and debris from between the 7" casing and the original 8%" borehole. 12. Prepare to pump 15.8 ppg class G cement. Use cup -style placement tool to ensure that cement is circulated through the perfs. a. Calculated annular volume between the 7" and the 8a/," borehole is only 4.3 bbl for the 160' perforated interval, but be prepared to pump -24 bbl of cement (i.e. at least 2x the 8%" hole volume) to adequately squeeze this interval. 13. Pick up out of cement, circulate clean. 14. TOH, lay down cement squeeze assembly. 15. WOC as needed 16. PU drilling BHA with 6%a" mill tooth bit. Drill out cement down to bridge plug at 4000' MD. Pressure test squeeze perfs to 14.2 ppg EMW (i.e. 0.74 psi/ft, or 920 psi at surface with 9.0 ppg brine in the hole). 17. MIRU e -line a. Run CBL across the squeeze interval to evaluate quality of the cement squeeze. 18. PU ±330' of 4'/", 12.6 ppf, L-80 liner on ZXP liner hanger/packer. Liner will include two outer wedge assemblies spaced out for CTD exits at 3812' MD and 3782' MD. TIH, space out 4'/" liner, putting the outer wedges on depth and the ZXP liner -top packer within 200' MD of the deepest exit point (i.e. no shallower than 3612' MD). 19. Set liner hanger. Cement 4'/i' liner in place with 15.8 ppg Class G cement. Set ZXP packer, and pressure test IA. Circulate clean and TOH. 20. PU with 4%" completion and TIH. Sting seals into sealbore and space out. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger. MIT -IA. Set BPV. 21. ND BOPE, NU 4-1/16" tree. RDMO. Page 3 of 3 11/15/2018 Roby, David S (DOA) From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Thursday, December 13, 2018 12:45 PM To: Roby, David S (DOA) Cc: Loepp, Victoria T (DOA); Boyer, David L (DOA); Wallace, Chris D (DOA) Subject: RE: [EXTERNAL]Sundry application for KRU 1g-03 (PTD 182-149) plug for redrill Yes that is correct this well will no longer support those wells Thanks, James Hayes C: +1918.914.9609 From: Roby, David S (DOA) <dave.roby@alaska.gov> Sent: Thursday, December 13, 2018 12:39 PM To: Hayes, James C <James.C.Hayes@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]Sundry application for KRU 1g-03 (PTD 182-149) plug for redrill James, So in summary, the offset producer(s) supported by this injection well are no longer viable/receiving any benefit from continued injection so there's no need to keep this well online as a Kuparuk injector. Correct? Dave Roby 907-793-1232 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Dave Roby at 907- 793-1232 or dave.robv@alaska.eov. From: Hayes, James C <James.C.Haves@conocophillips.com> Sent: Thursday, December 13, 2018 12:34 PM To: Roby, David S (DOA) <dave.robv@alaska.aov> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.Rov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]Sundry application for KRU Ig -03 (PTD 182-149) plug for redrill Roby. I apologize I completely missed this email. We have quite a few wells in Kuparuk that are no longer producing what we feel is necessary. So the injector portion of this well in the Kuparuk will be MAU We do not have any plans on replacing this well in this are with another injector. The goal of this well and 3 others is to penetrate the Wes Sak in a relatively virgin area. We are attempting to coil farther than we ever had to prove that it can be done. There are many other wells like these that we have, which could be possible candidates for more of these sidetracks. All of which have similar complications of lack of TOC and deep set surface pipe. Does this answer all of your questions? Thanks, James Hayes C: +1918.914.9609 From: Roby, David S (DOA) <dave.roby@alaska.gov> Sent: Wednesday, December 5, 2018 4:17 PM To: Hayes, James C <James.C.Haves@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Boyer, David L (DOA) <david. bover2@alaska.eov>; Wallace, Chris D (DOA) <chris.wallace@alaska.eov> Subject: [EXTERNAL]Sundry application for KRU 1g-03 (PTD 182-149) plug for redrill James. In reviewing the subject sundry application for conservation of resources purposes I have a few questions for you. The subject well is an active injector in the Kuparuk River Oil Pool, why has this well been chosen for redrilling into the West Sak? Is it no longer needed as an injector? Has, or will, its injection role be replaced by another well? Another reason? Thanks in advance. Regards, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 CONFIDEN77ALITYN07ICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Dave Roby at 907- 793-1232 or dave.robv@alaska.eov. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Brian Buck Workover Supervisor ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1 G-03 Permit to Drill Number: 182-149 Sundry Number: 318-536 Dear Mr. Buck: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Ca y7. Foerster Commissioner DATED this 0 day of February, 2019. RBDMS=L- FEB 1 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O 20 AAC 25.280 FISC'EiVE® DEC 0z� 2018 AOG Co�'S 1. Type of Request: Abandon ❑ Plug Perforations VIV Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑� Other Stimulate E] Pull Tubing ❑✓ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑� Re-enter Susp Well Alter Casing ❑ Other: -El- 2. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q 182-149 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-20824 -00 -OU 7. If perforating: 8. Well Name and Number:.P.15, What Regulation or Conservation Order governs well spacing in this pool? CO 4068 KRU 1 G-03 Will planned perforations require a spacing exception? Yes ❑ No Q 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25640 4 1 Ku aruk River Field, West Sak Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8489' 6951' 4800 4066 2358 cement to 6820' MD cut tbg 4800' MD Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 16" 108' 108' 1640 670 Surface 2302' 10-3/4" 2302' 2218' 3580 2090 Intermediate Production 8464' 7" 8464' 6929' 1 4320 4980 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7495'-7825' MD (gross, sgz'd) 6104'-6380' (gross, sgz'd) 3-1/2", 9.2 ppf J-55 7739' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Carrico TRDP-1A SCSSV, Baker HB packer SCSSV: 1804' MD, 1777' TVD. HB packer: 7355' MD, 5987' TVD 12. Attachments: Proposal Summary Wellbore schematic 1r1 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q 14. Estimated Date for 15. Well Status after proposed work: V-r"- Commencin Operations: 3/1/2019 9 p OIL WINJ WDSPL u ❑ '� ❑ Suspended GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Brian Buck Contact Name: James Hayes Authorized Title: Workover Supervisor Contact Email: James. C. HavesoconocophiI l ips.com Contact Phone: 907-265-6927 Authorized Signature: �'-'�` -�"�" Date: /Z I LO18� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -hV Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: r.2 ft 5-"- -/-c, 300 O p 5 1 U s 1 ljtvnvlaI/ Pv-le,✓Ch $tv Post Initial Injection MIT Req'd? Yes ❑ No Er Spacing Exception Required? Yes ❑ No d Subsequent Form Required: APPROVED BY Q — Approved by: �+-- COMMISSIONER THE COMMISSION Date: RBDMS FED 2019 pL Forth 10-403 Revised 4/2017 Approved 2a PPIiC/ai 4 f r GA AL date of approval. Submit Form and Attach ensin Duplicate f>f WS B WS U WS_C v u WS D WS_ O NS—D F1 ConocoPhillips Alaska Well 1G-03 Top West Sak Pick and Quartermile Buffer h Nearby Wells' OWw West Sak Picks N ' 11/26/2018 \°8 A WS U 0 INS Al 1G WS C WS — D WS_D 0 Top West Sak in 1 G-03 • ON West Sak Picks 13,03 Well Tract — Active Plugged and Abandoned O 13,03 Top WS Quarlermae Buller i� CPAI Lease 0.1 0.2 oMiles KRU IG -03 Workover Setup for West Sak Injection Quarter -Mile Review surface Top of D- surface Surf.. Well theme PTD API Wall Well status Top of O -sand sand Oil Pool CMint Set Gsint Set falling Set Cement Opermlons Summary Mechanical Integrityfl.'"a tion Oil Pool (MD) OVD) WPM IMDI Depth (NO) perms Wes[ Sak? lot/.••.. l.m u PID ee0 m N�nl n1 ow x,aww,.w�wl°ns.T wrer.coe. x 1401 TBTIN 4Wz In�ealer m�M 6 l.'/61 THI 1. 1i16 intsF l°ban'YT .. w °3WlpI w,+Ml l'1SY w reapnw�wn. ili- IT1.5. 1°Lm R: WisM11 zSY .v1: I..oswOols"I YsnN I— 1.1 WAotlileq r, -[td 1406 INrzm T4 Inµq°r Inlmlry ..wl I.NT Y1Y ;Im FSYF aa'repbno[meml° ��°owle:llliwvlal Yn ,ve yn/Y ttA°� ,m IT,TvupswA°16a Inlo Tmow:a• ua ye/u va/••nmm.dw.uT...Nl.,en50v lou vslu oaY vmT Lym°. nsl am . nY Twz nm Fuse °Tlse oppw uamue— m:a mlp°iw. rel u.euM. wa•x=zYwremm�vren,[=. x6 [°lemw�m,.alvw T.sh-lsexxlFd w>wTlNa.nwd xox l4v zNa6z oannms .ma,w w°e°[,n 1o4 TaN un 11vuF IYwn.re. o- ree hilum ml 1G -03i Workover Setup 4%" completion in preparation for CTD sidetrack CTD KOP 3812' MD, 3279' SSTVD, 43° inc West Sak formation (top "'3200' TVD) PWC squeeze perfs: 3675'-3835' KB (160') Following squeeze, drill out & log, run 4.5", 12.6 ppf, L-80 liner cemented in place with ZXP packer @ —3620' KB. Shoe of liner at —3950' KB. Includes two wedge assemblies integral to the liner. KRU 1G-03: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1G-03 (PTD 182-149) is a Kuparuk injector equipped with 3'/" tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1G-03 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1 G-03; a CTD permit to drill (10-401) will be submitted in the near future for 1 G-03. The Kuparuk sand formation pressure in 1G-03 is 3872 psi at 7700' MD, 6276' TVD, as measured on 8/22/18. For the plugging operations the maximum potential surface pressure is 3244 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1541 psi at 3368' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2358 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3500 psi • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi Kuparuk Sand Plugging Operations 1. RU Slicklirle: a. MITiive si b. Pull cross the SCSSV at 1815' KB is frac sleeve has been in place since 1995 isolating a failed n a SCSSV. The plugging operations given below are nt on being able to pull this sleeve and drift through the ConocoPhillips will submit a revision to the plugging plan if /p l ve cannot be pulled or the SCSSV cannot be drifted. c. Drift tubing out the ting tail at 7738' KB. 2. RU E -line: Page 1 of 3 a. Tie in with CCL to tubing t of 11/13/87. b. Set CIBP for 3'/", 9.3 ppf tubi in the tubing tail at 7720' KB, in the middle of the 4.10' pup above the D-nipp , to isolate the A -sand perfs. c. Pump down the tubing. If fluids a not freely going into the C -sand perfs, punch holes into the 3Y:" tubing adt\thesa e C -sand to allow injection into the perfs. d. Punch holes in the 3Yd' tubing at —bove the upper production packer. Perf in the lower half of themmediately above the packer to leave room for the cement retainer a joint. e. Bullhead 105 bbl diesel down IA to confirm th to the perfs. Diesel will serve as an IA freeze i. 105 bbl = 4000' in the 7" x 3Y2" annulus tubing punches are clear of fluid after cementing. 11/15/2018 f. Set 3'/" cement retainer at -7320' KB, below the GLM at 7303' KB but above the tubing punches. 3. RU Service Coil and cementing unit: a. RU to take returns off the IA and the tubing b. RIH with CT. Sting into cement retainer at 7320' KB and establish injection into, C -sand perfs with seawater. Monitor IA pressure to establish a baseline inje4tion pressure. c. Prepore to pump 15.8 ppg class G cement. f. Sting out of the cement ret0 returns on the tubing. Lay i 5 tubing, which is sufficient for g. Continue to POH while switchi leftover cement. Remain at 20 until PowerVis turns the corner, cement. 4. Slickline: r and shut-in returns on the IA. Begin taking bbl (minimum) of cement inside the 3.5" 500' plug of cement. n0 over to PowerVis to contaminate any 0' bove calculated top of cement in the tubing an then POH while cleaning up any residual a. After cement has had minimum of 24 hou to cure, RIH with slickline bailer. Tag top of cement. Pressure test cement p g to 2000 psi via tubing and IA separately. Provide 24-hour notice for the A GCC to witness this operation. 5. E -line: a. RIH with jet cutter for 3%", 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±4800' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig WorkoverWorkover Operations to Set Up CTD Sidetrack into the West Salk Formation Set Uo for CTD Sidetrack into the West Sak Formation Note: Well 1 G -03's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at 3812' KB, 3368' TVD. 1. MIRU workover rig onto 1G-03. NU BOPE, test. 2. Pull old 3'/" tubing down to the cut at ±4800' KB Page 2 of 3 11/15/2018 L \This procedure calls for pumping a minimum of 35 bbl of cement to lug the 1G-03 Kuparuk Sands completion, but we will blend cement o the fly in the event more cement is needed. cement through the retainer into the C -sand perfs. Monitor d. Pump 15.\minimum pressure continuously while pumping cement into the perfs. i. Aum of 16 bbl of cement is expected just to fill the tubulars, but thtion is to pump sufficient cement to see at least a 300 psi inin IA pressure. e. Once IA pr has built to 300+ psi over baseline injection pressure, open up the IA w ment to enter the IA. Maintain 1:1 returns on the IA. Circulate imum f 14 bbl of 15.8 ppg cement into the IA, which is ' sufficient ce a 5 plug of cement in the IA. L 505.8 ppg ement will add -175 psi hydrostatic pressure over dithe 1 G-0 inclination of ±40°. f. Sting out of the cement ret0 returns on the tubing. Lay i 5 tubing, which is sufficient for g. Continue to POH while switchi leftover cement. Remain at 20 until PowerVis turns the corner, cement. 