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185-006
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2U-03 KUPARUK RIV UNIT 2U-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2U-03 50-029-21269-00-00 185-006-0 W SPT 5643 1850060 1500 2450 2450 2450 2450 330 430 430 440 4YRTST P Austin McLeod 8/7/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2U-03 Inspection Date: Tubing OA Packer Depth 845 1815 1740 1735IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220808193424 BBL Pumped:1.5 BBL Returned:1.5 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:38:19 -08'00' • 0 aJ9 H H O li In p c X a s > 3oo mv @ ° b 0..----. 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Tyler Subject: Recent MIT's performed at KRU Attachments: MIT KRU 1E-08A 08- 7-15.xls; MIT KRU 1Y-10 08-27-15.xls; MIT KRU 2H-04 08-27-15.xls; MITA RU 2U-03 08-27-15.xls; MIT KRU 2W-16 08-27-15.xls Attached are copies of the recent MIT's performed at KRU. 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 WELLS TEAM scale Z,t6 1 • • ,... STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rega alaska.gov AOGCC.Inspectors(c(alaska.00v phoebe.brooks(rDalaska.gov chris.wallaceejalaska.dov ' elt6I N(l5- OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT/PAD: Kuparuk/KRU/2U DATE: 08/27/15 OPERATOR REP: Riley/Beck AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2U-03 " Type Inj. W' TVD 5,643' Tubing '1,100 1,100 1,100 1,100 Interval 4 P.T.D. 1850060 Type test P Test psi '1500 Casing 1,425 2,000 -1,970 1,970 P/F P i Notes: OA 360 360 360 360 Bob Noble waived right to witness 4 year MITIA 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 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MITKRU2U-0308-27-15.xls STATE OF ALASKA AL. A OIL AND GAS CONSERVATION CON. .SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed. Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r474 Re-enter Susp Well r Other: Install tubing Patch I� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development r Exploratory r 185-006 3 Address. 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21269-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 25644 KRU 2U-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6868 feet Plugs(measured) none true vertical 6277 feet Junk(measured) none Effective Depth measured 6718 feet Packer(measured) 6103,6364 true vertical 6151 feet (true vertical) 5643, 5857 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 2971 9.625 3008 3008 PRODUCTION 6763 7 6798 6219 �D �V ED AUG 17 2015 Perforation depth: Measured depth: 6279-6326, 6424-6431,6435-6475 True Vertical Depth: 5787-5826, 5907-5913, 5916-5sE +1NEO JAOGGC Tubing(size,grade,MD,and TVD) 3.5, L-80,6386 MD, 5875 TVD Packers&SSSV(type,MD,and TVD) PACKER-OTIS RRH PACKER @ 6103 MD and 5643 TVD PACKER-OTIS WD PACKER @ 6364 MD and 5857 TVD SSSV-CAMCO TRDP-1A-SSA SAFETY VALVE @ 1807 MD and 1807 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Od-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 AAC 25.070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r�i Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r,► WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt. 315-308 Contact Tyson Wiese (c,263-4250 Email Tyson.M.Wieseconocophillips.com Printed Name T son Wiese Title Sr. Wells Engineer Signature Phone:263-4250 Date $-1,—x,015 L"Tt_ q72/,j RBDMS AUG 1 9 2015 Form 10-404 Revised 5/2015 e 2g, Submit Original Only • a KUP INJ 2U-03 Iv ConocoPhillips 1° Well Attributes Max Angle&MD TD Alaska IncUW Wellbore APIII Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cmocogtilsps ` 500292126900 KUPARUK RIVER UNIT INJ ' 40.35 4600.00 6868.0 ... nu Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 21J-03,8/420151:49:24 PM SSSV:LOCKED OUT Last WO: 40.99 2/19/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,425.0 9/26/2013 Rev Reason:SET NIPPLE REDUCER/PATCH hipshkf 8/4/2015 1111inir easingSUIn s HANGER;32.3 g ■' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(L.Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SURFACE 95/8 8.921 37.0 3,007.9 3,007.7 36.00 J-55 BTC 1 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I..Grade -Tr.Th ead 1 i PRODUCTION 7 6.276 34.8 6,798.0 6,2186 26.00 J-55 C Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 32.3 6,386.0 5,875.4 9.30 L-80 EUEBrd Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;380-115.0 32.3 32.3 0.04 HANGER MCEVOY TUBING HANGER 3.500 1,807.3 1,807.2 1.06 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 2.812 8/30/85) SAFETY VLV;1,807.3 no��i_ 6,091.6 5,633.8 35.67 SBR OTIS SBR 3.000 6,102.7 5,642.9 35.58 PACKER OTIS RRH PACKER 2.970 • 6,250.6 5,763.8 34.73 BLAST RINGS CARBIDE BLAST RINGS(3) 2.992 6,363.0 5,856.4 34.46 LOCATOR OTIS LOCATOR SUB 3.000 4.000 6,363.6 5,856.9 34.46 PACKER OTIS WD PACKER SURFACE;37.03.007.9I 6,367.5 5,860.1 34.46 SBE SEAL BORE EXTENSION 3.000 6,378.5 5,869.2 34.46 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT;6,050.511 6,385.2 5,874.7 34.45 SOS BAKER HYDRAULIC GUN RELEASE,ELMD @ 6381' 3.015 per SWS(PROF 9/12/2006 IIIOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°1 Des Com Run Date ID(in) 560;6,091.6 6,327.0 5,826.7 34 47 PATCH 2.71"x 2.25"HES OWENS X-SPAN PATCH W/30' 8/2/2015 2.250 SPACER PIPE ' 6,385.2 5,874.7 34 45 NIPPLE 2.75"x 1.81"NIPPLE REDUCER 8/2/2015 1.810 REDUCER PACKER;6,102.7 ° Perforations&Slots Shot Dens INJECTION;6,140.1 Top(TVD) Btm(ND) (shotslf lop(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com II 6,279.0 6,326.0 5,787.2 5,825.9 C-4,UNIT B, 3/28/1985 12.0 IPERF 5"Baker TCP 2U-03 INJECTION;6,210.7 6,424.0 6,431.0 5,906.7 5,912.5 A-4,2U-03 3/28/1985 4.0 (PERF 5"Baker TCP 6,435.0 6,475.0 5,915.8 5,948.9 A-3,2U-03 3/28/1985 4.0 IPERF 5"Baker TCP Mandrel Inserts St IPERF;6,279.0-6,326.0-. ati _ on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com �( 6,050.5 5,600.5 MERLA TPDX 1 1/2 GAS LIFT DMY RM 0.000 0.0 6/21/2000 2 6,140.1 5,673.4 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 9/26/2013 I 3 6,210.7 5,731.0'MERLA TPDX 1 1/2 INJ DMY RM 0.000 0.0 4/1/1995 Close ,/ d PATCH;6,327.0 11 7 4 6,343.5 5,840.3 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 4/1/1995 Close INJECTION;6,343.5 1 d Notes:General&Safety End Date Annotation 9/12/2006 NOTE:Leak recorded in'C'Sands @ INJ Mandrel#4&4'Pup above same mandrel LOCATOR;6,363.0 PACKER;6.363.6 Lei 11 M SBE;6.3675 ' . lit 1 NIPPLE;6,378.5 3 F. III J NIPPLE REDUCESOR;Q3B5.S;6.365.22 1 lL ~ IPERF;6,424.0-6 431.0- IPERF;6,435.0-6,475.0-_ PRODUCTION;34.8 6,798.0 2U-03 WELL WORK SUMMARY • DATE SUMMARY 7/4/2015 RAN 2.44" CENT W/ 1.5" SAMPLE BAILER,TAGGED BOTTOM @ 6615' RKB.RAN 2.80" GAUGE RING,S/D @ 6266' SLM.UNABLE TO WORK THRU.RAN 2.64" CENT W/3.5" BLB & 2.35" GAUGE RING.BRUSHED DOWN TO 6378' RKB.RAN 2.80" GAUGE RING,DRIFED DOWN TO D-NIPPLE @ 6278' RKB.SAW NO RESTRICTIONS.RAN 31'X 2.72" PATCH DRIFT,S/D © 5614' SLM.UNABLE TO WORK THRU,PULLING HEAVY OFF BOTTOM, IN PROGRESS. 7/5/2015 RAN LDL BASE LINE © 100 FPM TO 6340' SLM.BRUSHED & FLUSHED FROM 6340' SLM TO SURFACE.RAN 2.74"X 31' PATCH DUMMY TO 6400' SLM,SAW NO RESTRICTIONS.SET 2.75" CA-2 PLUG @ 6378' RKB. 7/6/2015 RAN LDL TO 2.75" CA-2 PLUG @ 6378' RLB.LEAK FOUND IN C SAND STRADDLE @ 6337'.5", IN SAME AREA OF KNOWN LEAK. PULLED PRONG FROM CA-2 PLUG FROM 6378' RKB.ATTEMPTED PULLING PLUG BODY FROM 6378' RKB.RAN 2.5" PUMP BAILER,TAGGED © 6330' SLM.BAILER EMPTY.MADE ANOTHER ATTEMPT PULLING PLUG BODY,S/D @ 6166' SLM.UNABLE TO WORK THRU.RETURN IN AM, IN PROGRESS. 7/7/2015 PULLED 2.75" CA-2 PLUG BODY FROM 6378' RKB.WELL READY FOR PATCH. 8/1/2015 RAN 2.74"X 41' PATCH,S/D @ 6330' SLM.UNABLE TO WORK THRU.RAN 2.64" CENT W/3.5" BLB & 2.30" GAUGE RING. DRIFTED DOWN TO 6360' SM & BRUSHED D-NIPPLE @ 6330' SLM.SET 2.75" NIPPLE REDUCER @ 6330' SLM/6378' RKB.HAD TO WORK THRU SBR,POSSIBILITY PREMATURELY SHEARED.IN PROGRESS. 8/2/2015 SET 2.75"X 1.81" NIPPLE REDUCER @ 6378' RKB.SET HES OWENS X-SPAN PATCH.LOWER MIDDLE ELEMENT @ 6358' RKB & UPPER MIDDLE ELEMENT @ 6328' RKB.IN PROGRESS. 8/3/2015 SET 1.81" CA-2 PLUG IN NIPPLE REDUCER @ 6378' RKB. LRS PERFORMED MIT-T TO 3000 PSI,PASSED.PULLED 1.81" CA-2 FROM 6378' RKB.JOB COMPLETE. OF Te „-v., /jy�, �� s THE STATE Alaska Oil and Gas � 1, ofA As KA Conservation Commission ;i ist} ,---,1=_2-..-4--f,--7333 West Seventh Avenue \Tti' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279.1433 O' ALASACP' Fax 907 276 7542 www.aogcc alaska.gov Tyson Wiese Sr. Wells Engineer SCANNED .;UN 0 12d1� O� ConocoPhillips Alaska, Inc. g _D P.O. Box 100360 v Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2U-03 Sundry Number: 315-308 Dear Mr. Wiese: Enclosed is the approved application for 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, Cathy P oerster —�/�.. Chair DATED this 2- day of May, 2015 Encl. 1 STATE OF ALASKA ' A. A ,KA OIL AND GAS CONSERVATION COM. .TION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r�./ '•' rV Atter Casing r Change Approved Program r Rug for Redrill r FFrforate New Pool r Repair Well Re-enter Susp Well r Other: Install tubing Patch 57, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 185-006 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-029-21269-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r No r KRU 2U-03- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25644' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured). 