4. Slickline: r and shut-in returns on the IA. Begin taking bbl (minimum) of cement inside the 3.5" 500' plug of cement. n0 over to PowerVis to contaminate any 0' bove calculated top of cement in the tubing an then POH while cleaning up any residual a. After cement has had minimum of 24 hou to cure, RIH with slickline bailer. Tag top of cement. Pressure test cement p g to 2000 psi via tubing and IA separately. Provide 24-hour notice for the A GCC to witness this operation. 5. E -line: a. RIH with jet cutter for 3%", 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±4800' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig WorkoverWorkover Operations to Set Up CTD Sidetrack into the West Salk Formation Set Uo for CTD Sidetrack into the West Sak Formation Note: Well 1 G -03's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at 3812' KB, 3368' TVD. 1. MIRU workover rig onto 1G-03. NU BOPE, test. 2. Pull old 3'/" tubing down to the cut at ±4800' KB Page 2 of 3 11/15/2018 3. MIRU a -line a. (optional) Run CBL from -4800' to surface to evaluate cement behind the 7" casing. Tie into the original CBL from 10-3-82 and look to see if there are any meaningful changes in the new log. b. Set CIBP for T', 26# casing at ±4000' MD as a base for cement. RD a -line. 4. Nipple down BOPE and McEvoy Gen 3 tubing tubing head. Replace the old tubing head with a Cameron Gen 4 tubing head. Pressure test IC seals. NU BOP and retest as needed. 5. PU and TIH with ±160' of TCP guns (gun OD and shot density TBD). Tag CIBP to correlate depth for squeeze perfs 3675'-3835' MD (i.e. top of the N mudstone to mid West Sak D -sand). 6. Circulate hole full of ±9.0 ppg brine to overbalance anticipated formation pressure 7. Fire TCP guns. per F 8. Circulate bottoms up, confirming adequate overbalance to formation pressure. Adjust brine weight as needed. 9. TOH, laying down spent TCP guns. 10. PU and TIH with cup -style perf wash & cementing tool 11. Use cup -style wash tool to wash squeeze perfs 3675'-3835', removing old mud, cuttings, and debris from between the 7" casing and the original 8%" borehole. 12. Prepare to pump15.8�cllaass G cement. Use cup -style placement tool to ensure that cementis circulated lated through the perfs. a. Calculated annular volume between the T' and the 8%" borehole is only 4.3 bbl for the 160' perforated interval, but be prepared to pump -24 bbl of cement (i.e. at least 2x the 8%" hole volume) to adequately squeeze this interval. 13. Pick up out of cement, circulate clean. 14. TOH, lay down cement squeeze assembly. 15. WOC as needed 16. PU drilling BHA with 6'/e" mill tooth bit. Drill out cement down to bridge plug at 4000' MD. Pressure test squeeze perfs to 14.2 ppg EMW (i.e. 0.74 psi/ft, or 920 psi at surface with 9.0 ppg brine in the hole). 17. MIRU a -line a. Run CBL across the squeeze interval to evaluate quality of the cement squeeze. 18. PU ±330' of 4'/z", 12.6 ppf, L-80 liner on ZXP liner hanger/packer. Liner will include two outer wedge assemblies spaced out for CTD exits at 3812' MD and 3782' MD. TIH, space out 4'/:" liner, putting the outer wedges on depth and the ZXP liner -top packer within 200' MD of the deepest exit point (i.e. no shallower than 3612' MD). 19. Set liner hanger. Cement 4'/" liner in place with 15.8 ppg Class G cement. Set ZXP packer, and pressure test IA. Circulate clean and TOH. 20. PU with 4%" completion and TIH. Sting seals into sealbore and space out. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger. MIT -IA. Set BPV. 21. ND BOPE, NU 4-1/16" tree. RDMO. Page 3 of 3 11/15/2018 KRU 1G-03 Workover Setup for West Sak Injection Quarter -Mile Review surface Top of D- Top of D- Surface Surface Surface Casing set Surface Casing Cement Arctic Pack Well PTD. API We" classification Well Status sand Oil Pool sand Oil Casing Set Casing Set Casing Set Across West Operations Summary Cement Ops Mechanical Integrity Name (MD) Paol (TVD) Depth(MD) Depth (TV0) AcrossOgnu2 Sak? WI/r: Ino SK w79 bal of W133.] 00..41 ttl/U.M]bbl tlleul, lo/3/b),MVxer aoYAYWFu M^Y tY3(0]Pol pauM 1Y25 Is ppBleaE.ESbu(<i bM1eI13.Jng)FL a®l'<3bb1=MPlncg M^QOto 38:A pL Paautl 313S1a IGL3 Sfl]-149 SUOn3dEiG0 InkLtn InpLtMg 3,>n 3.3nG 2,M3 ;)]G ull. WMre ,fftlrelob. Gu 393u OL~ oxer LemmtbaMfau. Narcr3pwtlert Fn=amull. -3Im35N'Mo. 325 pq FMW. 163/4": 13U]u1445 IN) ofoslol 12.2 00:41 hhl .IftBM l/ID/l3.ttMl= WAMEMD WE P. In MnM to l9W pL paxM 3(B/IB ppakatl.=nf(41bbl)alli)rgpF{tlluH, W In M{ann.i. MnlA t09CW plpxutl 3/8)38 1646 10)-3N 508i3109)dU Inleflor Mlectlry 4,N3 3.343 2..;150 rntEE II. hftlno Y1nFM91rcleb..o . bV) of 15.7 Mtepl(Es:l .(25141 bM1 of 15.)p{g. W pl l5ossp5WM 15.1 pe& Frt+¢.S pog CM. W:NMLmt lbbl MWnm WFLLHueuilax 10.3/4': 3030ue(PFE IEApghad♦ tllexL l,il/B/A3. WSObbl=Mrt-Yto 35Mpl paauE 12MR/18 3W uoF 15.6pp{PFttall. GwtlLeeum ]MYln a{Mm:MI.30a Mn -0A to lBNpy paasrlf3/)/]8 1G-16 189.155 360Hi1o3120 Inittto� L)n 4.154 3,333 3,fi42 3,]50 1Altf entluleb, Hui356N LementtewHan. bN+EW 1'. 01.0 ows Ho«dpeLalkn. Fn-..' EMW. <[<LlkMhwda50'- )3/8':35]LLJol10.]PpBketl. ]G bNM No remN O.W. 1G-1) 393683 SOOHENNSUO TWuur :.Mns q5M 3, 363 4,38] 3.933 M E MUf 158 ppgM0. 89 EbIxmeMto FYLfare. MRQ1to 3YA psipuetl l]/19/03 Ep}s 151 EMW. EMn-IAtei S e013 ] IG -03i Present Well Condition (generic) West Sak formation (top `3200' ND) West Sal, adjacent to uncemented 7". a hd Peds KKxx' MD 286 J45 shoe xKXx' MD No CBL across 9-5/8", but it's >1000' above the West Sak. FIT to 12.5 Fog Arctic Pack cement is above the West Sak formation. 7" CBIS confine it spans the surface shoe. 7" cement extends above the Kuparuk sands which will be abandoned. COLS in all. 1G -03i (injector) Workover Prep 43s" completion in prep for CTD sidetrack Kuparuk intervals P&A'd esh-Cement of 7" annulus ervall d by 4-1/2' ed Omer. Liner awoouter forfuture CTD JL 1G -03i (injector) CTD Sidetrack CTD completion: 219" slotted liner in 4.25" ID hole - CTD window exit (2- stdng) exit near the top of the WSak sands. • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission �,'� DATE: Thursday,August 13,2015 TO: Jim Regg mac,. 5113/is P.I.Supervisor f SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1G-03 FROM: Jeff Jones KUPARUK RIV UNIT 1G-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -Teg - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1G-03 API Well Number 50-029-20824-00-00 Inspector Name: Jeff Jones Permit Number: 182-149-0 Inspection Date: 7/7/2015 Insp Num: mitJJ150813091751 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1G-03 Type Inj W"TVD 5992 Tubing 2200 • 2200 • 2200 2200 PTD 1821490 Type Test SPT Test psi 1500 IA 670 3000 • 2880 2860 Interval 4YRTST P/F P ✓ OA 460 - 600 - 620 " 610 • Notes: I well inspected,no exceptions noted. SOWED Thursday,August 13,2015 Page 1 of 1 P7 /t' z 1410 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Wednesday, January 25, 2012 10:54 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk MIT's performed on 01 -21 -12 Attachments: MIT KRU 2L -305 01- 21- 12.xls; MIT KRU 1G -02, 03 01- 21- 12.xls All, Attached are the MIT forms for the Kuparuk MIT's that were performed on 01/21/12. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 ar ` FE ZWL • # STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq @alaska.aov; doa. aoacc.orudhoe.bavCcaalaska.gov: phoebe.brooks @alaska.gov: tom.maunder @alaska.aov OPERATOR: ConocoPhillips Inc. 'czyq I i 7 la/ FIELD / UNIT / PAD: Kuparuk / KRU / 1G pad DATE: 01/21/12 OPERATOR REP: Ives /Jensen /Bybee AOGCC REP: Packer Death Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1G -02 MI W TVD 5,882 Tubin• 1,060 1,060 1,060 1,060 1,060 Interval 4 P.T.D. 1821380 IME P 111M1 1500 LJ 388 2,535 2,515 2,500 2,496 _ P/F P Notes: Waived right to witness by John Crisp OA 240 380 380 380 380 Well ' 1G -03 INEI W - TVD ' 5,987' Tubin• 1,350 1,350 1,350 1,350 4 P.T.D. ' 1821490 EMI P M 1500 518 '2,500 2,396 '2,378 P/F P Notes: Waived right to witness by John Crisp OA 550 620 620 620 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test, Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT KRU 1G -02 03 01 -21 -12 MEMORANDUM '\) 1/'7D/07 ;\~eif . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Friday, July 20,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC FROM: Bob Noble Petroleum Inspector IG-03 KUPARUK RIV UNIT IG-03 \ 'D;}- \ ~q Src: Inspector Reviewed By: P.I. Suprv , ~\Et-- ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IG-03 API Well Number: 50-029-20824-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070714192225 Permit Number: 182-149-0 Inspection Date: 7/14/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. / Well : IG-03 IType Inj. i w TVD I 5992 ~ IA i 610 I 2820 2760 2750 ì i ¡ I I P.T.DI 1821490 iTypeTest i SPT Test psi i 2820 {OA i 210 340 ! 340 340 1 I I I i Tubing! i I Interval 4YRTST P/F P ...,/ 2275 I 2275 i 2275 2275 I I Notes: ¡'vÌVte : Pc:tCl~r- Ì)epti..,\ LT\lD) c~..Lc'<.J2ks f)1'7tß í fe~b,¡-{- Li D'-4òì) avvl D¡ rechc~£L S..~v;~1 -kç+ P,~Ç,S(A,'~ ò Ie- ~ \í\Je~l CðW P\eh~ SCANN6J ~UG () ß 2007 Friday, July 20,2007 Page I of I 06/08/07 Schlumbepgel' NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 ], 2001 GOI1~.(:orí¡m¡rg'eANNe.D JUN 1 4 2007 \ Cl:; 'J.~ \ q- q Kuparuk ~v Field: Well Job# Log Description BL Color CD Date 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V-OBA 11629013 PM IT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-O 1 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y-11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1F-08 11665435 SBHP SURVEY OS/20/07 1 1 J-170 11632709 INJECTION PROFILE OS/24/07 1 10-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU/1G 07/04/03 Arend/Brake - APC John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Wo,,I,G-02 I TypelnjI Sp I T.V.D. 15883 I Tubing I 8001 8001 8001 8001 Interval P.T.D. I1821380 TypeTest Test psiI 1500 I Casing I 12801 22501 22501 22601 P/F Notes: OA 720 780 780 780 P.T.D.,I1821490 ITypeTest TestpsiI 1500 I Casing I 15801 31801 31401 31201 P/F Notes: OA 860 980 980 980 Well I1G-09 P.T.D. 11831240 Notes: Type Test TestpsiI 1572 I Casing I 4251 20501 20001 20001 P/F OA 0 0 0 0 we"ll6'14Ie "il s I T.V.D. I 61471Tubingl 10301 10301 10301 ~030IInterval P.T.D..I1831410 Type TestI P I Testpsil 1537 I Casingl 19001 26601 2660126601 P/F Notes: OA 1000 t040 1040 1040 P.T.D.I1831550 Type Test TestpsiI 1527 I Casing I 15201 23601 23601 23601 P/F Notes: OA 350 400 400 400 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0704_M IT._K RU_I G-16.xls 7/1 1/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: P.I. Supervisor FROM- John Crisp Petroleum Inspector DATE: July 4, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 1G Pad Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I le-O2 IType,,j.I s I T.V.D. I~ I Tubingl 775 I 800 1800 I 800 Ilntervall 4 P.T.D.I 1821380ITypetestl P ITestpsil 2000 I CasingI 1280I 2250 I 2250I 2260I P/F I P Notes: Pretest OA psi. 720 OA psi. during test 780 1BBL pumped for test I ITyp ,,j.[sI T.V.D. 15992 I Tu i. l=sooI= oo I I= oo[Interval[ 4 P.T.D.I 1821490ITypetestl P ITestpsil 2000 I Casingl 1700131801314013120I P/F I P Notes: Pretest OA psi. 880 OA psi. during test 980 2BBL pumped for test We,,I le-09 [Type,nj.I e I T.V.D. I~=~ [T. bing[ 2525 [2525 I=~=~ I=~=~ [,.terva,[ 4 P.T.D.I 1831240 [TypetestI P ITestpsil 2000 [Casing[ 425 [ 2050 [ 2000 [ 2000 [ P/F I P Notes: Pretest OA psi. & psi. during test was 0 4 BBL pumped WellI 16-14 ITypelnj. I S I T.V.D. I 6147 I Tubingl 1030 I 1030 I 1030 I 1030 Ilntervall 4 P.T.D.I 1831410 ITypetestl P ITestpsil 2500 I Casingl 1900 I 2650 I 2650 I 2650I P/F I P Notes: OA psi. 1040 1.5 BBL pumped We,,I Is I T.V.D. 18108 I Tubing 12950 12950 12950 12950 I Interval 4 P.T.D.I 1831550ITypetestl P I Testpsil 2000 ICasingI 1500I 2360I 2360I 2360I P/F I P- Notes: OA psi. 400 1 BBL pumped Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: _5 Attachments: Number of Failures: 0 Total Time during tests: 4 hrs. MIT report form 5/12/00 L.G. 2003-0704_M IT_KRU_I G- 16_ic.xls 7/17/2003 .....STATEOF~ AI.P,SKA OIL AND GAS CONSERVATION ~MIS~51ON REPORT OF SUNDRY WELL OPERATIONS I1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing ,_.._. Repair well Other 2. Name of Operator 15. Type of Well: 6. Datum elevation (DF or I Development ~ ARCO Alaska. Inc, Exploratory _ X 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1129' FSL, 264' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1102' FSL, 1762' FWL, Sec. 30, T12N, R10E, UM At effective depth 1305' FSL, 1348' FWL, Sec. 30, T12N, R10E, UM At total depth 1335' FSL~ 1299' FWL~ Sec. 30~ T12Nr R10E~ UM 12. Present well condition summary Total Depth: measured true vertical RKB 90 feet 7. Unit or Property name Kuparuk Biver Unit 8. Well number 1~i-03 9. Permit number/approval number 82-149 10. APl number so-029-20824 11. Field/Pool Kuparuk Rivor Oil pool , 8 4 8 9 feet Plugs (measured) None 6 9 51 feet Effective depth: measured 8 3 71 true vertical 6 84 8 feet Junk (measured) None feet Casing Length Size Structural Conductor 1 0 8' 1 6" Surface 22 7 0' 10 Intermediate Production 8433' 7" Liner Perforation depth: measured 7495'-7525', true vertical 6104'-6130', 3/4" Cemented 325 SX AS II 1400 SX AS III & 250 SX AS I 900 SX Class G & 250 SX AS I 7540'-7563', 7772'-7825' 6142'-6161', 6336'-6380' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 w/ tail @ 7740' Packers and SSSV (type and measured depth) Measured depth True vertical depth 108' 108' 2302' 2218' 8464' 6929' RECEIVED JUN 2 5 199,3 Alaska Oil & Gas L;o,t~. uu,,,,nissior, Anchorage PKR's: Baker HB @ 7361'~ Baker FB-1 @ 7724; SSSV: Camco TRDP-1A ~ 1815' 13. Stimulation or cement squeeze summary Fracture stimulation of "A" Sands on 5/9/93. Intervals treated (measured) 7772 '-7825' Treatment desCription including volumes used and final pressure Placed 173 MLBS of 16/20 and 12/18 ceramic proppant into formationr ftp was 6000 psi. 14. Renresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 0 - -0- 1900 325 2350 Subsequent to operation - 0 - -0- 2100 325 2350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISi~ned C'[J'-J-~ Title ~'~''' Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ' WELL ARCO Alaska, InC" > Subsidiary of Atlantic Richfield Company /dr -$ CONTRACTOR ~),'~ ~_~ ~ L L REMARKS WELL SERVICE REPORT IPBDT iFIELD ' DISTRICT ' STATE iDA7 OPERATION AT REPORT TIME DATE O UN 2 5 199~ Alaska Oil 8, Gas Cons. Commission Anchorage J I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. Chill Factor ] Visibility } Wlfld Vel. Report °F °FI miles JSignee knotsl~, . _~., __.~... -/? ~'"~'"' STATE OF ALASKA AL,-,oKA OIL AND GAS CONSERVATION COMMi,.-~SION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1129' FSL, 264' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1102' FSL, 3517' FEL, Sec. 30, T12N, R10E, UM At effective depth 1305' FSL, 3932' FEL, Sec. 30, T12N, R10E, UM At total depth 1335' FSL, 3981' FEL, Sec. 30, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 8 4 8 9' feet true vertical 6951 ' feet Plugs (measured) 6. Datum elevation (DF or KB) 90' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1G-3 Injector 9. Permit number/approval number 82-149/8-633 10. APl number $0-029-20824 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 3 71 ' feet true vertical 6848' feet Junk (measured) Casing Length Size Structural 7 9' 1 6" Conductor 227 0' 10 Surface Intermediate Production 8433' 7" Liner Perforation depth: measured 7772'-7825', true vertical 6336'-6380', 3/4" Cemented Measured depth True vertical depth 325 Sx AS II 7 9' 7 9' 1400 Sx AS III & 2302' 221 8' 250 Sx AS I 7540'-7563', 6142'-6161', 900 Sx Class G & 250 Sx AS I 7495'-7525' 6104'-6130' Tubing (size, grade, and measured depth) 3 1/2", 9.2#/ft, J-55 tubing w/tail @ 7721' Packers and SSSV (type and measured depth) 8464' 6929' RECEIVED o 719 g Alaska Oil & Gas Cons, Commission Anchorage BeT 2B W/L set pkr @ 7699'; BeT HB-1 hyd. set pkr @ 7344'; Camco TRDP-1A SSSV @ 1908' 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Treatment description including volumes used and final pressure Convert from WI to WAE Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -0- -0- 700 285 246O ..2475Subsequent to operation -0- -0- 4800 -0- 1 700 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector m Oil .._Gas Suspended Service WAG Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISi~ned ~'~~ ~~ Title Sr. Operations En.clineer Form 10-404 Re{/ 05/17/89 SUBMIT Ih DUISLIOATE AR ,C, O, Alaska, In~ ~--, ~ ~ Sul:~J'~ry o Atlantic Richfield Comp~ ~/ELL ~ONTRACTOR ~7'/$ -- n~MARKS WELL SERVICE REPORT I-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA "'~'~ ~' ALA...A OIL AND GAS CONSERVATION COI~.,,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ ~ Re-enter suspended well Tl Alter camng [I T,me extension Change approved program Plugging '~ Stimulate .? Pull tubing Amend order ,r Perforate [' Other 2 Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 90 feet 3 Address 6. Unit.or~P. roperty, n~.me PO Box 100360, Anchorage, AK 99510-0360 KuparuK ~ver un~ 4. Location of well at surface 1129' FSL, 264 FWL, Sec. 29, T12N, RIOE, UN At top of productive ~nterval 1102' FWL, 3517' FEL, Sec. 30, T12N, RIOE, UN At effective depth 305 ' FSL. 3932 FEL, Sec. 30 T12N, RIOE UM t total depth ' ' 1'~' I:'(;I '~QP. 1 ' FFI (:;sc '~n T19N I~lnF IIM 11.-~r~ent' ~/~li' c~)~'i~'ion' s-u-~m~, ..... ' .... ' ..... ' -" 7. Well number 1G-3 8. Permit number Permit #82-149 9. APl number 50-- n?Q_?n~gzt 10. Pool I<ll,nnrllk R~vPr Nil Pno1 Total depth: measured 8489' MD feet true vertical 6951' TVD feet Effective depth: measured 8371' MD feet true vertical 6848' TVD feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Plugs (measured) N/A Junk (measured) Top of fill @ 7820'None Vann Guns @ 7963' Cemented Measured depth 79' 16" 325 SX AS 11 79' MD 2270' 10-3/4" 1400 SX AS III & 2302' MD 250 SX AS I 7" 900 SX Class G 250 SX AS I 7772' -7825', 7540' -7563', 7495' -7525' MD 8433' measured ~ue Vertical depth 79' TVD 2218' TVD 8464' MD 6929' TVD true vertical6336'-6380' 6142'-6161' 6104'-6130' TVD Tubing(size, grade and measumd depth) 3-1/2", 9.2#/ft, J-55 tubing w/tail @ 7721' Packers and SSSV(type and measumd depth) B0T 2B W/L set pkr @ 7699'; B0T HB-1 hsd. set pkr @ 7344'; Camco TRDP-1A SSSV @ 1908' 12.Attachments Description summa~ of proposal ~ Detailed operations program ~ BOP sketch ~ Convert from water injection to WAG 13. Estimated date for commencing operation Au au s t./S e~t.P, mhe r 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the~ foregoing is true and correct to the,~best of my knowledge Signed ~d:7,,~.~(,/ ~ ,~,/'~~/~---~'~/ Title c/~/t ///~..--,~.c~;"~ - ~ - ' Commissi;~ Use O~ly Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness I-} Plug integrity [] BOP Test D Location clearance .,,pr)roved Copy Commissioner Date J Approva, No. by order of the commission Date~]~.--/~.~2~ , , Submit in triplicat~ Form 10-403 Rev 124-85 Sundry Notice Well 1G-3 No BOP will be used for the proposed work. No workover fluids are required. The estimated BHP is 3600 psig. 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I~ WATER INJECTOR ..... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-149 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-20824 4. Location of well at surface 9. Unit or Lease Name 1129' FSL, 264' FWL, 5ec.29, T12N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1102' FSL, 3517' FEL, Sec.30, T12N, R10E, UM 1G-3 At Total Depth 11 Field and Pool 1335' FSL, 3981' FEL, Sec.30, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 90'I ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/20/82 10/01/82 10/08/82* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8489'MD, 6951 'TVD 8371 'MD, 6848'TVD YES~] NO [] 1804' feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SP/GR/Cal, FDC/CNL, BGT, GR/CBL/CCL/VDL, CBL, GR/CCL/CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf ' '79' ' 24" 325 sx AS I I 10-3/4" 45.5# K-55 Surf 2302, 13-1/2" 1400 sx AS ill & 250 ~ AS I 7" 26.0# K'55 Surf 8464' 8-3/4" 900 sx Class G & 250 sx AS I . 24. Perforations open to Production '(MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 120° phasing 3-1/2" 7739' 7721' 7495 '-7526 'MD 6104 ' -6130 'TVD 7540'-7563'MD 6142'-6161 'TVD 26. ACID, FRACTUREi CEMENT SQUEEZE, ETC. 7772 ' -7825 'ND 6336 ' -6380 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7432'-7434' 250 sx Class G 7674'-7676' 200 sx Class G .. See Sundry dated 9/1 8/84. for fra~.~ur~ 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL' CHOKE SIZE I GA~-OIL RATIO TEST PERIOD J~ I Flow Tubing casing Pressure CALCULATED 'OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c°rr) Press. 24-HOUR RATE e 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Atask~ 0it & Gas Cons. commission Anchorage *Note: Well fractured 8/10/84. Workover performed & well perforated 8/25/84. Converted to water injector 10/25/85. Workover performed 11/13/87. ,,,.~r~ STATE OF ALASKA " ALASK,,~ OIL AND GAS CONSERVATION ~,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO Form 10-407 WC/*/1/*:DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7495' 61 04' N/A Base Upper Sand 7562' 6160' Top Lower Sand 7750' 6317' Base Lower Sand 7876' 6422' 31. LIST OF ATTACHMENTS None 32. I hereby certify that The foregoing is true and correct to the best of my knowledge Signed Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~-'~"~ STATE OF ALASKA -~"~'"'" AL,. .... . OIL AND GAS CONSERVATION CO. ,,,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [~ W0RKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 90' Feet 3. Address 6. Unit or Property name P.0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1129' FSL, 264' FWL, Sec.29, T12N, R10E, UM At top of productive interval 1102' FSL, 3517' FEL, Sec.30, T12N, R10E, UM At effective depth 1305' FSL, 3932' FEL, Sec.30, T12N, RIOE, UM At total depth 1335' FSL, 3981' FEL~ Sec.30~ T12N~ RIOE~ UM 7. Well number 1G-3 8. Approval number 7-636 9. APl number 50-- 029-20824 10. Pool Kuparuk River Oil Pool 11. Present well condition summary · Total depth: measured true vertical Effective depth: 8489 ' MD 6951 ' TVD measured 8371 'MD true vertical 6848 'TVD Length siZe 79 ' 16" 2270 ' 10-3/4" Casing Conductor Surface Production 8433' 7" feet Plugs (measured) None feet feet Junk (measured) feet Top of fill ~ 7903' Vann Guns ~ 7963' Cemented 325 sx AS II .1400 sx AS III & 250 sx AS I 900 sx Class G & 250 sx AS I Measured depth 79'MD 2302'MD 8464'MD True Vertical depth 79 ' TVD 2218 ' TVD 6929' TVD Perforation depth: measured 7772 ' -7825 ', 7540 ' -7563 ', 7495 ' -7526' true vertical 6336'-6380', 6142'-6161', 6104'-6130' Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail @ 7739' Packers and SSSV (type and measured depth) FB-1 pkr @ 7721' & TRDP-1A SSSV @ 1804' RECEIVED 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure DEC i 4 !987 0il & Gas Cons. C0mmissl0ri Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations Ex Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~ ¢-C~¢/..~' Signed- '~)~~ ~.fllJ~ , Title Associate Engineer Date ]Z'~'~7 Form 10-404 Rev. 12-1-85 ~ ' -- (Dani) $W03/17 Submit in Duplicate 11/02/87 ( TD: 8489 PB: 8371 SUPV:DJ 11/03/87 ( TD: 8489 PB: 8371 SUPV:DJ 11/04/87 ( TD: 8489 PB: 8~71. TD: 8489 PB: 8371 SUPV:JE SLOPE 1G-3 IWoll POOH MN: 9.9 NaCl/NaBr FINISH POOH W/3-1/2" TBG, SSSV, & SBR. RD TBG TOOLS, PU WASH PIPE & DC. LOAD SHED W/DP. RIH, WASHOVER SLICK STICK, CIRC. SWEEP, POH. (WASHED OUT FILL TO TOP OF PKR ~ 7339', PUMPED HIGH-VIS XC PILL (25 BBLS), FINE SAND AND CLAY IN RETURNS) RIH MW: 9.9 NaC1/NaBr POH. LD WASHPIPE. FLUID LOSS-10 BBLS. SLIP AND CUT DRLG LINE, SERVICE. RIG. TIH. LATCH FISH AND JAR FREE. CIRC. POH AND LD FISH. PU WASHPIPE AND TIH. POOH MW: 9.9 NaC1/NaBr TIH. TAGGED GLM @ 7659'. TIH. TAGGED FISH ~ 7617'. JAR ON FISH. POOH. POOH MN: 9.9 NaC1/NaBr POOH. L/D BHA AND FISH, INCLUDING SEAL ASSY AND 1-1/4" HYDRIL AND W/L TOOLS. TOOLS PACKED IN FRAC SAND IN TUBING. M/U BHA W/6-1/8" BIT. SLIP/CUT 50' DRILL LINE. RIH 7697'. TAG PACKER. CIRC. HOLE CLEAN. PUMP HIGH-VIS SWEEP. n~..- POOH. Date . ITitle ARCO Oil and Gas Company Daily Well History--Interim etructJona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. umber all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field KUPARUK Date and depth as of 8:00 a.m. I County or Parish IState ARCO Alaska, Inc. I NORTH SLOPE I AK I Leaae or Unit I ADL 25640 Complete record for each day while drilling or workover in progress NORDIC I 11/06/87 ( TD: 8489 PB= 8371 SUPV:JE 11/07/87 ( TD: 8489 PB: 8371 SUPV:JE 11/08/87 ( TD: 8489 PB: 8371 SUPV:JE/R~ 11/09/87 ( TD: 8489 PB: 8371 SUPV:JE/RB 11/10/87 ( TD: 8489 PB: 8371 SUPV:JE/RB The above is correct 8) 1G-3 RIH WITH 3-1/2" TUBING MW=10.0 NaCl/NaBr FILLED DP WITH CLEAN BRINE. ATTEMPTED TO POH. PULLED 72 eTD-BULLHEADED 22 BBLS FOR FILL-UP. HOLE SWABBING. RIH SLOWLY. TAGGED PACKER ~ 7696'.. DISP. VISCOSIFIED BRINE WITH 10.0 PPG CLEAN BRINE. POH. NORMAL FILL UP. NO FLUID LOSS. L/D BHA. RECOVERED 1/2 GAL. FRAC SAND IN JUNK BASKET. RIH WITH 5" IMP. BLOCK ON WIRELINE. TAGGED ~ 7666'. POH. NO W/L TOOL MARKS. PICK UP SHORT SEAL ASSY F/BOT 2B PACKER AND RIH WITH 3-1/2" TUBING. NO FLUID LOSS IN THE HOLE AFTER DISPLACING BRINE. DRIFT TBG WHILE RIH. .o) BREAK CIRC. ABOVE PKR MW:10.0 N&Cl/NaBr RIH WITH 3-1/2", 9.2%, BTC TUBING. TAGGED @ 7703'. STAB INTO PACKER & PRESS. UP TO 1500 PSI. RIH WITH 1-1/4" DRIFT ON SLICKLINE. TAG @ 7708'. RIH W/IMP. BLOCK. TAGGED % 7692'. CIRC. TBG VOLUME AFTER P/U OUT OF PACKER. RIH W/IMP. BLOCK. TAGGED @ 7695'. R/D SLICKLINE. POH WITH 3-1/2" TUBING. PU WASHOVER SHOE, BHA AND RIH WITH 3-1/2" DP. POH W/3-1/2" DP MW:10.0 NaCl/NaBr PU KELLY AND TAGGED PKR @ 7697'. MILLED PKR F/7697'-7700'. POH WITH 3-1/2" DP AND MILL ASSEMBLY, SHORTEN TRISTATE BULLNOSE, MU SPEAR BHA & RIH WITH 3-1/2" DP. TAGGED PKR @ 7660' & PUSH TO 7803'. STABBED INTO PKR AND POH WITH 3-1/2" DP. 11) RIH W/SCRAPER & 3-1/2" DP MW: 9.9 NaCl/NaBr .. POH WITH 3-1/2" DP AND SPEAR ASSY. NO PACKER RECOVERED. RIH AND TAGGED PKR @ 7803' CIRC. AND STABBED INTO PKR @ 7809' POH-RECOVERED PKR AND TAILPIPE ASSY. RIH. SLIP AND CUT DRILLING LINE. RIH W/BHA & 3-1/2" DP. For form preparation and distribution see Procedures Manual Section 10, DHIling, Pages 86 and 87 SET HOWCO RTT$ & STORM CH MW:10.0 NaC1/NaBr RIH WITH 3-1/2" DP AND 7" SCRAPER ASSY TO 7825'. WASH F/7825'-7895', DRILLED JUNK F/7895'-7903', CIRC. 70 BBL PILL (52 VIS.), SPOTTED 50 BBL PILL AT PERFS. POH W/72 eTD 3-1/2" DP. MIX AND CIRC. 10.0+ PPG NaCl/NaBr @ 3600' (WELL FLOWING). POH WITH 3-1/2" DP AND LD BHA. MU HOWCO BRIDGE PLUG, K~H, A~U ~mT ~ 7300'. Poo~ W/2 ~D~.' ~ HOWCG Rii$ & =~uua~ C~4~,SET @ 28'. ]Title Well no. ARCO 0il and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" 8heats until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00a.m. I County or Parish ARCO Alaska, Inc. I NORTH SLOPE I Lease or Unit KUPARUK ~ ADL 25640 Complete record for each day while drilling or workover in progress NORDIC I 11/11/87 ( TD: 8489 ?B: 8371 SUPV=JE/RB 11/12/87 ( TD: 8489 PB: 8371 SUPV:DJ 11/13/87 ( TD: 8489 ?B: 8371 SUPV:DJ IState 12) RIH W/GAUGE RING MW:10.0 NaCl/NaBr ND 11" BOP AND CHANGE OUT McEVOY TBG HEADS. NU BOPE AND TESTED TO 3500 PSI. POH WITH RTTS AND STORM CHOKE. RIH AND RETRIEVED BRIDGE PLUG. CIRC. SYSTEM TO 10.0 PPG NaCl/Br. POH WITH 58 STDS DP. TESTED LUBRICATOR AND RIH WITH GAUGE RING. 1.3) AK 1G-3 14) RD SCHLUMBERGER MW:10.0 NaCl/NaBr RUN GR/JB. RU SCHLUMBERGER AND TEST LUBRICATOR. ATTEMPTED TO RIH WITH PKR AND TAILPIPE ASSY. POH. MODIFY TAILPIPE ASSY. RIH WITH PKR AND TAILPIPE ASSY TO 7418'--UNABLE TO GO DEEPER. POH AND RD SCHLUMBERGER. RIH W/COMPLETION ASSY MW:10.0 NaCl/NaBr RIH WITH FB-1 PKR AND SET @ 7710'WLM WITH 2500 PSI. POH. RU TO RUN COMPLETION ASSY. RIH WITH TUBING. (241 JTS 3-1/2", 9.2[, J-55; BTC, AB-MOD, R-2, IPC & 2 JTS 3-1/2", 9.3~, J-55, EUE, 8RD, AB-MOD, R-2, IPC TUBING. JWell no. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle ARCO Oil -and Gas Company Daily Well History-Final Report Inll~etio~lit Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or ~old. "Fl#il Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovere when an official te~t is not required upon completion, report completion and representative test data in blocks provided. The "Flail Report" form may be u~ed for reporting the entire operation if space is available. Accounting ARCO: Ala~a~ ~ Inc. I NORTH SLOPE ,~ ILease or Unit no. I .uPARuK IT,t,e ~L 25640 1G-3 I ~ ~I 50-029-20824 District COSt center code Field Auth. or W.O. no, Operator ~RCO ~TJthSFJ~,. Spudded or W.O, begu~ - ACCEPTED ~ of 8~ ~m; ~O~IC [ TD: - 04:G~; PB: 83'7~ A.R.Co. W.I. 56,0000 I'bate 10/31/87 Iotal number of wells (active or ina~tlve) on thl~ oat center prior to plugging and / bandonmant of this well our i i brier ~tltul If I W.O. 0130 l, RIG RELEASED MW: 10.0 N&C1/N&Br FINISH RIH W/ COMPLETION ASSY. LOCATE, VERIFY, SPACE OOT AND I-.~ND. SET PKR. SHEAR OUT PBR. TEST ANNULUS FOI~ STATE, TE-$T SSSV, S~EAR BALL, N/D STACK. N/U AND TEST DISPLACE TO DIESEL. TEST CHECK VALVE. SECUItE T~t~. RIG RELEASED g 2000 HRS, 11/13/87. SSSV g 1804', FB-1 P~lq 7721', TUBING TAIL ~ 7739'. Old TO I NeW TD I Released rig I Date I Classifications (o11, gas, etc.) Producing method Potential test data PB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) W'~il no. Date " ' Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ,,, , The above 18 correct For form; Preparation and dlatrihutlOn, see Prooedure~ Manual, Section 10, Drilling, Pages 86 lad 67. : Date ]Title ~-'", STATE OF ALASKA '~- : OIL AND GAS CONSERVATION CO, .... ,,,dSlON APPLICATION FOR SUNDRY APPROVALS feet 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing '~ Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~ Inc. ~KB 3. Address 6. Unit or Property name P. 0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4'. Location of well at surface 7. Well number lC-3 1129' FSL, 264' FWL, Sec.29, T12N, RIOE, UM At top of productive interval 8. Permit number .1102' FSL, 3517' FEL, Sec.30, T12N, RIOE, UM i~2-149 At effective depth 9. APl number 1305' FSL, 3932' FEL, 5ec.30, T12N, R10E, UM 50--029-2{3~2~ At total depth 10. Pool 1335' FSL, 3981' FEL, 5ec.30, T12N, R10E, UH Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical 8489 'MD feet Plugs (measured) N/A 6951 ' TVD feet Effective depth: measured 8371 'MD true vertical 6848 ' TVD Casing Length Size feet Junk (measured) feet Cemented Top of fill @ 7820' Vann Guns @ 7963' Measured depth Rue Verticaldepth Conductor 79' 16" 325 sx AS il 79'MD 79'TVD Surface 2270' 10-3/4" 1400 sx AS III & 2302'MD 2218'TVD 250 sx AS I Production 8433' 7" 900 sx Class G & 8464'MD 6929'TVD 250 sx AS I measured 7772'-7825' 6336'-6380' Perforation depth: , 7540'-7563' , 61 42'-6161 ' true vertical , 6104'-6130' SEP 2 5 19 7 Tubing (size, grade and measured depth) 3-1/2", 9.2#/ft, J-55 tubing w/tail @ 7721' Nas~ 0it & GaS C0~s. commtssto" Packers and SSSV (type and measured depth) B0T 2B W/L set pk.r @ 7699'; B0T HB-1 hyd. set pkr ~ 7344'; Camco TRDP-1A SSSV @ 1908' 12.Attachments Description summary of proposal ~k Detailed operations program [] BOP sketch ~ 13. Estimated date for commencing operation October 9, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,,~,~l//)/7~/)4'-/_~.~/J~.4. _, TitleAssoci ate Enqi rl~r Date Commission Use (JG) SA2/97 Only Conditions of approval Notify commission so representative may witness [] Plug integrity E]'. BOP Test [] Location clearance .... · Approved by by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate KUPARUK WELL 1G-3 FISH WIRELINE TOOLSTRING AND 48' OF 1-1/4" TUBING PRELIMINARY PROCEDURE 1) Move in rig up workover rig. Kill well. 2) ND tree. NU BOPE and test. 3) RIH w/chemical cutter, cut 3-1/2" tubing below "C" sand perfs and above fish at 7680'. 4) Pull out of SBR. POOH with tubing, change out collars to AB-Modified. 5) PU 3-1/2" DP and RIH. POOH with retrievable packer and carbide blast rings. 6) PU overshot on 3-1/2" DP. RIH. Latch 3-1/2" tubing with 48' of 1-1/4" tubing and wireline toolstring wedged inside. POOH w/3-1/2" tubing and fish. 7) RIH and set retrievable bridge plug. Change out wellhead to 5000 psi equipment. Pull bridge plug. 8) Run 3-1/2" single selective completion assembly. 9) ND BOPE. NU tree and test. 10) Displace well to diesel. 11) Test annulus and tubing to 2500 psi. Annulus will be tested for 30 minutes. 12) Secure well, release rig. Completion fluid: NaC1/NaBr Brine Anticipated bottomhole pressure: 2800 psi Anticipated start date: October 9, 1987 SA2/97a 7-1/, 16" 5000 PSI,BOP, STACK ANNULAR PREVENTER 6 ACCUMULATOR CAPACITY TEST 1, CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS ;~000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, :~. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS PIPE AMS 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSi REMAINING PRESSURE, R~CEI~) BLIND RAMS 5 TUBIN6 HEAD BOP ,STACK TEST SEP 2 2 CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETI:L~CTED', PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES, 5, INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PiPE RAMS, INCREASE PRESSURE TO 6000 PSi AND HOLD FOR 10 MINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH ::5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSi DOWNSTREAM, BLEED SYSTEM TO ZERO PSI, OPEN PiPE RAMS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO :5000 PSI, TEST KELLY COCKS AND INSIDE BOP TO :3000 PSi WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. , g, 10, 11. 12. 1:5. 14. 1. 16" CONDUCTOR SWAGED TO 10-:514" 2. 11"-:5000 PSI STARTING HEAD :5. t 1"-3000 PSI X 7-1/16"-15000 PSI TUBING HEAD 4. 7-1 / 16" - 5000 PSI PIPE RAMS 5. 7-1 / 16" - $000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR dG dULY 28, 1986 (NOP, r)IC: RI(~ 10-3/4") rio./-,,- k h r," , JUN 2~ 1~' (~34''/ &taska Oil & Gas Cons. Commission Anchorage ATTACHMENT I I Dri 11 Si te lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date Drill Site Well No. .Lo. 9 Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site 1C Well No. 1C-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8' · Log Date 519181 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D 1D-1 · 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 ~lD-8 (WS-8) 5/i0/78 AJar~ Oil & ~a~ Co,,s ~ Dri 11 Si te 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date lQ ~1Q-_5~~:12/1/85 Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 , 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Log Da te 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 ]0/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 16 Well No. Log Date 16-1 16-2 16-3 16-4 t6-5 16-7 ]6-8 Drill Site Well No. 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 !F-3 12/8/84 !F-4 10/13/82 1F-5 11/12/82 1F-6 3/12/83 1F-7 !9/85 o 1986 Alaska 0il & Gas Cons, Lo9 Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Wel 1 No. ~1H-3 ~1H-4 ~'1H-7 '"1H-8 Lo0 Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA ~/19/81 1E-2 ~8/17/81" _'~1/17/84/ 1E-3 "10/18/81~. ~11/7/81j ",,8/4/80~ 1E-5 ~10/27/81, 1E-6 ~10/21/81~ ~11/12/82/ ~1E-7 ~/28/81~ %10/28/81/ 1E-8 ~8/28/81~ ~11/1/81/ 1E-12 ~11/28/84 1E-15 ~/26/82 1E-16 ~/29/82 1E-17 ~9/1/82 1E-20 ~5/7/83 .1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 1E-28 ~10/27/8Z) ~6/13/83 1E-29 ~10/18/a2~ ~7/18/83 1E-30 ~0/16/82 Drill Site 1G Well No. '~'IG-1 ~1G-2 "~1G-3 '~1G-4 '~4G-5 % 1G-8 Log Date 9/7/82 ' 9/25/82~,, 9~28/82 12/8/84× 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F IF- 1 F-2 F-3 "1F-4 '",1F-5 ",.1F-6 ",, 1F-7 RECEIVI 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82x,, ,~ 517/83 ? FEB 2 1 1986 ~daska 011 & Gas Cons. Commi~lon Anchorage Mr. C..V.' Cha~ton May 27, 1986 Page 2 Wel 1 Number 1A-7 1A-9 1A-11 1A-12 1A-13 1A-14 1A-15 1A-16 Wel 1 Number 1E-lA 1E-4 -- 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 IE-23 1E-27 1E-30 KUPARUK RIVER UNIT INJECTION LOGS INJECTION PROFILES Date of Initial Injection Date of Injection Profile 3/21/83 3/25/83 3/1/83 3/22/83 3/7/83 3/21/83 3/1/83 3/6/83 2/4/83 10/17/83 2/22/83 4/11/83 3/1/83 3/18/83 3/1/83 3/24/83 Date of .Initial Injection Date of Injection Profile 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 10/25/85 12/20/85 1G-6 7/28/84 9/23/84 1G-9 9/15/84 9/23/84 1G- i4 8/24/84 9/22/84 1G- 16 8/24/84 9/22/84 1 Number Date of Initial Injection Date of Injec. tion Profile 1F- 10 8/13/84 10/30/84 1F-11 8/12/84 9/24/B4 1F-i3 8/16/84 9/25/84 1F-15 8/16/84 9/26/84 - -Wel Well Number Date of Initial Injection Date of Injection Profile Attachment I I ~-~ Page 3' Dril 1 Si te Wel 1 No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 314184 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~I~~.~ 11/5/10/83 21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. LoB Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 '~2C.~ 16~121-1t/85 Drill Site Well No. Lo9 Date 2Z' o/83 2Z-2 ': 6/24/83 7/19/83 '2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83- 2Z-8 8/3/83 VLF: pg: 0052 Anchorag~ ARCO Alaska, Inc.~ Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman Alaska· Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: on the Well Action Date Performed 1F-4 Conversion 1F-5 Conversion 1F-8 Conversion 1G-3 Conversion 1G-4 Conversion 1L-3 Conversion 1L-5 Conversion 1Q-8 Conversion 1Q-12 Conversion 1Q-14 Conversion 1R-3 Conversion 1R-10 Conversion 1Y-7 Conversion 1Y-10 Conversion 1Y-15 Conversion 1Y-13 Conversion 2B-6 Conversion 2B-8 Conversion 2B-11 Conversion 2B-12 Conversion 2C-2 Conversion 2C-4 Conversion 2C-5 Conversion 2C-7 Conversion 2D-4 Conversion 2D-5 Conversion 2F-3 Conversion 2F-4 Conversion 2F-15 Conversion 2F-16 Conversion 2D-10 Conversion 2D-16 Conversion 10/24/85 10/24/85 10/24/85 10/25/85 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10/25/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 11/5/85 11/5/85 11/5/85 11/5/85 11/6/85 1116185 11/6/85 11/6/85 11/6/85 11/6/85 11/2/85 11/2/85 11/2/85 11/2/85 11/6/85 11/6/85 · .. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,. STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 4. Location of Well SURFACE LOCATION. 1129' FSL, FWL, Sec. 29 T12N, R109E, UM 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-149 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20824 264' 5. Elevation in feet (indicate KB, DF, etc.) (RKB) 90 ' 12. I 6. Lease Designation and Serial No. ADL25640 ALK 2571 9. Unit or Lease Name KUPARUK R I VER UN I T 10. Well Number 1C-3 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). On October 25, 1985 Kuparuk well a water injector well as part of effort. Water is being injected 1G-3 was converted from a producer to the full field waterflood conversion into both the "A" and "C" sands. RECEIVED Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use KUPARUK Title UHI-'-I~ I I (JN5 COORD I NATOR Date11 / 1 5 / 85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Submit "Intentions'' in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc: ~ Post Office 't~,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine 'Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in'working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps'013 RECEIVED S E P 2 0 ON & Gas Cu~is. ComrrlJssion AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany f.-~.. STATE OF ALASKA ~ ALASK~ ~ ~_AND GAS CONSERVATION £ %MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL I-I COMPLETED WELL ~-I OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 99510 7. Permit No. see attached 8. APl Number s0- see attached 9. Unit or Lease Name Kuparuk Ri'ver Unit 10. Well Number see attached I6. Lease Designation and Serial No. see attached Check Appropriate Box To Indicate Nature of Notice, Report, or )ther Data NOTICE OF' INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate' ' [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other X~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool (Submit in 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). Pursuant to form 10-403, it is proposed that the attached list of~A~roducing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion; to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. R£CE V£D SEP 2 019 5 AlaSKa Oil & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed :~, /~'~ ~~'~'-~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy By Order of COMMISSIONER the Commission Date__ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ' 1E- 6 -26 iF- 2 ' 4 - 5 -- 8 1G- 2 - 3 - 4 - 5 IL- 1 -' 3 - 5 - 7 -16 - IQ- 1 - 2 - 7 - 8 -11 -12 -13 -14 iR' 3 - 8 -10 -13 1Y- 1 - 7 -10 -13 2B-5 - 6 - 7 - 8 - 9 -10 -11 -12 2C- 1 - 2 - 3 - 4 - 5 MARK:009 Permit 80- 78 82-166 81-211 172 132 162 82 138 149 161 83- 20 84-173 158 123 145 181 84-231 232 218 209 199 193 85- 44 45 85-177 73 96 150 83- 50 68 51 15 84- 4 22 24 28 27 29 35 38 83- 83 93 89 94 99 API# 029-20493 029-20840 029-20881 20846 20807 20836 029-20813 . 