6868 - 6277 ' 6718' 6151' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 2971 9.625 3008' 3008' RECEIVED PRODUCTION 6763 7 6798' 6219' MAY 202015 (YrS s/z?l is AOGCC Perforation Depth MD(ft): I Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft): 6279-6326,6424-6431,6435-6475 5787-5826,5907-5913,5916-5949 3.5 L-80 6386 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-OTIS RRH PACKER MD=6103 TVD=5643 • PACKER-OTIS WD PACKER MD=6364 TVD=5857• SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE MD=1807 TVD=1807 ' 12.Attachments Description Summary of Proposal p- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r Development r Service• r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/2/2015 OIL r WINJ r . WDSPL r Suspended r 16.Verbal Approval. Date: GAS r WAG r GSTOR r SPLUG r Commission Representative. GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 Email: Tyson M Wiesee.conocophillips.com Printed Name Tyson Wiese Title: Sr. Wells Engineer Signature Phone:263-4250 Date 5 "IR-1-°15 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -S t S-2 7 C) Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No V Subsequent Form Required. (O —,q O APPROVED BY Approved by' )7 :4(------1--b&—' COMMISSIONER THE COMMISSION Date:SZ/-7 1�� Approved appllG I catlo I V li for 12 it1 n i pr the date of approval. submit Form and Form 10-403 Revised 5/2015 p R I 7 I/ Attachments in Du licate vrz 5/2///5-- i* "72. ,,s RBDMS\ MAY 2 8 2 15 KUP INJ 2U-03 C011000PI1IIIipS Well Attributes Max Angle&MD TD Wellbore APIIUWI Field Name Wellbore Status ncl MD ftKB Act BtmftKB Alaska.Inc. --`,...E-,4;,,,,- C) (ftKB) 1 1 ,aa c(4,,,lur," 500292126900 KUPARUK RIVER UNIT INJ 40.35 4,600.00 6,868.0 - Comment R2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2U-03,927/20133'.20:00 PM SSSV:LOCKED OUT Last WO: 40.99 2/19/1985 Vedwal schemata(actual) Annotation Depth(ORB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,425.0 9/26/2013 Rev Reason:TAG,GLV C/O hipshkf 9/27/2013 HANGER 32.3 'Casing`Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 37.0 3,007.9 3,007.7 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)... WtlLen(I...Grade Top Thread PRODUCTION 7 6276 34.8 6,798.0 6,218.6 26.00 J-55 BTC Tubing Strings W1 mu em Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 312 2.992 323 6,386.0 5,875.4 930 L-80 EUE8rd Completion Details Nominal ID -- Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 323 32.3 0.04 HANGER MCEVOY TUBING HANGER 3.500 CONDUCTOR;38.0-115.0 "A.n 1,807.3 1,8072 1.06 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 2.812 8/30/85) SAFETY VLV;1,807.3 6,091.6 5,633.8 35.67 SBR OTIS SBR 3.000 r'..,, 6,102.7 5,642.9 35.58 PACKER OTIS RRH PACKER 2.970 6,250.6 5,763.8 34.73 BLAST RINGS CARBIDE BLAST RINGS(3) 2.992 6,363.0 5,856.4 34.46 LOCATOR OTIS LOCATOR SUB 3.000 6,363.6 5,856.9 34.46 PACKER OTIS WD PACKER 4.000 6,367.5 5,860.1 34.46 SBE SEAL BORE EXTENSION 3.000 SURFACE.37.0-3,007.9• • 6,378.5 5,8692 34.46 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,3852 5,874.7 34.45 SOS BAKER HYDRAULIC GUN RELEASE,ELMD @ 6381' 3.015 GAS LIFT;6,050.5 per SWS(PROF 9/12/2006 Perforations&Slots Shot Dens Top(ND) Btm(ND) Ishots# IC Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SBR;6.091.6 6,279.0 6,326.0 5,787.2 5,825.9 C-4,UNIT B, 3/28/1985 120 IPERF 5"Baker TCP �J 2U-03 6,424.0 6,431.0 5,906.7 5,912.5 A-4,2U-03 3/28/1985 4.0 IPERF '5"Baker TCP PACKER,6.102.7IM 6,435.0 6,475.0 5,915.8 5,948.9 A-3,2U-03 3/28/1985 4.0 IPERF 5"Baker TCP Mandrel Details Set INJECTION;6,1401111 a nC Top(TVD) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 6,050.5 5,600.5 MERLA TPDX 1 1/2 GAS LIFT DMY RM 0.000 0.0 6/21/2000 INJECTION;6.210.7if 2 6,140.1 5,673.4 MERLA TPDX 11/2'INJ DMY RM 0.000 0.0 9/26/2013 3 6,210.7 5,731.0 MERLA TPDX 1 V2 INJ DMY RM 0.000 0.0 4/1/1995 C 0 s _ e d IPERF;6,279.0.6526.0 = 4 6,343.5 5,840.3 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 4/1/1995 C I 'y o r s e IId INJECTION;6.343.5 Notes:General&Safety End Date Annotation 9/12/2006 NOTE:Leak recorded in'C'Sands©INJ Mandrel#4&4'Pup above same mandrel LOCATOR;6,363.0 at '(�J^y Al. '11 111�aa ///��JJJ PACKER;6,363.6 'cike\ \* '1444 over I-er)1 ^A k lki w - . 1"`rrr111 1rA` /�v T�1 V`�1 over V� '...77711�I\` ,M„Y`u'1/\ SBE;6.367.51 I (1)3 546 - 6,33'i . I NIPPLE:6,3785 I SOS;6,385.2 g i. IPERF;6,424.0-6,431.0IPERF;6,435.0-6,475.0 PRODUCTION;348-6,798.0 2U-03 Tubing Patch Installation Permit to Drill #: 185-006 5/19/2015 2U-03 was drilled on February 19th 1985, and completed as an A and C sand producer, with 3.5" L-80 tubing. On November 16th 1985, the well was converted to an A-sand water injector. The objective of this patch procedure is to install a patch across the known leaking IM (6,343' KB), the known leaking 4' pup joint (6,339' KB), and other potential C-sand selective leaks that may be found during the leak detect log. The estimated NOB associated with a successful patch job is 50 BOPD, by providing better support to the offset A sand producers. Procedure: Digital Slickline: (Leak Detect Log, Patch C-sand Leaks) 1. RIH and drift the tubing to 2.75" D-nipple @ 6,379' KB with a 2.78" GR. 2. RIH and obtain an accurate fill tag depth, to ensure the A-sand perfs are clear. 3. Dummy drift patch assemblies to approx. 6,370' KB, below planned set depths. 4. Set lock/plug in 2.75" Tubing Tail D-nipple @ 6,379' KB. 5. Perform Leak Detect Log across the C-sand selective to confirm leak locations. 6. Pull lock/plug from 2.75" nipple. Set pre-patch 2.75" x 1.81" nipple reducer if permanent patch systems will be utilized. 7. RIH with either a permanent or retrievable patch (whichever was able to drift freely). Log into position and set the patch across the leaking injection mandrel and 4' pup joint. 8. If additional C-sand leaks were found, install patch over those leaks as well. 9. RIH and set plug in nipple reducer (or test tool in patch assembly). 10. MIT-T to 2,500 psi. Record 15 min, 30 min T/I/O pressures. 11. Pull plug (or test tool). Turn well over to Operations. RDMO. Ima~roject Well History File CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier ~~Tw~iSided Organizing (done) RESCAN rn Color items: Grayscale items: Poor Quality Originals: Other: NOTES: BY: DIGITAL DATA [] Diskettes, No. Other, No/Type BEVERLY BREN ~SHERYL MARIA LOWELI. OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] : Logs of various kinds [] Other Project Proofing BY: ~ BREN VINCENT SHERYL MARIA LOWELl. - Scanning Preparation ,.~ x 30 = ' BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Production Scanning ""--o[age 1 PAGE COUNT FROM SCANNED FILE: y(..,~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ,V'~YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND' YES NO (S~N~ ~ C~E~ AT THIS ~ UN~ SPEC~ A~ENTDN IS REQUIRED ON ~ ~DNDUAL PAGE BAS~ III IIIllllllll II III RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3 NOTScan ned .wpd • • YI LPOTE SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tyson Wiese Wells Engineer o ConocoPhillips Alaska, Inc. 5, P.O. Box 100360 !_ . Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2U -03 Sundry Number: 312 -136 , Dear Mr. Wiese: i �;�� Q pv z . t _ Enclosed is the approved Application for 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy . Foerster Chair DATED this /(1_ day of April, 2012. Encl. • STATE OF ALASKA U T ! / i 61 / A OIL AND GAS CONSERVATION COMM•N Z APP FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool f Repair well r Change Approved R r Suspend f"' Rug Perforations r Perforate r Rill Tubing r Time Extension (- Operational Shutdown f Re -enter Susp. Well r Stimulate r Alter casing r Other:Install Tubing Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185 -006. 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21269 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 2U -03 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25644 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6868 • 6277 • 6718' 6151' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' &, „ .... ° . � SURFACE 2971 9.625 3008' 3008' tt �� PRODUCTION 6763 7 6798' 6219' a OR Q ®�/ ', 4f ` 1� X0, 4 A O h #; r Pr ca, + �- Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing M 6279'- 6326', 6424'- 6431', 6435' -6475' 5787'- 5826', 5907'- 5913', 5916' -5949' 3.5 L -80 6385 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - OTIS RRH PACKER MD= 6103 TVD= 5643 PACKER - OTIS WD PACKER MD= 6364 TVD= 5857 SSSV - CAMCO TRDP -1A -SSA SSSV MD =1807 TVD =1807 12. Attachments: Description Summary of Proposal p' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch j Exploratory r Development Service Jr ` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/15/20212 Oil r Gas r WDSPL r Suspended E 16. Verbal Approval: Date: WINJ 1✓ • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese © 263 -4250 Printed Name on Wiese Title: Wells Engineer Signature i c Phone: 263 -4250 Date by- Dy- Ul Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 IA , I /.-. Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /6 _ Liel G (5 . L1 J / {ten/ APPROVED BY � r /.�_ Approved by: ,11��..//ll�,�,(( / COMMISSIONER THE COMMISSION Date: 4 1- "- / �/•SiZ � / \ Form 10 -40 .1:', �,',• § 111012 4Q R I G I N A L Submit in Du icat r ,, , , 4. • 2U -03 Tubing Patch Installation Permit to Drill #: 185 -006 2U -03 was drilled on February 19 1985, and completed as a C and A sand producer, with 3.5" L -80 tubing. On November 16 1985, the well was converted to an A -sand water injector. The objective of this patch procedure is to install a patch across the leaking IM (6,343' KB) and the leaking 4' pup joint (6,339' KB). The estimated NOB associated with a successful patch job is 50 BOPD, by providing better support to the offset A sand producers. Procedure: Coil Tubing: 1. Perform a FCO to remove fill from across the A3 Sand Perfs. Slickline: 1. RIH and tag fill to ensure the A3 Perfs are clear. 2. Drift dummy patch assembly to 6,370' KB, just below planned setting depth. 3. Brush and Flush from 6,320' — 6,370' KB, to ensure packer set depths are clean. E -line: (Install lower tubing patch packer) 1. RIH with a 2.74" OD Patch Packer. Log into position and set the packer mid - element at 6,358' KB, 5ft below the bottom of the leaking mandrel. Utilize original tubing details, as well as updated caliper log data for depth correlation. Slickline / Little Red: (Install upper patch assembly) 1. RIH with upper patch assembly (snap latch, spacer pipe, upper packer) and latch into lower packer @ approx. 6,356' KB. 2. Set the upper packer mid - element @ 6,334' KB, 5ft above the leaking pup joint. 3. Pump 55 bbls of Diesel down tubing (fluid pack tubing to upper packer) 4. RIH and set test tool in upper packer @ approx. 6,332' KB. 5. MIT -T to 2,500 psi. Record initial, 15 min, 30 min TIO pressures. 6. Pull ER test tool and turn well over to operations. RDMO # KUP • 2U -03 C011000Pi11iiipS A Well Attributes Max Angle & MD TD • • ,a. Wellbore API /UWI Field Name Well Status Intl (°) MO (ftKB) Act Btm (ftKB) Ahaska`Irtc, 3 500292126900 KUPARUK RIVER UNIT INJ 40.35 4,600.00 6,868.0 ""' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO. 40.99 2/19/1985 Well Confa::- 2U .03, /12/201'. 5chemalic 10-Actual 1 9 57 03 AM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,438.0 9/16/2010 Rev Reason: GLV C/O ninam 10/12/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thrd HANGER, 32 CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,007.9 3,007.8 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 34.8 6,798.0 6,218.6 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd t TUBING 31/2 2.992 32.3 6,386.0 5,875.4 9.30 L -80 EUE8RDIPC Completion Details --- Top Depth Ell (ND) Top Inc! Noml... T op (ftKB) (ftKB) (°) Item Description Comment ID (in) 32.3 32.3 0.13 HANGER MCEVOY TUBING HANGER 1500 CONDU38 - 1,807.3 1,8072 0.91 SAFETY VLV CAMCO TRDP -1ASSA SAFETY VALVE (LOCKED OUT 8/30/85) 2.812 115 6,091.6 5,633.9 35.65 SBR OTIS SBR 3.000 SAFETY VLV, ? .e=as I 6,102.7 5,642.9 35.58 PACKER OTIS RRH PACKER 2.970 1,807 6250.6 5,763.7 34.49 BLAST RINGS CARBIDE BLAST RINGS 2.992 6,363.0 5,856.4 34.46 LOCATOR OTIS LOCATOR SUB 3.000 6,363.6 5,856.9 34.46 PACKER OTIS WD PACKER 4.000 6,367.5 5,860.1 34.46 SBE SEAL BORE EXTENSION 3.000 6,378.5 5,869.2 34.46 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE, 6,385.2 5,874.7 34.45 SOS BAKER HYDRAULIC GUN RELEASE, ELMD @ 6381' per SWS (PROF 3.015 37 - 3,008 9/12/2006 GAS LIFT. Perforations & Slots 6,051 Shot H Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB (ftKB) (ftKB) Zone Date ( Type Comment 6,279 6,326 5,787.2 5,825.9 C-4, UNIT B, 3/28/1985 12.0 IPERF 5" Baker TCP 2U -03 SBR, 6,092 6,424 6,431 5,907.0 5,912.7 A-4, 2)1 -03 3/28/1985 4.0 IPERF 5" Baker TCP 6,435 6,475 5,916.0 5,948.9 A -3, 2U -03 3/28/1985 4.0 IPERF 5" Baker TCP Notes: General & Safety PACKER. 6,103 End Date Annotation 9/12/2006 NOTE Leak recorded in 'C' Sands @ INJ Mandrel 84 & 4' Pup above same mandrel r INJECTION, - r 6,140 INJECTION, 6,211 IPERF, �' ({ _AI 6,279-6.326 !PERE, Y/'v - INJECTION, k. 6,343 TF LOCATOR, � - � 6,363 PACKER, 6,364 SBE, 6.367 it NIPPLE, 6,378 I. . 1111 1 SOS, 6,385 ,Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run IPERF, - ® Stn Top (ftKB) (ftKB) ('1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 6,050.5 5,600.6 35.91 MERLA TPDX 1 1/2 GAS LIFT DMY RM 0.000 0.0 6/21/2000 6,4246,431 -- 2 6,140.1 5,673.4 35.35 MERLA TPDX 1 1/2 INJ HFCV RM 0.000 0.0 8/10/2009 3 6,210.7 5,730.9 34.51 MERLA TPDX 1 1/2 INJ DMY RM 0.000 0.0 4/1/1995 Closed IPERF. 6 II .435 4 6,343.5 5,840.3 34.47 MERLA TPDX 1 12 INJ DMY RM 0.000 0.0 4/1/1995 Closed PRODUCTION, 35-6,798 Ns • TD,6,868 Page 1 of 3 • Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139 @conocophillips.com] Sent: Thursday, January 27, 2011 9:09 AM , s -( 0 G To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); Colombie, Jody J (DOA); NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt; Bradley, Stephen D Subject: FW: RE: Request for Approval Attachments: Kuparuk Gas Injector Flow back Volumes.xls Tom, Attached you will find the Kuparuk Gas Injector Flowback information per your request. v Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist C 67 (19 ConocoPhillips Alaska, Inc. ' M EP I 1 Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: NSK -69 This email may contain confidential information. If you receive this e-mail in error notify the sender and delete this email immediately. From: Maunder, Thomas E (DOA) fmailto :tom.maunder(a>alaska.gov] Sent: Tuesday, January 25, 2011 9:09 AM To: NSK Prod Engr & Optimization Supv Subject: RE: Request for Approval Gary/Denise, Following up on my brief conversation with Gary the other day, could one of you provide some information with regard to the flowback of these WAG injectors while TAPS was unavailable. Please copy everyoned as before with your response. Thanks in advance, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody 3 (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. 1/27/2011 • Page 2 of 3 • Tom Maunder, PE AOGCC X From: NSK Prod Engr & Optimization Supv jmailto :n2046 ©conocophillips.comJ Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 I1 From: Maunder, Thomas E (DOA) [mailtoaom_ maunder ©alaska.goy Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv jmailto :n2046@conocophil_ips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D 1/27/2011 • • Page 3 of 3 Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ' lowback Adjacent Estimated Prod ias Injector PTD# SI Producer PTD# (Mscfd) 'X ?P-420 201 -182 2P -422A 202 -067 4,500 a1P -447 203 -154 2P -448A 202 -005 2,000 aU -03 1: -006 2U -02 185 -005 3,500 - 5 S -09 4,1 202 -205 3S -08C 207 -163 7,500 3S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/27/2011 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Roby, David S (DOA) Sent: Monday, January 10, 2011 5:21 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: Request for Approval All, Seems like a reasonable plan to me. There shouldn't be any impacts to ultimate recovery as the volumes of gas that would be removed from these injectors should be negligible in the grand scheme of things, assuming the proration does not go on indefinitely. On a side note. Should we require, or at least strongly encourage, all operators to develop contingency plans pre-approve that we can rove to handle situations like this in the future so that they and us don't have to pp jump through a bunch of hoops to try to get something approved in a very short period of time? Dave Roby (907)793 -1232 From: Maunder, Thomas E (DOA) StANNED JAN 1 8 2 O 1 - nt: Monday, January 10, 2011 4:38 PM • NSK Prod Engr & Optimization Supv Cc: •- rster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject. • E: Request for Approval Gary, I acknowledge your - quest. Do you have any best estimate of when this could be needed? Will there be any modi ..tion of the pilot settings on the "new producers "? Sundries will not be neces .ry. Having to ability to test is appropriate for allocation purposes. I have copied this to my colle. •ues so they may make necessary assessments. I do not have the authority for thi . pproval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n •46 @conocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Eng • NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if -eded to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so • •uld help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is sti -volving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for fl. •ack to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the len. • of the 1/11/2011 • Page 1 of 3 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval 1/11/2011 • Page 2 of 3 Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ' lowback Adjacent Estimated Prod ias Injector PTD# SI Producer PTD# (Mscfd) .;P-420 201 -182 2P -422A 202 -067 4,500 ) P -447 203 -154 2P -448A 202 -005 2,000 �U -03 185 -006 2U -02 185 -005 3,500 31S -09 202 -205 3S -08C 207 -163 7,500 31S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/11/2011 MEMORANDUM To: Jim Regg p P.I. Supervisor ^~'~ ~(2.