20824 20835 20908 029-21196 21182 21155 21171 21202 029-21247 21248 21234 21225 21216 21210 21306 21307 029-21406 21333 21351 21385 029-20933 20950 20934 20903 029-21067 21078 21080 21079 21082 21084 21089 21092 029-20962 20972 20968 20973 20978 Lease & Serial ~ Convert Date 25651 469 10/15/85 " " 10/15/85 25652 2578 10/15/85 " " 10/15/85 " " 10/15/85 " " lO/15/85 25640 2571 lO/15/85 " " lO/15/85 " " lO/15/85 " " lO/15/85 25659 2585 12/15/85 " " lO/15/85 " " lO/15/85 " " 12/15/85 " " lO/15/85 25634 2567 10/15/85 " " 12/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " lO/15/85 25635 2568 lO/15/85 " " lO/15/85 " " lO/15/85 " " lO/15/85 25641 2572 12/15/85 25646 2577 12/15/85 " " 12/15/85 25548 2662 12/15/85 25656 2582 12/15/85 " " lo/15/85 " " 12/15/85 " " 10/15/85 25655 2581 12/15/85 " " 12/15/85 " " 10/15/85 " " lO/15/85 25654 2580 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 ,, ,, SE? 2 o BBS AlaskF. Oil & Gas Cons. Commission ARCO Alaska, Inc/--~ Post Offic/ : 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 12/06/84 Transmittal No: 4896 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 and return one signed copy of this transmittal. CBL' s FINALS Schlumberger 1F-4 "Variable Densi'ty" "CRS/BP 4"/HJ ll/JB" 1G-3 " " "JB/GA/PPS/CRS/Perf" "Squeeze" 8/14/84 Run 2 8/21/84 Run 3 6988 - 7842 6994 - 7864 /cat Receipt Acknowledged: Date: DISTRIBUTION B. Currier BPAE Chevron Drilling Geology Mobil W. Pasher G. Phillips Phillips Oil State of AK ~ Sohio Union D&H NSKOps. J Rathmell Well Files ARCO Alaska, In? Post Office .=ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1G-3 Dear Mr. Chatterton- Enclosed is the Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, If J. Gruber Associate Engineer JG/tw GRU2/L33 Enclosures RECEIVED OCT 2 519 ¢ Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is e Subsidiary of AtlanticRichfieldCompany ' ~ STATE OF ALASKA .--'-' ALASK. 'AND GAS CONSERVATION (. ;,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-149 3. AddreSs 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-20824 ..... ,, 4. Location of well at surface 9. Unit or Lease Name 1129' FSL, 264' FWL, Sec.29, T12N, RIOE, UN Kuparuk River Unit At Top Producing Interval "10. Well Number '- 1102' FSL, 3517' FEL, Sec.30, T12N, RIOE, UN 1G-3 At Total Depth 11. Field and Pooi 1335' FSL, 3981' FEL, Sec.30, T12N, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 90' RKBJ ADL 25640 ALK 2571 12. Date Spudded09/20/82 13. Date T. D. Reached10/01/82 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re [ 16' N°' °f Completi°nsl 0/08/82 . N/A feet MSL 1 17. Total Depth (M D+TVD) 18. Plug Back Depth {MD+TVD)19. Directional Survey I 2o. Depth where SSSV set I 21 . Thickness of permafrost 8489'MD,6951 'TVD 8371 'MD,6848'TVD YES [~ NO [] 1908 feet MD 1500' (approx) 22. TyPe El'ectric or Other Logs Run D IL/SP/GR/Cal, FDC/CNL, BGT, GR/CBL/CCL/VDL, CBL, GR/CCL/CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 79' 24" 325 sx AS II , 10-3/4" 45.5# K-55 Surf 2302' 13-1/2" 1400 sx AS Ill & 250 s; AS I , 7" 26.0# K-55 Surf 8464' 8-3/4" 900 sx Class G & 250 s: AS I , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7772' - 7825' 3-1/2" 7721 ' 7344' & 7699' , 7540' - 7563' w/12 spf, 120° phasing 7495' - 7526' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7432' - 7434' 250 sx Class G ,,, 7674' - 7676' 200 sx Class G , 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I ,-, · , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OtL-BBL GAS-MCF WATER-BBL el L GRAVITY-APl (c°rr) .... Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, Porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED OC'f 2 5 I 9fJ4 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 GRU1/WC18 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 301 " 'GEOLOGf-CMARKERS '' ' ' - '* FoRM'ATIONTESTS" ' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7495' 6104' N/A Base Upper Sand 7562' 6160' Top Lower Sand 7750' 6317' Base Lower Sand 7876' 6422' 31. LIST OF ATTACHMENTS Workover Well Hi story __ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~/. //_~_.Z4~/vl '__ Title Area Drilling Engr. Date /¢/~2///~,~//, / INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion .report and log on all types of lands and leases in Alaska. ' Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation,-injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for dep~th measurements given in other spaces on this form and in any attachments. '-, Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for °nly the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from grOund level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool.; Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Inler'tion .Shut-in Other-.exol=i¥, ~aa~ ...... ~ [ North Slope Borough ~ [~ ~ O~ Kupa~k River [ ~L 25640 ~m. or w.o. ~. ITltle ~ 103942/204587 I Eecomplectoa O~mtor Nabors 1-E$ ARCO Alaska, Inc. Workover . 8/14/84 0800 Hrs. Dire and depth u of 6:00 Lm. 8/14/84 8/~5/84 Well History. Initial Flepmt- gtltl Alaska 1G-3 8/16/84 8/17/84 8/18/84 thru 8/20/84 Complete mGon] for slob dly reported IA,CO W.,. 56.24% Prior stmtu~ If · W.O. 7- @ 8371' RU. 7" @ 8371' Accept 0800 hfs, 8/14/84. Pull BPV. Kill well by bullheading 60 bbls CaCO_ dn tbg. Sqz 50 bbls into perfs w/final press of 300 psi @ 1 ~PM. Open ann & circ out gas i diesel, displacing to 8.6 ppg brine. SI well f/30 min. Mx 30 bbl CaCO~/BridseSal pill & sqz pill away @ .1/2 BPM @ 250 psi. SI well f730 min, wait on pill. Spot pill & sqz 25 bbls pill into perfs w/final press of 50 psi. Set BPV. ND tree, NU & tat BOPE. 7" @8474' 8.6 ppg NEC1, RIH w/fsh'g BHA Fin NU & tst BOPE; OK. Pull BPV. Pmp 50 bbls, 10.0 ppg pill to kill well, monitor well (accum fluid loss - 456 bbls). Pull tbg & std back. MU BHA, RIH, picking up 3½" DP. 7" @ 8474' 8371' PBTD, POOH w/2nd fsh'g assy 8.6 ppg NaC1 RIH w/BNA, tag top of cut off tbg above SBR @ 7309' DPM, latch onto fsh, unable to tel pkr, POOH to 6520' DPM. Circ gas bubble out f/under fsh. Redress fsh'g OS w/4~" double bskt grapples, RIH, tag top of SBR slick-stick barrel @ 7316' DPM, would not engage in OS, chase fsh to 7777' DPM, engage fsh w/grapples, POOH v/full rec'y of pkr & TP assy. 7" @ 8474' ' 8371' PBTD, Drlg cIBp @ 7900' DPM 8.6 ppg NaC1 LD HH-1 pkr & tailpipe assy. RIH w/R-3 pkr, set @ 7400' DPM. Tst csg to 3000 psi, unset pkr, POOH. RU Schl, tst lub to 1000 psi. Perf 7674'-7676' WLM @ 4 SPF. Rn JB & 6.125" OD gage ring to 7850' WLM, POOH. MU EZSV, RIH & set top of BP @ 7760' WLM, POOH. MU EZSV as top retnr, RIH on WL, set top retnr @ 7580' WLM, RD Schl. TIH w/stinger, sting in, hesitate sqz perfs w/200 sx C1 "G" w/l% CFR-2 & .08% HR-7 w/final rate of 1/4 BPM/3200 psi. CIP @ 1645 hfs, 8/18/84. Att to rev circ DP w/o success. POOH, std back 81 ]ts DP. MU DD & mill, RIH, tag cmt @ 7554' DPM. Mill hard cmt f/7554'-7588' DPM, mill top retnr f/7588"-7~91', cmt f/7591'-7701' . RIH to 7765' DPM, tag btm eZSV, mill f/7765'-7766', rest of CIBP fell dnhole. RIH, tag CIBP @ 7840' DPM, mill & wrk CIBP dn f/7840'-7880', POOH, LD DD & mill' PU 6-1/8" bit & tandem JB, RIH, tag CIBP @ 7880' DPM, drl .to 7900' circ out rubber & ink. The above il correct Slgnlturt For form prepirltlon/l~, d dlitributlon, see Procedures Ma~ual, Seetlo~ 10, OHIIIng. Pa~# 86 and 9/18/84 on W®dnelday of lhe week in which oil Ilring is set. Submit weekly for workover~ and following setting ol oil stdng until completion, District Field Date and depth al of 8:00 a.m. l County or Parish A.laska North Slope Borough I Leese or Unit Kuparuk River ADL 25640 Complete record for each day while drilling or workovar in progress 8/21/84 8/22/84 8/24/84 8~23/84 Isiat. Alaska IWell nO. lC-3 7" @ 8474' 8371' PBTD, Prep to perf 8.6 ppg NaC1 Fin drlg CIBP & chase to top of Vann gun fsh @ 7931DPM. POOH, LD tandem JB. PU 2, 7" csg scrprs, RIH w/3-1/2" DP, tag fill.@ 7900' DPM, wsh dn to 7920' DPM. PU to 7900' DPM, chg over to cln 8.6 ppg brine, circ, POOH. Spot 9.6 ppg CaCot pill across "C" sand perfs @ 7570' DPM, cont POH, LD DP. RU Sch, tst lub to 1000 psi. RIH w/CBL/GR/CCL tls, log f/7000'-7840' WLM; good bond, POH. RU Schl, 5½",'12 SPF perf gun w/120° phasing. 7" @ 8474' 8371' PBTD, 7931' TOF, MU WL Pkr & TP Assy 8.6 ppg NaC1 RIH w/perf gun, unable to get past 7402' WLM, POH & LD. MU 6.125" gage ring/JB, RIH to 7850' WLM, POOH. RIH w/5½" dummy gun, stopped @ 7439' WLM, POOH. RU DA, tst lub to 1000 psi. RIH w/perf gun, perf 7560'-7563' WLM, 7550'-7560' WLM, 7515'- 7525', , 7495'-7505' WLM & 7505'-7515' WLM @ 12 SPF/120° phasing. Rn 6.125" gage ring/JB to 7830' WLM, POOH, no jnk. MU 2B-WL pkr & tailpipe assy. 7" @ 8474' 8371' PBTD, 7981' TOF, RIH w/3-1/2" Compl 8.6 ppg NaC1 Fin MU pkr & TP assy. RIH w/BOT pkr, stopped @ 449' & hung up. Wk free, POH. MU bit & 2 csg scrs. RIH & wk thru spot @ 449' RIH to 547', circ, POH LD DP & BHA. RU Dresser. PU BOT pkr & TP assy, RIH & set w/top @ 7690', POH, RD DA. PU CA & jewelry & RIH. 7" @ 8474' 8371' TOF, 8371' PBTD, ND Tree, Prep to POH w/Tbg 8.6 ppg NaC1 Fin RIH w/233 jts, BTC & 7 jts EUE + 3 blast its, 3½" tbg &lnd. ND BOPE, NU & tst tree to 5000 psi. RU to displ well, unable to circ thru choke vlv. RIH w/GL pull tl, set dn @ SSSV, would not pass, appears ball seat gone & pmp'g into formation, POH. RIH w/impression block, set dn on SSSV, POH; no impression. Set BPV in prep to POH w/tbg.. ND tree. The above is correct Signature For form preparation a.~. distribution see Procedures Manual Section tO, Drilling, Pages 86 and 87 Date ]Title 9/18/84 Drilling Superintendent ARCO Alaska', .... cf Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 22, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton' Enclosed are Subsequent Sundry Reports for the following wells' 2F-6 1G-3 1G-2 1Y-3 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer · JG/tw GRU2/L30 Enclosures RECEIVED OCT 2 1911 u~ ~ G~i Coils. C0111rlliSS[011 Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLxI~ OTHER [] 2. Name of Operator ARCO Alaska, inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1129' FSL, 264' FWL, Sec.29, T12N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 90' 12. 7. Permit No. 82-149 8. APl Number 50- 029-20824 9. Unit or Lease Name Kuparuk River Uni~. 10. Well Number 1G-~ 11. Field and Pool Kuparuk River Field J 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool ADL 25640 ALK 2571 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). Accepted rig @ 0800 hrs, 08/14/84. Killed well. ND tree. NU BOPE and tstd - ok. Pulled tubing and packer. Set R-3 pkr ~ 7400'; tstd casing to 3000 psi - ok. Perf'd 7674' - 7676' w/4 spf. Set top of bridge plug @ 7760'WLM. Set EZSV cmt retainer ~ 7580'. Pumped and squeezed 200 sx Class G cmt. Drld cmt EZSV & bridge plug & chased to top of Vann gun fish ~ 7931'DPM. Ran GR/CCL/CBL f/7000' - 7840'WLM. Tstd lubricator to 1000 psi - ok. Perforated the following intervals w/12 spf, 120° phasing: RIH w/gauge ring/JB to 7830'. Set 2-B W/L pkr (& 7721', HB-1 pkr @ 7344', & SSSV @ 1908'. Dropped Disp well w/diesel & Kuparuk crude. Secured well 7560' - 7563' 7550' - 7560' 7540' - 7550' 7525' - 7526' 7515' - 7525' 7505' - 7515' 7495' - 7505' tailpipe) ~ ~699'. RECEIVED OCT 2 Alaska 0il & Gas Cons. Commission Anchorage Ran 3-1/2" completion assy w/tail ~ ball & set pkr. ND BOPE. NU tree & tstd to 5000 psi - ok. & released rig ~ 1330 hfs, 08/25/84. J14. I here that the foregoing is true and correct to the best of my knowledge. Signed f /,,---// /~/ / v /--- The spac~el, ow ,or/~/~n ission use Conditions of Apprd~al, if any: Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev_ 7-1-80 GRU1/SN71 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. .... ~ ~.~ x:: 9~:~ lC . ..-;.':c.~.~ ~[~T 277 5£37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ansmitted herewith are the following items. Please acknowledge receipt and return one 'signed copy of this transmittal. ' P~B.U '~SLRVEYS/PRESSLTRE ANALYSIS -flA-2" 5/11,12/84 Torque Turn (Pressure & Temp Surveys) /1B-Il.J? /lC-1 /1C-6 /_J.G.10-' zlF-1 ~1Y-7 7/06/84 Camco 7/10,12/84 Camco 5/10/84 Otis 12/17/83 Otis Static 8/04/84 Otis 12/2!/83 · Camco 12/23/83 Camco 8/11/84 Otis 5/21/84 Camco 5/13,14/84Torque 2tzm (PressUre & Temp Surveys) '6/26/84 Camco Static 6/30/84 Canmo 5/26/83 Camco HP 8/11/84 Camco 6/28/84 Camco 7/07/84 Otis 12/27/83--'.Otis Static 12/14/83 Otis 12/15/83 Otis ~ .. ,. 7/03/84 Otis "' 4/10/84 Camco Receip 7 ~ac~nowledged: B. Adams · F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D C. R. Smith Sohio Union Well Files Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: . . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 · smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2cB~19)- 5/28/84 11/o9/83~ .. 2C-2 11/09/83 2C-6 11/08/83 2C-7 11/08/83 '-i-.~~ 4/18/83 ~~--:' 4/24/83 ~4> 4/22/83 ~~. 4/30/83 _ZV_~ 4/28/84 ~ "(,2~) 4/29/84 £~v-3~ 5/04/84 '~V'J-~5/06/84- " 2X-5 8/12/84 .. s/o8/8 3C-6 5719184 3C-6 5/17/84 .. 'Otis Lynes 'Lynes Lynes Lynes Camco Camco Camco Otis C~o Camco Dresser PBU Flow Survey (Gradient). Otis Static Gradient Otis Camco .. Dresser Dresser Mini Drawdown & Buildup Survey /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R ~ D C. R. Smith Sohio Union Well Files ARCO Alaska,. . Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 21, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached following in duplicate are subsequent not wells at the Kuparuk River Field: Well Action Dat 1F-2 Fracture 8/2 1F-10 Conversion 8/1 1F-11 Conversion 8/1 1F-13 Conversion 8/1 1F-15 Conversion 8/1 1G-3 Fracture 8/1 1G-4' Fracture 8/3 1G-5 Fracture 8/1 1G-6 Fracture 8/1 1G-6 Conversion 8/2 1G-9 Conversion 8/2 1G-14 Conversion 8/2 1G-16 Conversion 8/2 2C-7 Fracture 8/1 If you have any questions, please call me a ices on the e Performed 3/84 3/84 2/84 6/84 6/84 0/84 0/84 0/84 2/84 8/84 4/84 4/84 4/84 4/84 t 263-4253. Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany "~'~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~,OMMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC, 3. Address P. O. BOX 100360, 4. Location of Well SURFACE LOCAT I ON: T12N, R109E, 5. Elevation in feet (indicate KB, DF, etc.) 12. ANCHORAGE, ALASKA 99510 1129' FSL, 264' FWL, Sec. 29 UM (RKB)90' 7. Permit No. 82-1q9 8. APl Number 50- 029-20824 9. Unit or Lease Name .... KUPARIIK RIVER IlNIT 10. Well Number .. 1G-3 11. Field and Pool 6. Lease Designation and Serial No. ADL256~.0 ALK 257! ._POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data KUPARUK RIVER F i ELD KUPARUK RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). On August 10, 1984, the "A" sands of Kuparuk well 1G-3 were hydraulically fractured and propped to improve production. treatment consisted of 202 BBLS of gelled water as pad and fluid and 10,000 LBS of 12/20 sand as proppant. The carrying Prior to pumping, equipment and lines were tested to 5000 psi. sand was tagged with R.A. tracer to aid determination of job performance. The 14. I herebyce~n i ~~rrect to the best of my knowledge. KU P^RUK Signed Title OPERAT IONS COORD I NATOR The space below for Commission use 9/18/84 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 10, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are notices .of intention to fracture Kuparuk wells 1G-1, -2, -3, -4, -5,.-6, -7 and -8. If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JUL Alaska Oil & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRich/ieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC, 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4. Location of Well SURFACE LOCATION: 1129' T12N, R109E, UM FSL, 264' FWL, Sec. 29 7. Permit No. 82-1q9 8. APl Number 50- 029-20824 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 10-3 11. Field and Pool KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KUPARUK RIVER O I L (RKB)90' ADL25640 ALK 2571 POOl 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 ~I~ Abandon [] 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 in 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). it is proposed that the "A" sand in Kuparuk well 10-3 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant and pre-post frac logs are included in the treatment program. Fluid: Gelled Water Proppant. 12/20 sand ANTICIPATED START DATE- BBLS 179 LBS 11 , 000 July 25, 1984 Su~osequent Work Beporte~l on Form No. ~Datecl --~--/J-~/~ RECEIVED J U L 1 21984 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS COORDINATOR The space below for Commission use Date 7/10/84 Conditions of Approval, if any: ORIG;NA[ SIGNED BT (.ONNIE C. S~llTll Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. f Post Office r=,,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 9, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1G-3 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1G-3 to a selective single completion. Since we expect to start this work on July 28, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ng Engineer JBK/JG/tw GRU8/L38 Enclosures RECEIVED JUL o 1 184 Alaska Oil & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,. _, AND GAS CONSERVATION CC..,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 'COMPLETED WELL ~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-419 3. Address 8. APl Number P. 0. Box 100:360, Anchorage, AK 99510 50- 029-20824 4. Location of Well Surface: 1129' FSL, 264' FWL, Sec.29, T12N, RIOE, UM TD: 1335' FSL, 3981' FEL, Sec. 30, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 90' 12. I 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1G-3 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). ARCO Alaska, Inc., proposes to convert well 1G-3 to a selective single completion. The procedure will be as fol 1 ows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. A retrievable packer will be run to verify zone isolation between A and C sand. 4. The well will then be completed as a selective single. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. subsurface Safety valve will be installed and tested upon conclusion of the job. 'ECEIVED Estimated Start: July 28, 1984 BOP equipment will be tested weekly and The JUL 1 01984 ,Alaska 0il & Gas Cons. C0mmJssJ0rl Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title T h e ,P ac e b,~w'~ry,~ i s~ii o n/~ se Conditior~ of AP~, if any: ' ~pprov~ Date Returned Approved by 'J~ ~/ .I , '% By Order of ~ ~, ~J~' ,~ COMMISSIONER the Commission . · -..~ ~ Form 10-403 GRU8/SN15 ~ .~ Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. · Post Office B~,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 31, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 _~.'1 ENG(~ --'3 ', fii'~::.) .... _.]" 4 ~ '~ o~o~ ...... ~ STATT~C I SUBJECT' 16-3 Completion Report Dear Mr. Chatterton' The 1G-3 Completion Report, dated 11/13/82, incorrectly lists the squeezed interval as 8482'-8484'. The correct interval should be 7432'-7434'. Please make this change to your records. If you have any questions, please call. Sincerely, Gruber Associate Engineer JG'llm CC' R. W. Crick, ANO 912 G. L. Alvord, ANO 342 E. A. Simonsen, AFA 311 Well File 1G-3 RECEI IEI) FEB.'- 1 tg$3 Nasl~ 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany TO: William VanAlen D. W. Bose/Lorie L. Johnson TranSmitted herewith are the following: PI.WASE NOTE: BL- BLUELINE, S 'SEPIA, F- F~4, T- TAPE ('/o--,3 PT~ASE ~ R~CEIPT TO: ARCO ALASKA, INC. /~l~k5 0ti & Gas Cons. ~omm~ss~ult ATrN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post..,grffice ?"~'"',360 Anchorage, ~,,aska 99510 Telephone 907 277 5637 November 12, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: State Reports Dear Mr. Chatterton' Enclosed are monthly reports for October on these drill sites' 1-21 18-7 1-22 18-10 6-23 1E-26 6-24 1E-27 7-15 · 1F-7 13-14 1F-8 13-15 1G-4 WSW-4 WSW-5 WSW-6 Also enclosed are well completion reports for: 1-20 1G-2 6-22 1G-3 13-16 WSW-3 1E-30 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-20 and 13-16. P. A. VanDusen District Drilling Engineer PAV-JGOI'ltc Attachments NOV 1 8' Oil ~', ,Sas C:~r~o, ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany ,r--~"'~ STATE OF ALASKA ALASN ..... ,,/AND GAS CONSERVATION, MISSION WELL COMPLETION OR RECOMI LETION REI ORT AND LOO 11 Status of Well Classification of Service Well OIL [~ ' GAS [] SUSPENDED [] 'ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-149 3. Address 8. Alii Number P. O. Box 360, Anchorage, AK 99510 5o- 029-20824 , 4. Location of well at surface 9. Unit or Lease Name 1129' FSL, 264' FWL, Sec. 29, T12N, RIOE, UN -'~ATi~ Kuparuk River Unit At Top Producing Interval YF[~Ji:IEI) 10. Well Number 1102' FSL, 3517' FEL, Sec. 30, T12N, RiOE, UM Surf.-.,-'~' 1G-3 1335' FSL, 3981' FEL, Sec.-30, T12N, RIOE, UM -- Kuparuk River Field, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool 90' RKBJ ADL 25640 ALK 2571 12. Date Spudded09/20/82 13. Date T.D. Reached10/01/82 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°r° 116' N°' °f C°mploti°ns10/08/82 N/A foot MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8489'MD,6951'TVD 8371'MD,6848'.TVD YES[iX NO[--1I 1875 feetMD 1500' (approx) 22.'Type Electric or Other Logs Run DIL/SP/GR/Cal, FDC/CNL, BGT, GR/CBL/CCL/VDL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH, MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 79' 24" 325 sx ASII 10-3/4" 45.5# K-55 Surf 2302" '13~1/2" 1400 sx AS II't' & 25£' sx AS I 7" 26.0# K-55 Surf '8464' 8-3/4" 900 sx Class G '& 25£ sx AS I , 24. Perforations open to Production (MD+TVD of Top and Bottom and .2'5. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7772'-7825' 3-1/2" 7422' 7342' 7540'-7563' w/12 spf 7495 ' -7526' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ~'~ 250 sx Class G ?,-t$,z'- 7 f s,t '_ t/~r// , . . : : 27. N/A , PRODUCTION TEST Date Firs~ p'rOduction · I'Method of Operation (FloWing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED' ;, O'IL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATEII~ , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of. ~ ~ , oi., gas or water. Submitc(~i~sE/VED None ,. : tVOV 1 a 1982 Alaska 011 & Gas Cons. Commission 'AnChorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7495' 6104' N/A Base Upper Sand 7562' 6:[60' Top Lower Sand 7750' 6317' Base Lower Sand 7876' 6422' 31. LIST OF ATTACHMENTS _Drilling History, Gyroscopic Survey (2 copies) ,. 32. I hereby cer.,tify that the foregoing is true and correct to the best of my .knowledge Signed ,..~.~'-~1~-~ Title Sr. Drilling Engr~ate __-- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ,,.~!tem 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any a~tachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the. data pertinent to such interval. Item 21' Indicate' whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas In_...,, .tlo; ~, ........ Otb ............. DS 1G-3 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 203'0 hrs, 09/20/82. Drld 13-1/2" hole to 2330'. Ran 58 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2302'. Cmtd 10-3/4" csg w/1400 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg.EMW - ok. Drld 8-3/4" hole to 7903'. Ran DIL/SP/GR/Cal f/2302'-7886' & FDC/CNL f/2802'-4500' & 7280'-7860'. Ran BGT f/5960'-2302'. Cont drlg 8-3/4" hole to 8489' TD (10/01/82). Ran 7", 26#/ft, K-55, BTC csg w/shoe @ 846~. Cmtd 7" csg w/900 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. PBTD - 8371'. Ran Gyro & GR/CBL/CCL/VDL (shows poor bond). Reran GR/CBL/CCL/VDL - poor bond. (Arctic packed 7" x 10-3/41'_, ann w/300 bbls H20 250 sx AS I, & 100 bbls Arctic Pack.) Perf'd-~:,~ -~_~.- w/Sspf. RIH & set cmt retainer @ 7380'; sting into retainer - squeezed 250 sx Class G. Ran CBL - good bond. Ran 3-1/2" completion assy w/tail @ 7422' & pkr @ 7342'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set pkr & closed SSSV @ 1875'. Dropped perf bar & perf'd. Secured well & released rig @ 2400 hrs, 10/08/82. RECEIVED NOV 1 8 1982 Alaska 0il & Gas Cons. Commission Anchorage JG-11m 11/08/82 COMPLETION REPORT ~ ..... ARCO ALASKA, IHC. ~,, .... GYROSCOPIC SURVEY :. ~<., RADIUS OF CURVATURE METHOD OF COMPUT.AT!ON ': '~:~' C01,1PUTED FOR SDI BY OCEANTECH(FM LINDSEY & ASSOC;,:,,~:>' HEAS. DRIFT DEPTH ANGLE D 1,1 0 0 0 100 0 17 200 0 19 300 0 15 400 0 20 500 0 14 6,00 0 21 700 0 31 ~0~ 0 5 900 0 ~! 100o ! 7 1100 ~ ~ 1200 6 31 13'00 9 59 1400 13 18 15,0.0 16 55 1600 19 53 17.00 21 49 1800 23 21 1900 25 200'0 26 59 21:00 28 55 22~0 31 23 2300 33 29 24~ 34 35 19 OCT 82 KUPARUK 6-3 KB ELEV 90, JOB NO 2807 TRUE VERTICAL DEPTH ,'00 100,00 200,00 .::.. .;::RECORD .¥'i'. SEA · -. OF SI 1 O, O0 H42.1. OW ~.110,00. :30.0, O0 210. O0 400. O0 31 O, O0 499,99 .' "-4.09. 599,99 '.i:: 5:09,9,9 ':" N§5 699 i99 ?.9.9,99,':'!: 899,99: ~,.': 8.09,99 < ', 999,98 :"" 9.'.09 ':,'~98'i"-:: .. 1,34 1099;88 :1'009,88 J199 48 $109,48 ~..i ' "'" :4' 1298.4~ 12.08.4~ 1396,36 . 1,306',36 1492,89 .1.'482,89 33W. : ,~' 8,3 t587,76 'r1497', 76 S87.,75~'' 8,77 1681.21 ' :.'1'591,2 1773.54 1'683,54 seT,.9$a ,37 1864.72 ~ 774,72... 1954,55 1864,55 Nee";2e .,12,54 2042 ~ 8s t952, s8 2129.35 2039,35:' 2213.74 2123.74' Ne5.45~ 3 223~ 6~ 2206,6 FT. C L O"'S U R E S D I STANCE ANGLE D I'1 ,.O0 W .,09 W .'49 W' ,87 W ";67 W '. e tific .: !:ldllimg · 'lCiebrRational :.".,.83 E -- 2.80 W' '45.83 W 71.89 W 44 ~ 138'~ 99 W' · 1;77,35 W 18,39 W 62 ;31 W 3W 359;25 W ~,54 W %. .00 8'90 0 0 ,24 H 21 3 0 ,50 N 77'34 38 ,87 S 89 li 22 ,72 N 67 2.16 ,75:'S 8S 10 56 ,91..N 7-0 '22- 8 ,28 N 35 49 14 ,.32 H '77 '5~ 59' DOG LEG SEVER I TV ' DEG/J OOFT W W W W W W W W E' · 80 8? 84, 50 25 E 1.58 "8.31 52 56 E: 4,26 ,S 41" 5 9 W 12.46 S 67 20 19 W" 26,59 S 75 t0 23 W 46.55 S 79 54 59 W~ 72,37 8 83"23 20 W 103,81 S 85 9 18 W 139.39 S 85 39 59 W 177.78 S 86:0 30 W 218.79 S 86 33 262,61 S 87 15 44 W', 309.3~ S 88 4 16 W 359.3~ S 88 50 50 W 412,75 S 89 32 11 W 468,54 N 89 .53 7 ,000 .287 .. 0,34 .067 .084 ,100 .I17 . 167 ,.433 ,433 .601 . 2,520 2,883 3,468 .3,326 3',621 :2,986 ! .940 1,548 1 ,818 1 ,888 I ,978 2,468 2.113 1-. 105 SECTION DISTANCE O0 10 50 87 68 74 ,87 -,31 -. 8.0 -,90 2,64 I i 25,35 45,38 71 .40 1 02,90 1 38,32 I 7'6~ 54 217,50 261 ,40 308.27 :458';48 412.10 468.04 C) ARCO KUPARUK HEAS. DRIFT DEPTH ANGLE D M 2500 35 24 2600 36 1 2?.00 36 46 3000 39 15 3100 40 22 3200 41 32 3300 43 ? 34.00 44 3550 45 5~ 3600 45 365 0 44 1 ~?00 43 3750 42 56 3800 42 J850 4~ 49 3900 44 18 4000 44 4100 44 44 4200 45 43O0 45 1 4400 45 19 4500 45 32 4~00 45~40 4700 45 40 4800 45 42 4900 45 20 G-3 GYROSCOPIC SURVEY JOB NO 2807 TRUE VERTICAL DEPTH SUB SEA , sU.VEY ":? DR IFT DIREC 'DEG. ,-. TOTAL. CO~ 4ATES .. . : · . 2378.54 2459,65 2540.06 2619.85 2698,97 2777.08 2853.90 2929.43 3003,36 3075.24 2288,54 Ne5,.6?W 5 2369,65 ' Nes,sSW >. 9,69'~'N' 2450,06 ',, N85.02~ ? ":'1,4,5e ,N 2529:85 ~H84;35W '- 20,17 .H' 2608,97 ' N84;'20~ .';:' 26,27 N 268?, 08 H83.,65~ '::' .:: 32 2763 ,. 90 2839,43 H82';82~ ".~' .. 48, 2913,36 NB 1 ,.9'OU .. ? '"'57., 2985;24 N81 ~27~ 6: :3145.03.- 3055,03' NS'l 3179,61 3.089:, 61 i '/':::. 8 :321.4.59 3124.59.,, 325:0,18 '.3.160,t8...Se~,4?W~'~:~:~.~ 84,32 3~22.75 3232,75 ~'-$80,43~>"': :27 710 H 3359.35 3269,35 $76,.36~ ." .':'70,:26 H 3395.70 3305,?0 'S74,62~ 61.66 N 3431 .63 3~41,63 gP.4,45W 52,39 H CLOSURES DISTANCE ANGLE D M .. ?3 W 525,75 N 89 25 4,04 W 584,12 N 89' 2 ,43,29.W 643.45 N 88 42 03;31 W 703:60 N 88 21 W 764,6i N 88 i ~26.,24 ~ 826,89 N 87- 43 84 W 89'0,75 N 87 24 89 W 956,-10 N 87. 6 ~~ 1023.22 H e6'-.47 tifi 163.e2 H ligg 1199,88 .'N 86 atio s. 1270,60 N 86..;11 1304,84 N 86. '24 1338.41 N 86 41 1371134-N 87 3 1404..14 N 87 28 1437.25 'N 87' 54 3503.01 3413.01 S74.15W 3574.13 3484.13 S73,43W 3644.89 3554.89 S74.03W 3715.31 3625.31 874.53W 3785.66 3695,66 S74,98W :3855,84 .3765.84 S75;62W 3925,81 ~8:35,81 S75,52W 3995,69 3905,69 4065,55 4135.62 404'5,62 S77,~7W !67,80 19 ,9;54 "!436:;30 1504.08 N 88 43 1571.28 N 89.29 1639.07 S 89 47 '1707.59 S' 89 9 1776,5I S 88 35 1845.91S 88 4 1915.72 S 87.36 1985.73 S 87 10 2055.87 2126.11. 8 86 26 33.44 N '-i~i",,1 SO3. ? ! 13,82 N 1571.22 5.98 $ 1639~06 25,2t S i:707.40 43,89. S 1775,97 61,97 S . 1844,8~ 79,78 S ~! 1914,06 .I15.41 ~2.00 19 OCT 82 54 57 6 27 53 17 42 49 56 19 48 30 41 29 51 47 58 39 45 27 14 3 34 48 56 55 17 DOG LEG SEVERITY DEG/IOOFT .S18 .784 .614 .664 .636 1.253 1.135 1;177 1,640 1.877 1,558 3.355 3,987 4,740. 3,46~ 3.473 5.517 .2,447 .980 ,334 .379 .556 .261 .233 ,309 .143 .060 .033 ,966 0 SEC T I ON D I STANCE 525 37 58~. 83 643 24 703 46 764 54 826 86' 89 0 74 956, 10 1023,19 1 092, :37 1199,6~ 123~.~4 1270.40 1304.71 1 338.35 1:371 .1404.13 1437. 15 1503.57 157 O. 05 1636.85 1704.18 1771 .77 t839,72 1907.97 1~76,2~ 2 044.65 211.3,13 ARCO KUPARUK G-3 HEAS, DRIFT DEPTH ANGLE D H 5000 44 5 5050 44 5'100 45 5 5150 45 1 5200 45 1 5300 45 1 5400 44 55::00 44 29 .5600 44 32 5700 44 580'0 44 ::3 59.00 43 ! Lq 6000 42 4 61.00 41 34 6200 41 5 63?00 40 56 6400 40 2.5 650.0 39 38 · 6600 38 43 67.00 38 41 6800 38 I0 69..0.0 36 49 7000 36 5 71,00 34 29 72.00 34 12 730.0 3,3 22 740~0 33 17 7500 32 49 7600 33 14 TRUE VERTICAL- SUB DEPTH SEA 4206.69 4116,69 4242.52 4152.52 4270,.04 4180.04 4313,31 4223.3! 4348,60 4258,60- 4419,29 4329,29 GYROSCOPIC SURVEY .. .,, .{-. - RECORD OF DRIFT TOTAL DIREC DEG. . '. .- ... S05'.'~7~ 4490.29 -4400',29 4561,62 4471.62~'~ 4632.93~ -4542., 4704,4&~'::46!.4, 4776,28"- 4686.;'28 4848,69 .4758;:,69 4922,28 4832::28 4996.01 4906,8! 5071.90 4.901,90 5147,37 ;~' 5'057 , 37. '. 5223,2.1; ..-5133,2t N88,-I?~:., ~71 5299,78 5:209,78 NS?,'OSW ::?..t 68 . 6.1 S 143,55."$ 13'0,17~8 115,29 loO; 17 04,35 HSO.35W N?8,2FW N76.33W H74,65W N75,00W N?2,43W 5377,30 ..5287.30 '5455,35 -; 5;365.35 5533,69 5443.69 5613,03' 5523,03 5693,47 5603,47 5775,10 5685,10 5857.66 5767.66 9I/,31 !6101 5940,70 5850,70 6024,34 5934,34 6100,15 6010,15 6192.00 6102,00 47 W 82 W i24'02,44 U 55,54 W 7,!7 U 5'2,32 W 11:6,57 W W '41 ,46 W 02,53 0 '3461',90 ~ 35'1'9,42 0 3575, 16 0 3629,31W 66., 62','$ ~.' 3682,01 W 4.7, ! 9$' :;;?:3733,39. W i3., 57 O :' HTO ,37W H68,22W H65.0?W .,::, :3,4~ S · .' · !, ' .j,' JOB HO 2807 CLOSURES DISTANCE ~NGLE D H 2196.03 S 06:14 223'0,09 S 86.'12 2266,08 S 06 12 2301,51 S 06 12 2336,93 S 06 i2 2407.66 8 86- 13 2478,07 .S '86"~15 .. 2548 ,." 15 S" 067'17 2618,23 S 86'19 2688,00 S 06..22 :757,64 S 86,.24 2826,5~ S 86 27 ~4,19 $. 86 31 29.60.74 S 3026,61 S 86 41 3092,02 S 8,,6~47 3156.97 8 06 53 3220,99 S 86 59 3203,62 $ 87 8 3345..06 S 07 20 3405,56 S 87 35 3464,35 S 87 50 3521,30 S 88 7 3576,57 S 88 23 3630.29 S 80 40 3602.61 S 80 57 3733.69 S 09 16 3703.66 S 09 36 3033,27 S 09 56 19 OCT 8'2 'S DOG LEG SEVE,RZTY bEG/1 0 OFT 20 3? W 14 W 23 W 45 W- 9 W 31 W 6 ~ 29 W 25 26 W 33 W 2t W 22 W 57 W' 36 w 33 w 2 w 47 w 25 w 42 w ~ W 48 w 32 W 31 W 52 w 3,080 .219 ,639 .362 .354 .505 .15'3 ,227 ,40.0 . '087 1,000 ,159 .572 .559 .250 ,537 ,906 .531 .394 ,949 .518 .937 ,604 ,859 , O42 ,653 .878 ,420 SECTION P I S TRNCE 2181 78 221 6 28 2251 21 2286 42 232 i 63 2391 98 2462 06 2531 84 ., 2'601 67 2671 31 2740.65 2809.42 2877. 00 2943.60 3009,59 3075,10 3140.35 3204,66 3267.79 333 0.06 3391 .61 3451 ,56 3509.73 3566.14 3620.98 3674,48 3726.74 3777,9O 3828 62 © ARCO KUP~RUK G-3 ~YROSCOPIC SURVEY JOB HO 2807 OCT TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB SEA RECORD OF .... DRIFT TOTAL DIREC DEG. CLOSURES DISTANCE ANGLE D H S DOG LEG SEVERITY DEG?iOOFT .7700 33 23 6275,57 6.185.5.7 H6.6,.iS'W 18, 7800- 33 38 6358.95 6268,95..H66.08W - 41, 79,00 32 50 6442,59 6352,59' N65.,38W 8000 3l 44 6527, 14 6437, 14 N64.,3eW 8200 29 50 6698.82 6608,82'N6'I;l'OW 132, 8300 29 16 6785,81 6695,8] N58,,75~ ~'?," 157. IS EXTRRPOLATED,. TO'TD ,, THE FOLLOWINGa 8489 29 16 6950,6 "W 3883,49 N 8,9 43 t8 W ,92 W;. 3934,14 N 89 ;23 5'9 W 9'83;.'88 W .24 td ,93 W 1'23,67 W _ .173 .25! 3984,39'N 89 ,5 0 W ,826 4.033,17 N 88 46 21 W 1,174 4-080.39 N 88 27 54 W ' ,845 4125.81 N 88 9 16 W'." 1,233 4169,33 N 87 5'0 2 W ,798 ng :;i InternaUonal . ,000 SECTION DISTANCE 3879. 3931 3982,30 4031 . 70 4079.44 4125.27 4169,09 4250,31- © 0 ~RCO KUP~RUK ~-3 GYROSCOPIC SURVEY JOB NO 2807 19 OCT 8'2 0 MEASURED DEPTH AHD OTHER DATA FOR EVERY EVEH t00 FEET Of SUB SEA DEPTH. . TRUE " MEASURED VERTICAL SUB' MD-TVD VERTIC'RL DEPTH DEPTH SEA DIFFERENCE C.OI~REC~'!.ON TOTAL COORDINATES 0 190 290 390 490 590 690 790 890 990 I 090 1190 1291 1394 1497 1602 1710 1818 I928 2040 2154 2272 2392 2514 2638 2762 2889 :3017 314,9 3282 3421 3565 3705 3842 3982 .0, - -9O '190, '1 O0 .. 290, 200 .0 .... 39'.0, 300 : ':"';'.'0 " 490. 400 - .;..'O 590, 500 .. ;."::."..'0 ,. 69:0, 600 "" ''" "0 790 700 .. ,. ., . 890. 800 99 O, 900 '-' ..: 090, 1 000 ' 290.: ',:'1200 .. 1390, 1490, 159'0, 1690, 189,0.~' 1990, 209.0, 2190, 2290, 2390, 2490, 2590, 2690, 2790, 2890. 2990, 3.09.0. 3190, 3290, 339'0, 3490.- '1300 :14 1500 160.0 1700 1800 1900 2000 ;~' -64 2100 .81. 2200" -'I01 2300 !24 2400 147 2500 172 2600 1.98 2700 226 2800 257 290.0 '-291 3000 330 3i00 374 3200 415 3300 452 3400 49t .00 ,16' ,05 .29 · 06 .27 ,05. /.,:... ,03 I ,19 3,03 4,62 ,, - 8,18 bcientifice, 34 Drilling o. eo InternatiibBaT4 12,61 _.- 13,13 li ,88 0.74 4,54 ,60 5.83 1t .46 17,98 25.56 34.05 43.95 55.44 69,59 83.27 81 . 3.7 63, .09 36', 93 S N S. N $ H N N S S S S S S S' S N N N N N N N N N N N N N- ,00 tO -" .47 W ,84 W .72 W .70 tO .... 89 hi .;23 to .29 E -.; ,..~ ~- ,92 E 2,23 to ~.10 ,'46 tO 24,26 to 44,35 W 711,02 W 1:04,26 to 'J 42.. 53 to 104,50 W 230;39 W 280,65 W 335,83 Id 397.26 W 464,03 W 533,90 to 606 o- , ~. ~:. W 680.71 W 757.22 W 836.77 W 92'0,60 to 1 009.30 W 1105.05 W 1207.67 W 1305,75 W ! 397,, 56 tO 1491,~'40 W 0 RRCO KUPARUK G-3 NEASURED DEPTH AND OTHER DATA FOR EVERY EVEN TRUE HEASURED .VERTICAL DEPTH DEPTH 4122 4264 4406 4549 4692 4835 4977 5117 5259 5400 5540 5680 5819 5956 6091 6224 6356 6487 6616 6744 6871 6996 7118 7239 7~59 7478 7598 7717 78;337 7956 8.074 8190 8419 SUB 'MD.TVD SER DIFFEREHC£, ~.. 3500 3600 ~574" '-"-!'. 37.00 GYROSCOPIC SURVEY.' JOB NO 2807 .. !0;0 FEET OF 'SUB. SEA DEPTH, '" -. :.'.,:J '~,:_ ~.' TOTAL COORD ! NATES 359'0, 3690, 37.9.0 .~ 3e90, ,.. '~i 3800;..,./~':'.~ 658' '39eo,. '~- 4.09.'0, 4190 ;'.~": '41 00~''~ 4390 .449'0 4590.". 450.0 4690,.~' ,. ~.- 4 499'.0, Bi 9.0; 6 B29.0. ' :.~: 5200~ 5690, -5600. A..3'05 5790,, 57.00./': i 328 5890, ,.~:'5888 I349 5990, .,590 e ' 6090,.. 6000 ~,'13~8" 6190, 61 O0 6298,'. ,. 6200 1427.". 6390, . 6490, ~4OO, 1466. 6590. 6500 1483 6790;?'~' ..'.'6700 1514.~ 6890,'",'. 6800 ~951 ,. 6861 9,35 N !586.;31 18. ;36 S 1682,81 45.03' S 178'0.22 70,64 S 1878,63 96.17 S 19'77,,69 21 49 41.e5 $ . 2t?$,~9 50,808. 22?3, 09, 56. :78 S 2373, i ? 61 , 83 8 ...-."'.~ 24,72., 49 66,21 S · '~ ,i.' .:.' · · 42 ~.?,,'-..~,.-': . ' · "-' .;~ :~;- "."L ' ' '.'., 40 ~..:~.'~: :"'; :' ':' ' i ,. .... 42 ,'"" , '' ' '~ ~' ~t; ~ 41 .%'~'". I I 4.O g:;~,~. ::. :. · '~c~enu ' ' "' ~ e 4 q~? Dr, ll,ngl.z4.32' s :~~. 31:~"~ " 2g '". . 28,. W W W W W W. . W . . W W 19 OCT 82 W W W W, W W W lnternati~at ?. s;,? ,94 u 169,'02 $'. -32.08',4;3 td 150,:23 S ,'-3368,67 134,20 S 3445,01 97,49 s' ,.35e5;02 u 77,62 S '3650.08 W 55,40 S 3712,38 W 30,63 S 3772,84 4,01 S 3832,08 W 22,'70 N ~'~3~92,16 W 49.57 N 3952,6~ 76,45 N' .':4'0].],30 W 103.24 H 4066.78 W 130.41 N 4119,21 -'I 58,8.0 H' ..'. '4168:.,' 36 W 205,'5~ N 4245,34 W .... . , :; . · © ARCO KUPARUK GYROSCOPIC SURVE¥~~ ,JOB NO 2.807 INTERPOLATED VALUES FOR EVEN ', TRUE MEASURED VERTICAL DEPTH DEPTH 0 '0 o J 000 1000. 2000 - 1955. 3000 2777. 4000 5000 60.00 7000 8489 I00,0 FEET OF. HEA$'URED;,i~;~;.iEPTH. .- -, SUB SEA ~ TOTAL -90. 910. 1865. 2687. 3503, ' "' 341 ~ .... 5693;,: :~,- 5603; 6527. "': 6437 6951 ,.:"~.-~ Scientific g .International · . 19 OCT 82 ,] 0 ARCO KUPARUK INTERPOLATED CODE MEASURED NAME DEPTH TP UP/SD BASE UP/SD TP LW/SD BASE LW/SD PBTD TD GYROSCOPIC SURVEY ....: JOB NO 2807 TRUE VERTICAL DEPTH~ 'COORDINATE8 fiND CLOSURES FOR GIVEN DEPTHS TRUE ,..¥ERTtCAL .,7;{:~TOTAL.. '.~: .... C L O S U 'R E - DEPTH --- '~,.';-....."-,.-~'' DISTANCE ANGLE .. . . ~. · . ,, -,, . . 7495 7562 77'50 7876 837! 8489 -, · , '? '-;~ ;684? ,.~ 75,59 378 !, 20 3814,33 3908,76 3972 ~ 44 4"199,69 4250.31 19 OCT 82 SUB SEA ii 89' 35 29 W 6013..95 $"89::49~,11 W . 6070, H 89 :..33':: :3'6 W 6227,29 _ N 89~i'-'9~32 W 6332,45 'N," $?..:':.36..13 U-. '6757,74 N 87:~,i,3," 42 W . 6860 ; '1-? '.*'- ..--r- · :;: i' ......... !"T'r-?'";" ," . . -'74..: --. '. '- ....... : .-!--.[ .-',.-;---; ..--i...~.. :':::. ,.':":"-::' i i" : ' ' ' .-: .... -:-4.-,--4. . i': ...... .~ ....... t"t ..... '~"~'r"' ..... : ' · ~, "- ~ ..... t' ","'-~'! ...... .......... ; ....... ~-. ~...b 4-.---' .... 2.9-- .....F-+ .....· ..... I ' r'-4'--:-.k.-{--: ....... ............... 1... ', ...,.....;- .... ;~ ...... :- ' ?. -I. : ...... ..... r - '---...~ ........... .i- ' ,,i i suggested form to he inserted in each "Active" well folder to d~eck for timely compliance 'with our regulations.' ' Operat°f, ~ell -N.a~e' 'and 'Number Reports and Materials to be received by: II-~ Date Required · Date Received Remarks · _.Ccmpletion Report .Yes. '/1--/g-~. / ~ f~__ ..... Well History Yes /f"'~ .. Samples : ....... .,? :P.t -- d~,.. ~- .... , , , , ..... .. ... ,, Core Chips .>/'h"d ~~ ' ' - ,~ , ~ , . ' ., . Core Description · Registered Survey Plat 7~~ ,. ?.~, ~_. ~ ,,G~/' ·, , ,. ~ .... . .,, ,, ~ . ' . Incl±nation Survey ,,/!z:t/] . ~ ~ . , . ~ , , , , , , DirectionalSurvey \/¢~: ! I- i ~-~' ~- ~ 'm,.~ L::'~'~:. . · Drill Stem Test Reports '///d A/'Y% .. ,~ ,, , , , . ,.. ,, ,, , ,.,. , / ms ,,u,, , ~s Digitized Data y~.~ . . ........... KUPARUK ENGISm~,RING TRANSmitTAL #/?~/~ TO: William VanAlen FROM: D. W. Bose/Lo~ie L. Johnson Transmitted herewith are the following: ~ . ARCO'~Aia{ka~lnc. Post Office Bo~ Anchorage, Alaska 9.9510 Telephone 907 277 5637 October 14, 1982 Mr. C.-V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas'Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 · SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are mOnthly reports for sePtember on these drill sites' 1-19 18-6 1-20 18-7 6-21 1E-28 6-22 1E-29 13-16 1E-30 13-34 1F-6 1G-2 1G-3 WSW-3 WSW-4 A1 so enclosed are well completion reports for' 2-26 1G-1 6'-20 14-15 (completion report & subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be Submitted when an approved, survey is received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG'llm Enclosures GRU2/L15 ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany STATE OF ALASKA ~ ALASKA ('-'~AND GAS CONSERVATION CO. ~lSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well Workover operation I-] 4. Location of Well 1129' at surface 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-149 3. Address 8. APl Number P. 0. Box :360, Anchorage, AK 99510 50- 029-20824 9. Unit or Lease Name FSL, 264' FWL, Sec. 29, T12N, RIOE, UN Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) 90' RKB 10. Well No. 1G-3 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. ADL 25640 ALK 2571 Kuparuk River Oil Pool For the Month of September ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 20:30 hfs, 09/20/82. Drld 1:3-1/2" hole to 2:3:30'; csg, Dr]d 8-3/4" hole to 790:3'; running logs as of 09/:30/82. ran, cmtd & tstd 10-$/4" SEE DRILLING HISTORY ~ 13. Casing or liner run and quantities o~ement, results of pressure tests 16", 62.5#/ft, U-40, weld conductor set ~ 79'. Cmtd w/:325 sx AS II, 10-:3/4" 45 5#/ft, K-55, BTC csg w/shoe ~ 2302' Cmtd w/1400 sx AS III & 250 sx AS I.' SEE DRILLING HISTORY 14. Coringresumeandbriefdescription None 15. Logsrunanddepthwhererun None to date 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 1/7. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED , _ TITLE Seni or Dri 11 i no. Ennl n~.~rDATE . , . rtl w , , ! NOTE--Repo th~'sforr~ is requiied for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU 2/MR9 Submit in duplicate DS 1G-3 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2030 hrs, 09/20/82. Drld 13-1/2" hole to 2330'. Ran 58 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2302'. Cmtd 10-3/4" csg w/1400 sx AS III & 25-0 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 7903'. Running logs as of 09/30/82. JG:llm 10/06/82 GRU2/DH9 TO: William VanAlen Transmitted herewith are the following: D. W. Bose/Lorie L. Johnson PLVASE N(7i~: BL- BI/JELINE, S - SEPIA, F - FII~4, T- TAPE, PC - PHOTOCOPY /~A~: ~/~~E RERI/RN Rt~/EIPT TO: ATIN: LORIE L. JOHNSON - AFA/311 ............ P. O. BOX 360 ANCHORAGE, AK. 99510 MEMORANDUM Sta e of Alaska TO: C. ~. ~~t~.erton DATE: October 7 1982 Cha~~ ~' ' THRU: Lonnie C. Smi th ~.~l/~ FILE NO: 108A/C Commi ssi oner FROM-Doug Amos Petroleum Inspector TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO's Kuparuk 1G-3 Well Sec. 29, T12N, R10E, U.~. Permit No. 82-149 on Parker Rig No. 141 .W. ed.~sdaY_,' $_ep~em_ber _22,. 19.82- I traveled this date from Anchorage to Prudhoe Bay to witness the BOPE test on ARCO's Kuparuk 1G-3 well. The BOPE test was delayed because of hole problems. -T~ursday,_ September_.23J. 198_2 - The BOPE test commenced at 5:30 p.m., due to the top pipe ram failure the test was stopped at 6:15 p.m. The entire ram body had to be replaced because of a washout inside the unit. F_ri~day,__$_ept~mb~_._r 24,_. !