~~,~, FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2U-03 KUPARUK RIV UNIT 2U-03 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~j~',= Comm Well Name: KUPARUK RIV UNIT 2U-03 Insp Num: mitCS100823053232 Rel Insp Num: API Well Number: 50-029-21269-00-00 Permit Number: 185-006-0 Inspector Name: Chuck Scheve Inspection Date: 8/22/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 0 Wel U2 3 ' Type Inj. N ~ TVD 5643 IA 640 1950 ' 19]0 1910 " P.T.D lssoo6o ~ TypeTest ; SPT Test psi tsoo - pA z6o zao z8o zso Interval aYRTST p~F, P . Tubing 147s 1475 475 1476 Notes: pre-test pressures were observed for 30+ minutes and found stable. ;;~ ' ~ ~ '.. ~-, 1 t'' f 1 ~a'!. . ~, Wednesday, August 25, 2010 Page 1 of 1 • L J ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~ March 5, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~~~~ MAF ~ `l,Cl~ Dear Mr. Maunder: .;~,. ~~`w:a, . ~:. /~~(~ 18 ~_ ~~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23rd , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ ~~~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'S" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21 " 1 /24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2!22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 2U-03 PTD 185-006 • Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophi-lips.com] Sent: Wednesday, February 04, 2009 5:57 AM ~~ ~ ~~~~~v~ To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 2U-03 PTD 185-006 Attachments: 2U-03 90 day TIO.jpg ~ Jim, Enclosed is a follow up 90 day TIO plot of 2U-03 operating pressures and temps. Page 1 of 1 The wells OA is fluid packed from recent MITOA work. We perform surface casing integrity tests on all of the wells before we add the corrosion inhibitor to the conductor by surface casing void. 2U-03 was fluid packed during a passing MITOA performed on 12/22/08. The IA passed a MITIA on 1/10/09 and was fluid packed at that time. There is currently a small amount of gas :/ added to maintain a pressure differential from the OA and tubing. Both annuli are very sensitive to small changes in the temperature of the injectant. With time the operators will bleed and charge the annular spaces with gas. This process burps fluid out of the annulus and will slowly build a gas cap that will act as an expansion chamber and dampen the pressure changes associated with varying temperature changes of the injectant. We feel that the well does not have annular communication issues. ~ Let me know if you have any questions. Perry Klein ~. '~ lj~i~+' r--~ ~ k s qtr.""; ~.u~~: Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Voice Pager 659-7000 x937 «2U-03 90 day TIO.jpg» 2/6/2009 KRU 2U-03 PTD 185-006 2/4/2009 TT(~ Pre~SUreS • i~t4.!'e- • Regg, James B (DOA) ~ ~ From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Friday, January 16, 2009 10:26 AM ~~( To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Wetl Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: Emailing: 2U-03 90 day TIO.jpg Attachments: 2U-03 TIO.jpg 2U-03 TIO.jpg (455 KB) Jim, In response to your query regarding 2U-03 (PTD 185-006) we had DHD bled the IA and OA on January 9t . The inner casing packoff seal on the OA required re energizing at that time and is now on a preventative maintenance re energizing cycle. The OA pressure data between Jan 2nd and January 7th is suspect as we were under a technical phase 2 weather operation. Since the bleeds, both the IA and OA have stabilized to follow the temperature trend and have been monitored daily personally by myself, the DSO, and DHD. As a follow up to your question below "How do lower temps create a higher pressure in a closed annulus space (fixed volume)?". The IA volume is slightly smaller when a well is on gas injection (vs. water injection) due to the "balloon" affect caused from the 1600 psi increase in tubing pressure. Both the IA and the OA are completely fluid packed from recent diagnostic MIT's and as you can see from the attac ed TIO plot the IA and OA pressure trends are tracking the wellhead temperature. The IA is maintaining an 1800 psi differential and the OA is maintaining a 1400 bsi differential, neither of which could be maintained if communication were evident. If communication does become evident we will notify the Commission as per AIO 2B rule 7. In the mean time, removing some of stabilize ~t a mt we can schedule an "aggressive" bleed on the IA with the intent of the fluid and creating a gas cap after which the IA pressure should ch 7 ower pressure. We will send a follow up TIO trend to the Commission after the proposed bleed and a -1 week stabilization period. Please let me know if the plan is not acceptable or if you would like more information regarding this well. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 -----Original Message----- From: Regg, James B (DOA) [mailto:jim.regg@alaska.govJ Sent: Tuesday, December 30, 2008 8:29 AM To: NSK Well Integrity Proj Subject: RE: Emailing: 2U-03 90 day TIO.jpg Perry - 1 Regarding pressure increase the IA and OA, has there bee~ny attempt to confirm that these are not sustained pressures from communication? We are well aware of CPAI's operating guidelines and pressure allowances for injectors - we have also had numerous discussions without any real resolution centered on the discrepancy between CPAI's policy that has pre-established pressure allowances for injectors and the injection orders that do not make such allowance. In this particular case, as with many of CPAI's WAG injectors, the pressure limit set by CPAI "operating guideline" (e.g., 3000psi for IA) results in less restrictive operation than the sustained casing pressure rule (CO 494; producers only) which at least requires notification when you exceed 2000psi. As CPAI has heard us remark before, we believe CPAI operating guideline is inconsistent with AOGCC requirements for injectors. If pressure is thermal as suggested below, why not bleed the IA and OA pressures to say 1000psi/500psi and monitor; if truly thermal, the pressures should remain at/near the post bleed pressure. And, if the annuli exhibit significant re-pressurization (with stable temps), then I think it would be hard to make the case these pressures are only due to thermal effects. The temps do not support KRU 2U-03 annuli pressures being thermal - the temps are significantly lower with lean gas injection (60 deg F) than with the water injection (135 deg F). How do lower temps create a higher pressure in a closed annulus space (fixed volume)? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message----- From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Monday, December 29, 2008 3:15 PM To: Regg, James B (DOA) Subject: Emailing: 2U-03 90 day TIO.jpg «2U-03 90 day TIO.jpg » Jim, The IA pressure is stable at 2500 psi. Our well operating guidelines permit an IA do not exceed of 3000 psi when in gas service. The IA has thermal led up significantly since being WAGd to gas as is typical. Let me know if you have any questions. Perry 2 KRU_2U-03 PTD 185-006 1 / 16/2009 TIO Pressures iwpe~.k„~ KRU 2U-03 PTD 185-006 12/29/2008 Te,~~n- Fuel gas from lean gas injector . Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Thursday, January 01, 2009 5:11 PM ~~ ~ (~~ J To: Regg, James B (DOA) ~ ~'I Subject: RE: Fuel gas from lean gas injector Jim, • Page 1 Alyeska begin to move crude temporarily and we were bringing wells online yesterday. Today we have reversed direction and begin to freeze protecting and shut wells in. We have not had to use 2U-03 as a fuel gas source at this point in time. If the prorations deepen and the flow back plan is initiated we will notify and follow the plan as outlined below. Thanks for your help. ,.., ,~- ., ~~~,i ~ ~~~~ Perry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, December 29, 2008 4:41 PM To: NSK Well Integrity Proj Cc: DOA AOGCC Prudhoe Bay Subject: RE: Fuel gas from lean gas injector We concur with your request to back flow the lean gas injector 2U-03 to provide a tempo y fuel gas source during the ongoing Slope-wide production cut proration as described below. Approval is limited KRU 2U-03. As explained, CPAI will install temporary_har_dlne from 2U-03 to an adjacent producer {accesses the production flowline to CPF-2) rather than attempt to reverse the flow in the injection ~ e. Production will be measured, at the test separator for accounting d reporting purposes. CPAI engineers indicate there would be no impact to_the servoir because of the temporary backflow. The Commission also concurs with plans to temp ar's{y defeat the_safety valve system LPS on KRU 2U-03 conditioned on their being 24-hour surveillance by a qualified erator during the back flow. I appreciate your timely response to questions and need for clarity in your request. Please provide uerbal .notice. for the backflow commencement and the swap back to injection. Also provide a 1.0-404. to cover the temporary status change of the well. Please call if you have ~ questions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 1 /2!2009 12/30/08 G" -_~.- ~_ ~~o I ~°r, `„~, ~~~i~~~~~~i~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 2U-03 12080460 INJECTION PROFILE 'C ~ 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE - 12/07/08 1 1 1C-11 12114998 PRODUCTION PROFILE a 12/14/08 1 1 i D-07 12114999 USIT a 12/15/08 1 1 1 B-09 12115001 INJECTION PROFILE ~ L ~ 12/18/08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP 12/19/08 1 1 iC-18 12100472 .- INJECTION PROFILE 12/21/08 1 1 1 E-21 12115005 p INJECTION PROFILE 12/22/08 1 1 2C-02 12100475 INJECTION PROFILE 3 12/24/08 1 1 I t ~~~ Log Description N0.5024 Company: Alaska`Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD C~ • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Fuel gas from lean gas injector Regg, James B (DOA) - _ ._ From: Regg, James B (DOA) ~ ~~ ~7~~I'ZQ;v~2 Sent: Monday, December 29, 2008 4:41 PM '~ "911 To: NSK Well Integrity Proj Cc: DOA AOGCC Prudhoe Bay Subject: RE: Fuel gas from lean gas injector j J \~ Page 1 of 2 We concur with your request to back flow the lean gas injector 2U-03 to provide a temporary fuel gas source during the ongoing Slope-wide production cut proration as described below. Approval is limited to KRU 2U-03. As explained, CPAI will install te__mporary_har_dline from 2U-03 to an adjacent SI producer (accesses the production flowline to CPF-2} rather than attempt to reverse the flow in the injection line. Production will be rn..e....a..s.ured at the test separator for accounting and reporting purposes. CPAI engineers indicate there would be no impact to_the reservoir because of the temporary backflow. The Commission also concurs with plans to temporarily defeat the safety valve system LP$ on KRU 2U-03 conditioned on their being 24-hour surveillance by a qualified operator during the back flow. I appreciate your timely response to my questions and need for clarity in your request. Please provide verbal notice for the backflow commencement and for the swap back to injection. Also provide a 10-404 to cover the temporary status change of the well. Please call if you have any questions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 t~t~.~~ ~i~~ . ~~- 2C~~ From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Monday, December 29, 2008 2:54 PM To: Regg, ]ames B (DOA) Subject: Fuel gas from lean gas injector Jim, We are working through a proration. The Valdez terminal storage is at high levels and I believe inclement weather is hampering off loading of product. CPF2 has been asked to make large production cuts. Operations would like permission to back flow 2U-03 gas injector PTD # 185-006 as a fuel gas source for the facility. The back flow would be temporary, not to exceed the proration. Normal injection would resume as soon as the Valdez weather improves and Alyeska Pipeline lifts the proration and fuel gas can be harvested from the producers that are brought on line. Please advise if our proposal is acceptable. 12/30/2008 Fuel gas from lean gas injector • • Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, fnc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Page 2 of 2 12/30/2008 2U-03 PTD # 185-006 potential fuel gas source Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, December 29, 2008 3:55 PM To: Regg, James B (DOA) ~~ (Z,~7a ~Zw° Subject: 2U-03 PTD # 185-006 potential fuel gas source Jim, Page 1 of 1 In answer to you two questions regarding the proposal to back flow 2U-03 lean gas injector as a fuel gas source. The surface safety valve pilot system will be disabled and the well will have 24 hr man watch by a qualified operator. The CPF2 production engineer does not predict any reservoir damage from back flowing the well. Please let me know if our proposal is acceptable and/or if you have any questions. Thanks Perry 12/29/2008 09/15/06 Sc~.~e.... RECEIVED NO. 3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SEp·1 5 2006 ~Oif & Gas Cons. Commission Anchorage -~'--\" C t: P "'\ ~:~ '..f""h....·' '\') .... ~~r'Á.~,~.~~....."'j '. ,- :)'\01 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UI~ I~~-td.o Field: Kuparuk Well Job# Log Description Color CD Date BL 2A-18 11213804 LDL 09/09/06 1 1 A-20 11213802 PROD PROFILE WIDEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1 L-28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1 L-1 0 1142164 INJECTION PROFILE 09/09/06 1 1 J-1 02 11421625 US IT 09/11/06 1 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 SBHP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3O02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1F-01 ~ ~.~, Ic~ SILICON ACTIVATION LOG-RST 10101103 t 2U-03 ~=~--~::~! . STATIC SURVEY 10102103 1 2U-09 I~'~,~ STATIC SURVEY 10102103 1 2V-04 !33-)~--'2_ STATIC SURVEY 10/02/03 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 10/21/03 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Commissioner THRU: Jim Regg ¢/.~.~ P.I. Supervisor FROM' Jeff Jones Petroleum Inspector SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 2U Pad 2U-03, 2U-04, 2U-05, 2U-16 KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. 1850060 Type testI P Test psiI 1500 Casing 1350 2400 2360 2350 P/F Notes: Test fluid 2 BBLS diesel vw,I P.T.D. 1850070 Type testI P Test psiI 1500 Casing 1150 2450 2390 2360 P/F Notes: Test fluid 2 BBLS diesel P.T.D. 1850180 Type testI P Test psi 1500 Casing 1550 3200 3050 3025 P/F P Notes: Test fluid 4.3 BBLS diesel P.T.D.I 1842490I I IType testI P Test psi 1500 Casing 675 3500 2000 1150 P/F _F OA 600 1860 1800 1100 Notes: Test fluid 3.1 BBLS diesel. 3 casing hanger Iockdown leaks at packing glands were repaired. 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) May 14, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPAI) water injection wells 2U-03, 2U-04, 2U-06 and 2U- 16 to witness 4 year MIT's. Jared Break was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with wells 2U-03, 2U-04, 2U-05 passing their MIT's. When the inner annulus of well 2U-16 was pressured up the outer annulus pressure also rose, exhibiting IA/OA communication and this well failed the MIT. It appears that well 2U-16 wellhead pack-oft'is leaking. CPAI Problem Well Supervisor MJ Loveland indicated diagnostics and repair of this item would begin within 24 hours. Four well house inspections were also conducted with three exceptions noted. Three casing lockdown screws were leaking at the packing glands on well 2U-16 and were immediately tightened, stopping the leaks. Summary: I witnessed successful MIT's on CPAI's water injection wells 2U-03, 2U-04, and 2U-05 and a failed MIT on well 2U- 16 in the Kupamk River Field. Four well house inspections conducted, three exception noted. M.I.T.'s performed: 4 Number of Failures: 1_ Attachments: wellbore schematics (4) Total Time during tests: 3 hrs CC: MIT report form 2003-0514_M IT_KRU_2U- 16_jj.xls 5/19/2003 ARCO Alaska, Inc. ~ Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 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- Well Action Date Performed on the 1 L- 1 Conve 1 L- 7 Conve 1Q-2 Conve 1 Q- 7 Conve 1 Q- 11 Conve 1 Q- 13 Conve 2B-5 Conve 2B-9 Conve 2C-1 Conve 2C-3 Conve 2C-6 Conve 2C-8 Conve 2D-2 Conve 2D-7 Conve 2D- 11 Conve 2D- 1 4 Conve 2 F- 1 Conve 2 F- 2 - Conve 2 F- 1 3 Conve 2 F- 1 4 Conve 2G-3 Conve 2G-3 Conve 2G-5 Conve 2G-7 Conve 2G- 1 0 Conve 2.G- 1 2 Conve 2G- 1 6 Conve 2U-3 Conve 2U-4 Conve 2U-7 Conve 2U- 1 6 Conve 2W-2 Conve 2W-4 Conve rs on rs on rs on rs on · rs on rs on · rs on · rs on · rs on · rs on rs on · rs on rs on rs on · rs on rs on · rs on · rs on · rs on · rs on rs on rs on rs on · rs on rs on rs on rs on rs on · rs on rs on · rs on rs on rs on 11118185 11/18/85 11/17/85 11/17/85 11117185 11117185 11/23/85 11/23/85 11119185 11/19/85 11/19/85 11/19/85 11/20/85 11/20/85 11/20/85 11120185 11121185 11/21/85 11/2i/85 11/21/85 11/14/85 11114185 11114185 11/14/85 11/14/85 11114185 RECEIVED 11/16/85 ~ 11/16/85 JAN 11/16/85 11 / 1 5 / 8~k~ 0il & Gas Dn~ ~)~m~n 1 1 / 2 2 / 8 5 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 WELL []X OTHER [] 7. Permit No. 2. Nan~l~er/!~_~SKA, INC. 85 -6 8. APl Number 3. Add~ess O AOX 1 003 60 ANCHORAGE ALASKA 9951 0 50- 029 - :21 269 · · · · 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION' 458' FSL, 1066' FWL, Sec. 32, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 05 ' (RKB) 6. Lease Designation and Serial No. ADL 25644, ALK 2575 10. Well Number 2U-3 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOl_ 12. 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 November 16, 1985 Kuparuk well 2U-3 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into "A" sand. the 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~, ~/r~_,~ ~)~~ Title KUPARUK The space below for Commission use Date 1 2 / 1 R ! 85 OPERATIONS COORDINATOR Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate RETURN TO: ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ...... · : ~.'