_982 - The testing commenced again at 6:30 a.'mo' and' ~-S Concluded at 7:40 a.m. I filled out an A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the BOPE test on ARCO's Kuparuk iG-3 well. The upper pipe ram unit failed and was replaced and retested. O&G #4 4/80 Inspector OPerator Well STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Well Representative Permit # _]~ ,~Casing Set Rig % / 4/ Representativ~ Location: Sec Drilling Contr. actor Location, General ~. Well Sign . General Housekeeping , Reserve pit Rig ACCUMULATOR SYSTEM Full Charge Pressure. ~,.~d) psig Pressure After Closure ,/5~0 psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: ~ N2 ~_3~O/ ~/Od/ ~50; ~O psig Controls: Master ~ Remote ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly. Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold BOPE Stack Annular Preventer ~¢ Pipe Rams ~'~ ~ Blind Rams ChOke Line Valves Check Valve ~/ / Test Results: Failures I ~est Pressure ~Test Pressure Test Pressure ~Test Pressure Test Pressure Test Pressure ~ 0 t~o No. Val ve~ No. flanges. Adjustable Chokes Hydrauically operated choke min ~ sec. min ~ sec Test Time / hrs. ~ ~ '~ · Repair or Replacement of failed equipment to be made within. days and Inspector/Commission office notified. Distribut ion orig. - AO&GCC cc - Operator cc - Supervisor Inspector September 10, 1982 Mx. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99~510 Res Kuparuk River Unit 1~-3 ARCO Alaska, Inc. Permit No. 82-149 iur. Loc. II30'FSL, 263'F%U~, Sec. 29, T12N, R10E, Btmhole Loc. t045'FSL, 4200'FEL, Sec. 30, T12N, R10E, Enclosed is the approved application for permit to drill the above r~ferenced ~ell. Well samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the di§itized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage sys~:ems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commenc.~n~ operations you may be contacted by the Habitat Coordinator s Office,. Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the re§ulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. 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 ARCO Alaska, Inc. ~'~ Post Office [ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 31, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1G-3 Dear Mr. Chatterton: Enclosed are: An application for.Permit to Drill Kuparuk 1G-3, along with a $100 application fee. A di'agram showing the proposed horizontal and vertical projections of the wellbore. A proximity map indicating the relative location of Kuparuk wells 1G-1 and 1G-2. A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we expect to spud this well on September 15, 1982, your earliest approval would be appreciated. If you have any questions, Sincerely, Senior Drilling Engineer JBK:JG: sm Enclosures GRU1/L86 please call me at 263-4970. · Alaska Oil & Sas Cons AnChora~ Cornr~isSiort ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O,L AND GAS CONSERVATION CO,,,~vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchor age, Alaska 99510 ~Ec 4. Location of well at surface ~ ! VED I 9. Unit or lease name 1130' FSL, 263' FWL, Sec. 29, T12N, R10E, UN ~ I Kuparuk River Unit At top of proposed producing interval S~P 0 ~'i j.§~5) I lO. Well number ~ Target 1050' FSL, 3720' FEL, Sec. 30, T12N, R10E.UM ""'- I 16-3 /[la~a Oil & Gas C At total depth . ORS. C0[j]rn[J~l~. Field and pool . Anch .... ,u . . 1045' FSL, 4200' FEL, Sec 30, T12N, RIOE, UN ora§o T 't~uparuk R~ver Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. [ Kuparuk River Oil Pool 60.5' PAD, 90' RKB ADL 25640 ALK 2571 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 32 Miles NW Deadhorse miles BH 66.~ FWL of Sec 30 feet G-2 well 120' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8305'MD, 6670'TVD feet + ~. 4.5 9 09/15/82 19. If deviated (see 20 AAC 25.050) KICK OFF POINT1000 feet. MAXIMUM HOLE ANGLE 42° o 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) 2738 psig@__~_0°F . Surface :3120 ...psig@ 602,2 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Z4" I 16" 13-1/2" 110-3/4" 8-3/4"{ 22. Describe proposed Weight 65# 45.5# CASING AND LINER Grade Coupling H-40 PEB K-55 BTC BTC -- 7" 26# K-55 program: Length SETTING DEPTH M D TOp TV D 80' 30' I 30' 2269' 29' { 29' I 28' I I 28' 8277' MD BOTTOM TVD 110' I 110~ 2298' 12200' 8305' 16670' I I QUANTITY OF CEMENT (include stage data) ±200 cf ll00sx AS III 250sx AS II 1000sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8305' MD, (6670'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2738 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. · 23. I hereby certify.that the foregoing is true and correct to the best of my knowledge _~_'hGeNspEaDc TITLE Senior Drilling Engineer e be~ ~ 70 CONDITIONS OF APPROVAL DATE Samples required []YES ~'NO Permit number APPROVED BY Form 10-401 GRU1/PD28 Mud log required Directional Survey required I APl number I-~ YES ~NO ,[~,Y E S [-1NO J 50- O .~ .~ SEE COVER LETTER FOR OTHER REQUIREMENTS ~OMMISSIONER/"/'//'/ DATE ~"~'-/ 7 / by order of the Commission ' . Submit in triplicate Surface Dive,~'~r System -® I. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. .20" 2000 psi drilling spool w/10" side outlets. lO" ball valves, hyraul ically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer.~ 5. 20" 2000 psi annular preventer. 6. - 20" .bell ,nipple. Maintenance & Operation ~' 1. UpOn initial installation close annular ) preventer and verify that ball valves ) . _ have opened properly. · I 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. 3~ Close annular preventer in the event Q. that gas or fluid flow to surface is · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circumstances. 16" Conductor 1~_~,/8" 5000 P~I 'RSRRA BOP STP~CK ~ 2. 3. 4. t 1 " ' : : ::: :':-~ :: 9. _ ..._:;.~_-_- . .:....~ ;i -.. --- PIPE ).-7 (' ) .- .. DRiLLiNG' SP20L ' . ~ - 1. 2~ C- .) ) ( PiPE RRM$ . .()' ':s -.( · ) ] 6" Bradenhead 16" 2000 PSI x 10' ~S3 FSI c~sing head 10" 3000 PSI tubing head 10" 3000 PSI x 13-5/B= 5000 PSI .. adapter spool 13-5/8" 5000 PSI pipe ra~ 13-5/8" 5000 PSI drilling spool w/choke and kill lines .. ..- - o .13-5/8" 5000 PSI pipe ra~s- _-~__.. 13-5/8" 5000 PSL blind ra~ -- -.. 13-5/8" 5000. PSI anr~J, lar ..... _ ~ _ :'_.L': .... _.. ACCL~-IULATOR C~,PA~I'IT TEST . _ :_L .... ='-~ ~.. _. . ~'HECK M~ FILL ACC~T,.!LA,'TOR ?~ER'~qDIl~ l'O PRtDP-~ ~ ,-3'EI] WITr{ HYDRAULIC FI.DID.' ASSURE TI'AT ACC~-FdLATO~ PP~t~,E IS :~ PSI WITH TSO0 PSI O~SERYE TIHE Th?_N CLOSE ~ ~.,ITS SI~T~'~- OtSL¥ A~ID RECOPJ) 'FHE TI~ I,~ ~,q~R ALL L~(ITS I>'~ OFF. RECORD ON IADC REPORT. lt~ LLMIT IS 45 SE~.'(~ CLOSII~ T~,E ~'D 12:0 PSI R~tIN I'~' PP-~ESSURE. 13-5/8" BOP STA,.~ TEST FILL BOP STACK N{D I~-NIFOLD 14l]'~ ~'.PJ::iIC DIESEL. ~.ECK TP. AT AIL HOLD ~"-.~,z~ SC2~ ~.A~D. P~D~E~-:I)~ DEPT~ T~T ~I~ S~T A)~ S~T I~ ~~. ~ I~L~ ~N SC~S I~ H~. Y~Y~ OX ~XIFOLD. ~JT ALL C~4~IEI~S TO ~ ~l ~'~ ~ F~R I~;C~E PRESS~ TO lO MIIiUTES. BLEED TO ~0 }SI. PIPE ~J. I~;~E-PR~SV~ TO ~ ~I' ~{D ~ ~R lO ~E V~V~ DI~% ~~'~ OF ~. ' TO Z~0 PSI. - ' _ ~1 TOP 5~ 0F PIPE S~ ~ PIPE K~. · II;CR~E PRESSU~X T0 HII~JT~. 8~ED T0 Z~ ~I~;a JOI~ MiD PU~ ~ ~" DiD TEST T0 3~ ~I F~ i0 ~~. B~ED T0 ZERO PSI. - 0 ] I. - OI~ ~;D ~L YALY~ ~ S~ ~I~ ~I~I~ . ~ITI~I. - _. T~ ~qDPIPE Y~Y~ TO ~ ~I. ' TD ~Y ~ ~D I~I~ ~I~ ~Y P~.. PZ~ TEST IHF~'~TI~ YI~R. - ' - Z? 15 : '_~-- i _ ,,., l_, i, i i . ARCO Alaska. Inc ~'~ zg/~/zz ,~7-~' /'~' ~ate 3_~..'~~ ~'Z. ,."$~Z I sca~e C~ra~n by ',.L~, I dwg ,' "ZOO ' LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (~.) ~e..__t~ ,L~/c'~- ~9~ (2) Loc. ~ 8) (3) Admin,-n[/~[~.._x.. 9 ~3 (,9z thru l 1) (4) .Casg ~.~ ~, ~-~-~ (12 thru 20) (5) ~OPE ~.~/. ~- (21 thru 24) me 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 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 ....... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore 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 or~er needed ...' ' Is administrative approval needed ~iiiiiiiiiiii{iiiiii!ii[iiiii~iii Is conductor string provided ....................................... ,. Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons .... , ................ Will 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 well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of.diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~,f Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: Geology: Engin~rizng: __fi . VA z.z~a, JKT ~...-'"' RAD ~ ev: 08/19/82 INITIAL GEO. UNIT ON/OFF- POOL CLASS STATUS AREA NO. SHORE ~,/, o D~,,' t~, i~' f~ u )I~ ~ ~ o ~ Well Histo File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. PREVIOUS FILE : ** INF(3RMATION RECORDS MNEM CONTENTS DNIT TYPE CATE SIZE CODE CN : ARCO ALASKA I~C. 000 000 01~ WN : 1G-3 000 000 004 065 FN : KIJPARiJK ~)0~ 000 00~ RaNG~ IOE 000 000 004 065 TOWN: I~N riO0 000 00~ SECT: 29 000 00o 004 0~5 COUN: NORTH SLOPE i)t)O 00(~ 012 STAT: ALASKA 000 000 006 065 MNEM CONTENTS UNIT ]'YP~ CATE $]:ZK PRES: DILOOIE 000 (.)00 007 O65 ** R~:CdRD TYPE 047 ** ) ) }~PANY TH = 2302 DATA DEPT 7902 DRHO 0 9 4 DRHO CALl DEPT D~ SP DRHO CALl OEPT SP DRHO CALI SP DRNO CALl D£PT DRHO CALI DEPT DRHO CALl 10 7600 74OO '32 0 ?]00 0 7~00 -99~1 7100 11 74 0000 $~rLb 1,8418 IBM 1.5~45 ILD 1,259~ 65.63: GR 1I~ ,6875' N'PHI 48,4375 RAt 3.964~ 0503 ~,itj~ ,3633 ~-C~L 1:803~0000 FCNL 424'750) 0391 GR 113,6875 RNRA 4.2422 0000 SFLU 1,6025 IB~ 1,5889 ILD 1,6807 9375 G~ ~24,8750 ,,~PHI 44 8730. }'~RAT 3.7754 0313 RHOB 2,3984 NCNB 1853.0000 FCNL 465,2500 3594 f;~ 1~.8750 ~'~RA 3,' 982a 0000 5F l.,~J 2.1094- Ih~ 1,9785 1LD I[. ~,~ 4]75 G~ 396,7500 ~PHI -999,250~] NRAT -999.2500 2500 RHO~ -999.2500 r,~CNI,, -999' 25G~q ffCr~I~ -909.250~', 9687 GR 396,7500 P~RA -999,~500 0000 SFLU 3,2441 I5~ 2,8398 ILO 2.9B05 9375 G~ 108.250(~ ~:oFI -999.250~) ~:RAT -q99,250~ 250(t RH(]B -999 2500 NCNL -999,2500 FC~b -999,2500 3594 G~ 108~2500 R,'~RA -999.250{) ' 999 6406 C 124 8125 -999 2500 - 999 o DEPT DRHO C, AL! DEPT SP DRHO CALI OEPT SP DRHO CALl{ DEPT DRHO C~LI D~P .T' DRHO CAhI 11 64 10 6.~00 25 -999 11 6200 -999 11 °° i1 6000 -20 -999 10 5©(3 0000 929'7 "GR:::..~'RNRA -9 5~0 ,0000 SEL:U 2.35'~0 IL~ 2, 500 .9531 G~ 86~3125i. PHI -999"~945 ,25~0 ~HOB '999.2.5~0 NCNb -999,2500 .2422 (;a 8b,3125 ~RA -q99.2500 OO00 ,SF'L d 1.9932 JLa 2,3~09 453I GR 75,§750 NPHI -999,~500 250o ~qO~' -999,250t> ,~CNL -999i25o0 i797 GR 75,8750 RNRA -999,25OO 0000 SFLU 2.4609 IbM 4219 GR 95,1875 ,~PHI -999,250n 2500 ~Ht]B -999'2500 ~C~L '999,25U9 0078 G~ 95.1975 R,~RA -999,2500 0000 S~'!~ 2.7168 !I,,~ 2.7971 9531 G8 116.2500 t;PMI =999.250a 2500 ~Hit,., -999,250~ ivC~L -q09.~500 ~O06 GR j16,~500 ~RA -999.2500 IbD 2,384~ NRAT -999.2500 FCNL '999.2500 I[,D 2.3633 a~AT -Q99,2500 ILD 2,~512 FCNb -999.2~'o~,, ,. I. LD 2.7Rb2 - '9" 2500 NRAT 9, 9, . FCNL -999.2.5(.;~' OEPT 5800 -999 'T SP CALl 11 :PT DRHO -999 2500 SP -35 ORHO ~999 DEPT 5200 D~O -999 CALl 00o0 2500 9844 g~ OEPT 5100 0000 SFLU SP -31 6563 GN DRHO -999 2500 RHOB CALI 11 4375 G~ DEPT 5000 00()0 SFL~) SP -37,3125 GR ORHO -g99,2500 R~l]i~ C~LI' 11.5391 GR DEPT 4900,0000 SFLL! SP -33.0313 Gu DRHO -999,2500 R~.~[)~ 102. "999~, 1 '02'. 0 o'0 0 i, P )..~ I - 9 9 9.2.5 0 0 N ~,~ A .'r - 9 ',' 2 5 0 (.. 9 O( '25D'0 NCNL:: '999,:2500 FCN5-99 ,25 ) 00'09 ~ f'.'~ R A - ~'99.2500 2.5605 ].LM 2,6504 1LD 2.7] 10~,9375 NPHI 999,~500 NRAT -999,250 2500 [.CNL '-999. 500 -999, N ~06,9375 R~RA -999.2500 2.6055 ILM ~;~867 ILD 2 9bb~ 100,7500 {';PHI -99 500 NRAT -999~250 ~ -999.2500 NCNb -99~,2500 FCNL -999.2500 100.7500 ~,. R A -99 .2500 3.3184 ILM 3.62~1 ILD 3.7!~ 84,1875 NPHI -999,2500 NRAT -999.2500 -999.2500 r, CNI., -999.250'~ FCNI. -999.25~)~ 84,187:5 ~NRA -999,2500 14,7344 IbM 7,4219 ILO u,_12b0 g2.e25a .kP[~ I -999. 250,', .~MAT -999.2 -999,~500 NCNL -999.250o FCi~L -999.2500 .) 0 0 ! t:l !:~ 25 0 0 DRHO 0 1025 2 ' ( , . D E P"r 4203,00()(; SF'L~i~ 3,7500 I.L~) 4 1055 gP -34i34~'~ GR ? ,56~2:5 N~HI .39'892 ~AT ~,517~ 252q r~("i~L ~!28 ()00~ FCh~, 554,5000 D P H 0 0,0 3 3 2 ~ ~'-~ O ~ , .................... DEPT 4000,0000 I~'L,.t 5.2773 IbM 5.b975 ILD 6.1t:le SP -32.4375 Gg 86,8125 kPHI 38,6719 :~RAT DRHO 0,U435 R~O~ 2.~793 I'.~CNL 2156,000n ~CNL CALl 12.7500 GR 86.8125 ~R~ 3.80~6 DEPT 3900 0000 8FLU 5,8789 Ib~ 8,~047 ILO ~,5234 SP -40:7813 DRHO 0,0527 ~HOB 2,2480 ~CNL 2088,0n00 FCNL 514.0000 CALl 11,2~J3 (:JR 7~.1250 ~RA 4.05~6 OEPT .]800,00ti0 S ~,' L !.~ 21 .o250 :I. I., :~ 22.015~ lT.,t) 2,1.82~I SP -69,5625 ~R 82.3438 [:PHI 46.0449 t';R i:.~ 3.8496 DRHO HO 0 2 DEPT DRHO C~LI DRH© CALl DEPT SP DRHO CALI SP CALl DEPT 871 3100.0~00~ oF]bU I0 3984 IL;~ 9,80'~] 0;0322 RHOB 2; I738 }~' C:N L 21~0,0000 10, 55.o938 R'~RA 3 9375 406.3 Gf~ ..... . 3000,0000 SFL!i 13.~531 I[,,~,i ~.4.0~59 47,4375 G~ 40,5313 ~.~PH! 43,4082 0 0]37 ~HO~ ~.0488 LCNL 2162.0o00 10:1797 GR 40.5313 R. NRA 3,7793 2900.0000 SFLU 9.9141 II.,M 1.0,2969 -30,2187 G~ 16.5938 {'~PHI 37.9~95 0,0~64 ~HO~ 2,1445 ~!CNL 2212.0000 10.8750 (;~' 46.5938 ~RA 3.4669 2800,0090 SFL:~ 15.8594 I!,N 10,6~53 -32,093B GR 46,2187 [PHI 43.457u 0.0i61 ~C::z 2.0762 ~,CNL 2124.0nOu 10,6250 GR 46,2187 RNRA 3,~965 2700.0000 SFbu 5.7891 IL~ b.793~ I 1_, D 1 q. 4 u E. 3 i~ R A T ' 63 28 iLD 10,6250 ~.RAT FCNL 638,0000 IL, D { 1.2734 ~,3672 ) ) -17 2031 G~ DRHO 641 33 5000 SFt..,O 1 :! 390h II.,a 2000 0o00 i[,D 2000 a ~:~CN 136: 0000 ~ER DATE : MAXIMU~ LENGTB : I024 FILE TYPE : NEXT FILE NAME EOF ~$*~$~ ** TAPE TRAILER SERVICE NAME :$ERVIC DATE :821101 7 ORIGIN 56564 ~APE ~ANE CONTINUATION # NEXT TAPE NA~S: : COMMENTS :SCHLUMBERG~ ~EI~L SERVICES FIELD TAPE ** REEL TRAILER SERVICE NA~