. ':.. DATE: 10- 31- 85 · " :' TRANSMITTAL NO:5421 . ':. ARCO ALASKA, INC. KUPA_RUK OPERATIONS ENGINEERING RECORDS' CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERi~WITH ARE THE FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF T~IS TRANSMITTAL. FINALS/ SCHL/ C~4ENT <ONE * OF EACH> ~lA-3 / CEMENT. EVALUATION TOOL -lB-4~z .CEMENT EVALUATION TOOL -TR-11/ CET/CEL "1R-12" CET LOG ~2A-13 - CBL/VDL 2A- 13 ~/ CET/CEL J2U-3-~ CEMENT L~VALUATION TOOL '~2U-10j CEMENT EVALUATION TOOL '~2Z-13/ CET LOG ~2Z-14~ CET LOG ~'2 Z-15~ CET LOG '~2Z-16-. CET LOG ~3B-4"7. CEMENT E%~ALUATION' TOOL ~'3B-12~ CET LOG v3B-12 J CEMENT EVALUATION LOG W/ AC ~3B-16 ~'' CEMENT k~¥ALUATION TOOL -3C-9 '/ CET LOG ~3C-10~' CET LOG PLEASE ACKNOWLEDGE 05-04-85 RUN #1 7468-8287 05-28-85 RUN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN ~1 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN #2 6100-6600 05-19-85 RUN #1 5450-6950 07-09-85 RUN #1 6000-8411 07-09-85 RUN '#1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN #1 6100-8011 05-31-85 RUN #1 6000-7743 07-14-85 RUN #2 6139-8089 07-06-85 RUN #1 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 RUN #1 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: DISTRISUTION: BPAE DRILLING*BL W. PASHER B. CURRIER L. JOHNSTON ,. hXXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEkK*BL J. RATHMELL ~-' u.~ COns. SOHIO /SE UNION VAULT/~O*FILMS ARCO Alaska, lnc?"'-" Post Office ,.,,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-19-85 TRAI~SMITTAL NO: 5360 RETURN TO: ARCO ALASKA, INC. KUPARUK OPkKAT1ONS ENGINEEEING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND HERh%~ITH AkE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETUR/~ ONE SIGNED COPY OF T~I~ TRANSMITTAL. SCHL/ CBL 'S 04-26-85 RUN #2 7600-8842 04-26-85 RUN #1 5500-80lB 04-16-~5 kUN #1 6095-9046 03-02-85 RUN #1 3650-6690 04-21-~5 t~UN ~1 5595-7888 04-21-85 KUN #1 5895-7383 04-25-85 RUN #1 5900-7818 04-25-85 RUN #1 75U0-9123 FINAL PRINTS/ --~ 1Q_i~' 3~y lQ- 2~' -~Y'IQ-4 / ~ -v2U_3 ~/ '~2V-10 ~ ~ 2V-12 / RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M DIbTi~iBUT1ON: DRILLING*~L W. PASHER L. JOHNSTON EXXON MOBIL P~ILLIP$ OIm N5K CLEi{K*BL J. KAT~E4ELL STATE OF AI,~KA~*BL ~OhlO /bE UNION K.TULIN/VAULT*FILM ARCO Alaska. Inc. is a Subs~0iary of AtlanticRichfieldCompany ARCO Alaska, Inc~-~-- Post Office _ ~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 dri!lsite 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 2 o Cons, Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK'~-'~)IL AND GAS CONSERVATION C-'MMISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, :[nc. see attached 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 5o- see attached 4. Location of Well 9. Unit or Lease Name Kuparuk River Unit N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 6. Lease Designation and Serial No. see attached 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. 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). Pursuant to form 10-403, it is proposed that the attached list of;Aproducing 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 wi31 occur approximate3y.12/15/85. :[njection will be into the A and C sands. SE? 2 0 19B5 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: Form 10-403 Rev. 7-1-80 ~pprovecl Cc~y ]~.eturrmd / By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 -- 8 - 9 MARK:0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 2580 12/15/85 " 10/15/85 " 12/15/85 25653 2579 12/15/85 " " 10/15/85 " " 10/15/85 " " 12/15/8~ 25658 2584 10/15/85 " " 12/15/85 " " 12/15/85 " " 10/15/85 029-21246 25658 2584 12/15/85 21227 " " 12/15/85 '21213 " " 12/15/85 21214 " " 12/15/85 029-21058 25657 2583 12/15/85 21063 " " 12/15/85 21062 " " 10/15/85 21065 " " 10/15/85 21032 " " 12/15/85 21035 " " 12/15/85 21048 " " 10/15/85 21052 " " 10/15/85 029-21150 25656 2582 12/15/85 21165 " " 10/15/85 21119 " " 10/15/85 21124 " " 12/15/85 21140 " " 10/15/85 21159 " " 12/15/85 21163 " " 10/15/85 25644 2575 10/15/85 " " 12/15/85 " " 10/15/85 25643 2574 10/15/85 " " 10/15/85 " " 12/15/85 25655 2581 10/15/85 25644 2575 10/15/85 " " 10/15/85 .... i2/15/85 25655 2581 10/15/85 " " 12/15/85 25642 2573 10/15/85 " " 12/15/85 " " 12/15/85 ;', ,," r. / 5/85 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 Alaskr~ Oil & G..-':S C;or~5. comm!smor, ARCO Alaska, Inc. Post Office Bo~, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 11, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-3 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 2U-3. questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU10/L67 Enclosure If you have any RECEIVED J ~! L J. ::, ,,....,,., .. . l',¢i(tP:ii ;!,,,; ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA L _ AND GAS CONSERVATION CC ~llSSION 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. 85-6 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21269 4. Location of well at surface 9. Unit or Lease Name 458' FSL, 1066' FWL, Sec.32, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1109' FNL, 1277' FWL, Sec.5, TllN, RgE, UM 2U-3 At Total Depth 11. Field and Pool 1428' FNL, 1:~36' FILL, Sec.5, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 105' RKBI ADL 25644, ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 02/14/85 02/18/85 02/19/85* N/A feet MSLI 1 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey ] 20. Depth where SSSV set I 21. Thickness of Permafrost 6865'MD,6275'TVD 6718'MD,6151 'TVD YES [~X NO [] 1807 feet MD 1500' (approx) 22. Type Electric or Other Logs Run FDC/CNL/GR, DIL/SFL/GR, C01,' Gyro (GCT), CCL/Temp, CET 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 115' 24" 200 cf Poleset (Approx. 9-5/8" 36.0# J-55 Surf 3008' 12-1/4" 600 sx Permafrost E & 600 sx Permafrost C 7" 26.0# J-55 Surf 6798' 8-1/2" 300 sx Class G & 250 s~ Permafrost C -- 24. Perforations open to Production (MD+TVD of Top an~l' Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6424' - 6431' :~-1/2" 6386' 6363' & 6102' 6435' - 6475' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6279' - 6326' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addel~dum, dated 5/2/85. 6:~48' - 6350' 250 sx Class G 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 GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing PressUre CALCULATED , OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 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 Alaska (;ii & Gas Cobs. Cor:tmission Form 10-407 * NOTE: Tubing was run and the well perforated 3/30/85. GRU10/WC07 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ...................... : ...... - .... :-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 6279'-.:?F 5787' N/A " Base Upper' Sand 63'21 ' 5821 ' Top Lower Sand : --6406' 5892' "::~ - '.'~ ",'-,' . " Base Lower Sand 6551 ' 6012' i:-:j ',- ~ .... _. ':i~,". ,' . ":... '~: . . · ' ~ ':' -' ;-: ':i' ~! ' ~ .. . ~ · 31. LIST OF ATTACHMENTS -. .- ..... Addendum .... ~ : ' - ' .... 32. I hereby certify that the foregoing is t.rue and correct to the. best of my know!edge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska:~ Item 1' Classification of Service Wells:. Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 4/17/85 Frac well in 8 stages w/285 bbls gelled diesel, 700# 100 mesh, and 15,100# of 20/40 mesh. Log well w/CCL & temp tl. Drilling ~uperintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2U-3 Dear Mr. Chatterton- Enclosed is a copy of the 2U-3 Well History to include with the Well Completion Report dated 04/03/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU9/L66 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .--- · ALASKA L..~ AND GAS CONSERVATION CC; ~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-6 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 ' 50- 029-21269 4. Location of well at surface 9. Unit or Lease Name 458' FSL, 1066' FWL, Sec.32, T12N, RgE, UN !LC',.' T.'~ i..,;.::i Kuparuk River Unit At Top Producing Interval { '-/.[i::i'iLZ, ~ 10. Well Number · 1109' FNL, 1277' FWL, Sec.5, T11N, R9E, UM :~._.:-f.___~K___i 2U-3 At Total Depth i ~-, :.~ ,~.' ~ ~., '.._ i 11. Field and Pool 1428' FNL, 13:~6' FWL, Sec.5, T11N, RgE, UM ................... "- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 105' RKB ADL 256~4, ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/14/85 02/18/85 02/19/85 N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness °f Permafrost 6865'MD,6275'TVD 6718'MD,6151 'TVD YES I~X NO [] N/A feet MD 1500' (approx) 22. Type Electric or Other Logs Run FDC/CNL/GR, DIL/SFL/GR, Cal, Gyro (GCT) 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 115' 24" 200 cf Poleset (ADDFOX . . 9-5/8" 36.0# J-55 Surf 3008' 12-1/4" 600 sx Permafrost E & 600 sx Permafrost; 7" 26.0# J-55 Surf 6798' 8-1/2" 300 sx Class G 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) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A I. 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) 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 =~,, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lit(~ology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None R£:C[IV[D APR. 1 7 1985 Alaska 0il & Gas Cor~s, Commission ~nchorage Form 10~,07 GRUS/WC/+2 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. .... · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DE. PTH _,GOR,and-timeofeach phase· . . .. Top Upper Sand 6279~-:~. 5787' N/A " Base Upper Sand 6321' - 5821' Top Lower Sand ~ 6406' ' 5892' '.. -- ' .' Base Lower Sand 6551 ' - 6012' · ~? :: ' : ;. -i i '~ ~"' .... ' ' . . . · · . ' -~, [ Z :", . : , ;' ; ~- : . · : , .-. f~-.;- .- . , -_: ;,' 31. LIST OF ATTACHMENTS .. · Nvrn~rnn~r '.c;,,rvw:v (3 ror~es) · -.~ - _ ._ ~- ....... .~ · - 32. I hereby certify that the foregoing is true apd .C..o..rrect t© ~he best of mY knowledge : ., .. Associate Engineer Date #- INSTRUCTIONS General' This form is designed ¢or submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. .. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data .pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO. Oil and Gas Company ,~," Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is. spudded or workover operations are started. Dally wo~ prior to spudding should be summarized on the form giving inclusive dates only. DistHct Alaska Field Kuparuk River Auth. or W.O. no. AFE 603601 Westward #1 Operator ARCO Alaska, Inc. ICounW. parish or borough North Slope Borough ILeaseorUnit ADL #25644 Title Completion API 50-029-21269 ISlets Alaska Well no. 2U-3 ARCO W.I. IHour ]Pr or statue if a W.O. 0715 Hrs. Spudded or W.O. begun IDate Completion I Date and depth as of 8:00 a.m. 3/23/85 thru 3/25/85 3/26/85 3/28/85 3/29/85 Complete record for each day reported 3/23/85 56.24% 7" @ 6798' 6718' PBTD, Sqz cmt 10.2 ppg NaCl/NaBr Accept ri~ @ 0715 hrs, 3/23/85. ND tree, NU & tst BOPE. RIH w/perf gun, 4", 4 SPF, shoot 6348'-6350'. RIH w/pkr, set @ 6100'. Est IR of 2 BPM/1000 psi. M&P 250 sx C1 "G" blend. Switch to fresh wtr to displ. Lns packed off. Circ thru ann, unplug ins. Pmp cmt away. POOH w/pkr. RIH w/bit & scrprs, tag cmt stringers @ 6029'. Tst sqz & est IR of 3 BPM @ 1200 psi. RIH w/RTTS, set @ 6047'. Pmp 200 sx cmt. 7" @ 6798' 6718' PBTD, DO cmt 10.2 ppg NaC1/NaBr Rel pkr, POH. RIH w/drlg BHA, WOC. Tag cmt @ 6100'. 7" @ 6798' 6718' PBTD, RIH w/perf guns .. 10.2 ppg NaC1/NaBr ' Drl w/brine. PU TCP guns & 3½" tbg, RIH. 7" @ 6798' 6718' PBTD, TOH 10.2 ppg NaC1/NaBr RIH w/TCP guns, fire, no flow to surf, POH. cln. RIH, circ hole 7" @ 6798' 6718' PBTD, Setting BPV 10.2 ppg NaC1/NaBr Fin POOH. PU tbg conveyed guns & pkr, RIH, set pkr @ 6357' WLM, circ, POOH. RIH w/3½" CA, space out. PU tbg hgr, drop std'g vlv, set pkr. Tst tbg to 2500 psi. Shear SBR. Tst ann to 2500 psi. Set BPV. Rn total 199 jts, 3½", 9.3#, J-55 EUE 8RD IPC tbg. SSSV @ 1807' "D" Nipple @ 6378' Pkr @ 6103' TT @ 6386' The above is correct IDate 4/12/85 ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowabl~ has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. f Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ~Lease or Unit Well no, Kuparuk River I ADL #25644 2U-3 Auth. or W.O. no. ITitle AFE 603601 I Completion API 50-029-21269 Westward #1 Operator [ A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun I Date Completion I 3 / 23/85 Date and depth Corrlplete record for each day reported as of 8:00 a.m. 3/30/85 I otal number of wells (active or inactive) on this pst center prior to plugging and [ bandonment of this well I our I Prlor status if a W.O. I 0715 Hrs. 7" @ 6798' 6718' PBTD, RR Diesel/Crude Oil to GLM @ 6050' ND BOPE, NU &tst tree. Displ well to crude. Displ 30 bbls crude w/N? f/under bal. Drop firing bar, flowed well to tst tank. DrSp ball & sheared out gun rel. Set BPV. RR @ 0100 hrs, 3/30/85. Old TD New TD 6865' (2/17/85) Released rig Date 0100 Hrs. 3/30/85 I PB Depth 6718 ' Kind of rig Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production · Oil on t~t Gas per day - Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected JUN;> Alaska Oil & 6'aq The above is correct ~./~,~,~.. ~;~,o. (~Of/'lmi.~i~m..,.; Signature [Date ITit,e Iu,i~e ...... ~ ' ' ~Z ~,~.~~ 4/12/85 Drillin~ Superintendent For form preparat,o2 a;d gtribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, inc.' Post O,'lice E;ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE:05-29-$5 T93, NSMITTAL NO: 5199 RETURN TO: T ]b\NSM ITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-!llSB P.O. BOX 100360 AZ':CHORAGE, AK 99510 IIEREJ~ITI] ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK WELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 2A-7 04-23-85 2F-6 03-21-85 2G-8 03-21-85 2G-12 03-23-85 2I!-13 04-26-85 2ii-14 04-28-85 2tt-15 04-29-85 2U-1 04-11-85 2U-2 04-11-85 2U-3 04-11-85 2U-4 04-11-85 2U-5 05-02-85 2U-6 05-03-85 2U-7 05-04-85 2U-8 05-04 -85 2U-13 03-09-85 2U-!4 03-21-85 2U-!5 03-20-85 2U-!6 03-15-85 2V-2 03-23-85 2V-SA 03-17-85 2V-SA 01-24-85 2W-4 04-13-85 2X-! 04-14-85 ?X 3 04-13-85 2X-13 03-30-85 STATIC-'C' SAND STATIC-'A' & 'C' SAND STATIC-PBU-'A' SAND PBU-'A' SAND STATIC-PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND S'fATIC-'A' SAND PBU-'A' SAND PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND ST%"~¥C-'A' SAND STATIC-'A' SAND S TAT iC STATIC-'A' &'C' SAND STATIC-'A' &'C ' SAND STATIC-'A' & 'C' SAND STATiC-'C' SAND STATIC-'C' SAND STATiC-'A'&'C' SAND o~lC- A SAND STATIC-'A'&'C' SAND STATIC-'A' & 'C ' SAND PBU-'A' SAND -IECEIPT ACKNOWLEDGED: ;PAR* ~ CU?'~ER* ) & M* DRILLING L. JOIINSTON b10B I L * NSK CLERK DISTRIBUTION: . ,. i°l z~ .\ EXXON PHILLIPS OIL* J. RATHMELL* DAT~I~sk~ Oil & G~.s Ccr, s. t;ummms~:' S_A~ OF ALASKA* SO]iiO* UNIO~* K. TULiN/VAULT ARCO Alaska, Inc. Post Offic, x 100360 Anchorage, ...,iaska 99510-0360 Telephone 907 276 1215 F.'r-: T URN TO' ; /I ...... - F:.: E C i:? Z I"' T ,"-'; i,.' D DATE' APRIL i9, i985 TRANSIdlTTAL N.O'~ ~t-1'7. F'AG E A.F.:CO AI_A;~I<A, Ii'~.C. AT'tN: r-::ECC1RI)S C;L_ERI( ATO- i i i 5B F:'. C) . !:~(:IX i · :',J F' 1 I , A !", (') F, ....,",0~-.~--~, AJ( '.:" .-'...'t 0 L-,r,F--,,,ZTH ARE '['1"1~'' F--Ol L_FII.,IING I l!...I, _..-..~ ._ IRETURN ONE SIGNED CO!-"'Y Il'EMS.' F'I '-'A°IE ACl,.~f'r'ilJ/ F'f',f~r- .... EL ,2. _x .......... . __ I.:. OF TI--Il,? 'FI-RAN~MI'I'TAL. t OF 2 -:.:' I---; [;-! 'J E i',' (] E OF EVENTS' i!E--3 'A' £AU.D i m._.m ,~ T?~T T Fi , '... ,_., ~ -- '~ v-i i F'F,'I I i Y- i t F'BU ..:L -%' I-' ,~-, L) '-~ Y - i .--~ p RI I i ,t'l ..- o ,r.., Ii 1] ia--2 GELI._ED 1,,!ATER FRAC iG-i I-iYDRAUL_IC FRAC I L.-i6 PO~T FRAC TEHP ..... ,_. i F'RU ...... --> ~.~ ,-.; , .L, _. i F.,_ -- ~ ~_~ F" ~r--: U .? i'.-.,. _-~ i' ' mD WATER BATCH .._ "- ~a. 7 .. ~ _ ~ ~.."--"~m~-_, POST, FRAC TEEMF' LOG 2 W ..... ~ ~ , --; .--. TAT T C BHP .=..-:-'._, ,:~ TAT I P. iE-~6 INJ~CTIV!TY TE,?T '~ I I .... ---~-, ..... .... ~,,-,T~C 3/'IP 2U-3 B!--!F' .,,._,..'-"~ ~_ BHP '..]LI- i )_--,' i"! F:' -~',... i z. .c...:.,'_, - i !----i 6 POST FF..'AC TEMP · -~ v T:' -J F' ~'.; ,,% --~ ~ ...' ! , . -- PI-I-mT ~ F" i/' ....... FRAC TEMP 'i F .... i 6 HY!). FF,'ACTUF,:E ~_ - -- ? I---"F-:I ' ~:. ,' F' B U FRAC-.GELLED WATEF~ I~IF' LOG LOG FRAC -'I / 3 / 8 5 4/3/85 3/3"i / 8'"- · 4/i -2/85 3/3 t/85 3/3~ '1;'t/85 4/i/85 ,~ ~o_/85 ,~' t...,: 'I/i i -i 3/OD F_.,E(]~-iPT ,,,-, ,blOb;; EZ'_,cF-n- L_ . I'-i L, ~-, .... - ..... - BF'AE . B~ CURRIER c , ,... RON .... F,ETM D ~ STRI [;UT I rjf~. DRII_I_. I?.1r_,..,.. I,,,I., F'ASHER I .....I[)HNSTON EXXON MOl)IL F'H l LL l F'.S' OIL NSK CLERK J~ RAI'HNELL ARCO AImIkm, Inc. II m $ub$1dim~¥ ~! AIImnIicRichlieldCompmny CSTATI:' OF AI-A.,~ _ ¢-..' 0 I-.I I O tJN I ON K ."F I.J L_ I N/VAI_II_ T ARCO Alaska, Inc. Post-Office B{' 100360 Anchorage, Alaska 9951'0-0360 Telephone 907 276 1215 ,i' i...T I" ';h f':. r:' · . ~.'.: ',,'" !.:; E: F;: L. O,.0 I( ,, I) :I: 1.../.,.";' F L.. - g F/ r;,.., l::.'" ,',;'" / N I: U -' C; R '"' IR ¢-, H ):) !ii: N ..,"' N l:'7 LJ '-G R '"' F:' Ci I:;~ C) I) ]:,I... Z.,?.F"' L..'"' C:; f;: .... 17.':.' I.":: N ./N E U "' (; I:;~ "-I:;~ r.':i I.'.,'"' ,::. N/'N E U- G R --F' CI I";,' 0 r.7; Y E.~ E: IR L.. O O t( ' ' ...:.,::' ,,. ...r) :E I... / ,!.:' I-:' L --. 6 ....'~'"'" I) F:'... N / N E tJ ( F:' C) R C) )' ' ..,."=" I) IE i'4 / N E: U ( i:;: ¢., t4 .'~ ">" I) :[ I... / S I"- L -g R '":'" I) E N / N Ii::. U ( F' 0 I::~ C) ) '.?. "' I) Ii!: N / NE tJ ( F: ¢., t.,.J ) 7t 00--'7850" ' ,3549 .... 7906 7 t 00'"'7:.'369 ' '7 i 0C:'-'786':? · 7, 5:4 ':;:. .... "',' ':':','. '.":).. 6 '71 0.0-.'7c:,'" ..'.~ .... 5,< 71 0 (.)--. 7 :.'.'!<f.,5.> ,. 41as~a 0il. &. 6as Cons. Commission Anchorage )) r.-';"i'E: ........ ~......,: .................... .','.",'57'¥ I::, T' !7 ('i F"' ~'~ l.. :' ,....' !.:: ,':.'.~ ,5.' ['~ I' I ...... l'O' r f !?.. t,.. "-: 'j ..,':' r:., .... ~ U N :I: C) !"..! ( F :[ L. i"! ,.'7 ) ( i '-' :(:'. I... > ~,: l(., 'f t.,~ L.. 2: ?'.!/' V ~:; :J l... 'I" ......................... "lR¢.O:.,Ua.~ka.,~l~-*~ ;k~/ub,si~ ~.rjLofj._At..an_t.i.F_R..fc.h'{.i..el_dCgmPany ................................................................ ,.- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 8, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2U-3 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. Tubing details will be submitted when the well has been completed· If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L94 Enclosures RECEIVED APR 1 7 ]985 OiJ & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 2, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2U-3 Dear Mr. Chatterton' Enclosed is an addendum to the Well Completion Report If you have any questions, Sincerely, the 2U-3 Well History dated 03/25/85. to include with . J. Gruber Associate Engineer JG/tw GRU5/L91 Enclosure please call me at 263-4944. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED APR 0 9 IgC5 /tlaska Oil & Gas Cons. CorrlrnissJon Anchorage ADDENDUM WELL: 2/28/85 2U-3 Arctic Pak w/250 sx PF "C", followed by 55 bbls Arctic Pak. ~Drili{~ Superintendent RECEIVED APR O 9 Alaska Oil & Gas Cons. Commission Anchorage Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 28, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-3 Dear Mr. Chatterton. Enclosed is a copy of the 2U-3 Well History to include with the Well Completion Report, dated 03/25/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU5/L66 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Well History - Initial Report- Daily Intl~uctione: Prepare and submit the "Initial Rel~rt" on the first Wednesday after a well is spudded or workover operations are started. Daily wort( prior to spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough Alaska North Slope Borough Field Lease or Unit Kupaurk River ADL 25644 Auth. or W.O. no. ITitle AFE 603601 I Drill, Complete & Perforate State Alaska Well no. 2U-3 Doyon 9 API 50-029-21269 Operator ARCO Alaska, Inc. I^RCO W.,. 56.24% Prior status if a W.O. Spudded or W.O. begun [Date IHour Spudded 2/14/85 1015 Hrs. Date and depth as of 8:00 a.m. 2/14/85 2/15/85 2/16/85 thru 2/19/85 Complete record for each day reported 16" @ 115' Accept rig @ 0500 hrs, 2/14/85. NU diverter sys. 16" @ 115' 3025', (2920'), Circ Wt. 9.3, PV 12, YP 29, PH 9.0, WL 10, Sol 6 Spud well @ 1015 hrs, 2/14/85. Drl 12¼" hole to 3025' 9-5/8" @ 3008') 6865', (3840'), Rn 7" csg Wt. 10.2, PV 13, YP 9, PH --, WL 4.8, Sol 13 C&C, 12 std short trip, C&C f/9-5/8". Rn & lnd 75 its, 9-5/8", 36#, J-55 BTC csg @ 3008'. Cmt w/600 sx PF "E" cmt & 600 sx PF "C" cmt. CIP @ 2248 hrs, 2/15/85. Good rtns thru out job. Tst csg. ND diverter. NU & tst BOPE. RIH, drl'g 10' new hole. 6865'. f/6860 1925', 3186', 3583', 4022', 4522', 5350', '5980', 6472', 6865', Conduct leak-off tst to 11.5 EMW. Rn FDC/CNL/GR f/6834'-6050'. 'Rn DIL/SFL/GR -3009' & CAL f/6860'-5250'. TIH, C&C mud. Assumed vertical 3.8°, S13E, 3186 TVD, 5.32 VS, 13.4°, S13.8E, 3575 TVD, 75.73 VS, 27.6°, S10.5E, 3987 TVD, 223.86 VS, 40.6°, S10E, 4399 TVD, 506 VS, 37.3°, S9E, 5042 TVD, 1028 VS, 36.6°, S9E, 5540 TVD, 1414 VS, 34.2°, S12.5E, 5940 TVD, 1698 VS, 32.7°, S12.5E, 6268 TVD, 1914 VS, Chg BHA. Drl w/ND to 5.2S, 1.2E 72.65S, 19.95E 219.42S, 48.98E 498S, 93E 1015S, 168E 1397S, 222E 1677S, 275E 1888S, 316E The above is correct Signature Pot form prepareflon ~nd distrt~tlon, see Procedures Manual, Sectiofl 10, Drilling, Pages 86 and 87. IDat$ 3/19/85 ITM Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporling the enlire operation if space is available. Accounting cost center code District County or Parish Slate Alaska North Slope Borough Alaska Field Lease or Unit Well no. Kuparuk River ADL #25644 2U-3 Auth. or W.O. no. T t e AFE 603601 Drill, Complete & Perforate Doyon #9 API 50-029-21269 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 2/14/85 Complete record for each day reported Date and depth as of 8:00 a.m. 2/20/85 I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 1015 Hrs. 7" @ 6798' 6718', (0'), RR Wt. 9.4, PV 12, YP 21, PH 9.0, WL 10.8, Sol 8 ~00 RU & rn 171 jts, 7", 26#, J-55 BTC csg. Cmt w/~d~sx Cl "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ w/257 bbls, 10.0 ppg brine. Bump plug. CIP @ 1035 hrs, 2/19/85. Good trns thru out. Set slips, instl pack-off, NU tbg head & companion flange. RR @ 1730 hrs, 2/19/85. Old TD New TD 6865' (2/17/85) Released rig Date 1730 Hrs. 2/19/85 Classifications (oil, gas, etc.) 0il Producing method Flowing Potential test data PB Depth Kind of r g Type completion (single, dual, etc.) S±ngle Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time IProduction I iOil 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 is correct Signature I Date I Title 3/19/85 For form preparation and distr~ution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent .. A.RCO Alaska; Inc.i .... . Post Ollice .b-,~^: 360 ~ -,:"(:z~ Anchorage, Alaska 99510 Telephone 907 277 5637 RE;'f L!F:~' '0'7 ~iii(~ (.1 ".nL,.fl..~1< ¢,-, TF;:¢ii"-.!f..:H iii T'T'(:iI... NO · '.5 i.',:';,':;" .. ! . __---:--.:-~ -- -' ...... i~--J' --''; ;I~'1i~1ri:' , .... ',, ~'.7,..~-'-_~ , ;.: 'f'i I~ :[' ~" ..... ' ....... l-., V ( ~ ...Il... 'f' ARCO Alaska, Inc. ~-~ Post Office B,.,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-3 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2U-3. I have not yet received a copy of the Well Hi story, but when I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L33 Enclosure RECEIVED MAR 2 7 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .~--, STATE OF ALASKA ..~, ALASKA · AND GAS CONSERVATION Cq ,VIISSION WI=LL COMPLETION OR RECOMPLETION'REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED r~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-6 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21269 4. Location of well at surface 9. Unit or Lease Name 458' FSL, 1066' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number. To be submitted when gyro is run. 2U-3 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 105' RKB ADL 25644, ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/14/85 02/18/85 02/19/85 N/A feet MSL N/A 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+'I~'D) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6865'MD 6718'MD YES [] NO I~X N/A feet MDI 1500' (approx) 22. Type Electric or Other Logs Run FDC/CNL/GR, DI L/SFL/GR, Cal 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 115' 24" 200 cf Poleset (Approx 9-5/8" 36.0# J-55 Surf 3008' 12-1/4" 600 sx Permafrost E & 600 sx Permafrost C 7" 26.0# J-55 Surf 6798' 8-1/2" 300 sx Class G 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) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 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 CHOKESlZE IGAS-OILRATIO TEST PERIOD I~ I OILoBBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE I~ 28. CORE DATA ~'~ II- r ~ i '~ / r" i'~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips,j~' II ~ l II V L ~ None MAR 2 7 1985 Alasl~ 0il & Gas Cons. C0mmissi Anchorage Form 10-407 Rev. 7-1-80 GRUS/WC20 Submit in duplicate CONTINUED ON REVERSE SIDE · , ... · 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 6279'' N/A N/A . Base Upper Sand 6321' N/A Top Lower Sand -6406' N/A Base Lower Sand 6551' N/A' · · . _ . .- . . 31. LIST OF ATTACHMENTS' ' None ,- . -. .: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ Title A$$°¢iat:;e 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 (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- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". $UB'$ URFA ~E DIRECTIONAL SURVEY [~'1 UIDANCE I'~-I ONTINUOUS ~-~ OOl RECEIVED APR ~ 7 ~985 Company ATLANTIC RICHFIELD COMPANY Well Name 2U-3 (458' FSL, 1066' FWL, S32, T12N, RgE, Field/Location ~:U~A~U~, N0[~H SLOPE, A]'.ASF~ Job Reference No. 70169 Lo~3{3ed By: KOZUSKA Date 13-MARCH- 1985 Computed By: * FOR a~CO A[,ASKA, INC, ? U - 3 KLIPARUK NI]RTH S£,nP~,ALASKA SURVEY DATE: TOF~L !.,PC~llr]~l: '~A~?'GFNTthG- averaged deviation and azimuth VWi~TIrAI, SECTfU": ',.if~RTZ. niS'r. PROJECTED ONTO h TARGET AZIMI,ITH nf' SnUTH 8 BEG 8 MIN EAST CD,,~lPd:rATIf3i'~ I)AT~: 13-~AR-R5 · DATE OF SURVEY~ 03-FES-85 KELLY BUSHI'NG ELEVATION: 105,00 FT ENGTNEE~: KOZUSKA INTERPO[,ATED YaI,OF$ FnR EV~.]M 1.06) FEET OF ME2$TIRED DEPTH Tr~IJR SU~-SEa ~E/t,511Rr,'D ¥~RTICA~. YEP'£TC~b DEVIATION DE p',rl.~ OEP~h DEPTH DFC MTN l,J P. G n oO 00o -105.00 1 oo~ ~o o9:99 -5.0! 9,.00. ~30 109 9q 94.99 ]00. fl(.) 299:gn 194.99 400.00 399.9~ ~94,q9 500.OU 499,9~ ~94.99 600.00 599.90 .494.99 700,0U ~09 90 594.g9 ~0O.OC 709:90 69~.09 QOOeO0 ~O~' 90 794.99 1nO0.O0 909.9(.) R94.09 11 On O0 10q9 9° ~94 a9 1200 ~ O0 11 q9 ~ 9q 1094 ~ g9 14On. a(') 1399 99 179~.99 l~OO n() l~q9;qR 1294.e~ 160n: nO 15~9.9~t ] 494.9~ 1700, O0 1099.97 ] 594,, q7 1PO0.O0 17~9 95 ]~94.e5 /gUO,O0 1809:93 1794.03 0 16 0 15 O].7 0 2~ 0 37 ! 0 0 5~ 2oOO.nO 1909.92 iPO4.o2 0 56 21.00,o0 7,.')n9,91 lq~4,()j 0 bO 2200 O0 9109 ~q 2ng4..R9 1 t 2300~o0 7209:8R '21. 94. RF, '.11 24On.nO '23q9. ii6 2~94.n6 I 4 2~O0.no 24q9,84 ~239a. R~, u 5R 260~. o() 75Q9,8.'~ 2~94.~'~ 0 47 2700.0U ~609,6'~ 2594,~3 u 31 2ROn. Ou 97qg.u? '2~94. ~2 0 37 2gOo.nO !8q9.~ 2794.~2 () 40 V~,:~TTCAb DOGB~,G RECTANGULAR COORDINATE8 HORIZ. DEPARTURF SECTIO~,i SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET Di{q/1 uO FEET FEKT FEET DEG O,00 0,00 0,00 '0.36 0,45 0.31 -0.35 0,66 0,2~ -n,24 0.82 0,15 -0.09 l,Og 0.02 0.00 1,1g 0,II 0,08 1,(,)7 0,21. -0,07 0,97 0.09 -0.36 0,96 0,18 -0.46 0,80 0,25 -O.]t 1.02 ' 0.10 n.o4 1,04 0,26 6),43 1,03 0,64'S' 0,89 0,67 1.07 1,46 0,75 1,61. ~.09 0.85 2,18 ~.81 1,07 2,84 3,51 0.19 3,35 4.n7 0,37 3.66 4.50 0,70 3,83 4.R8 0.44 3,99 5.79 0,92 4,17 5.RB 1.14 4,52 fi.24 1,28 4,63 &.15 0,7~ 4,29 5,00 0,72 3,80 S.6I 0.31 3,30 ~,39 0,43 2.95 5.25 0,86 2.70 5.40 0,48 2,7! 5.03 1,02 3.08 6.99 0,54 4,0t ln.22 7,74 7.08 23.17 1,13 19,67 4n,59 0.17 36,61 5R.R9 2,39 54,36 80.75 1.23 75 59 105,04 3,43 q9:46 133.&4 4,21 127' 87 1og.~3 6.8~ 162,29 0 O0 E 0:35 W 0,52 W 0,69 W 0,79 W 0,87 W 0,96 'W I 13 W li33 W 1 44 W 0 O0 NO 0 g 047 N 48 7 W 0 59 N 61 21 W 0 70 N 78 I W 0 79 $ 88 17 W 0 88 S 81 45 W 0 8 S 77 25 - 1 ~3 $ 85 2~, ') 1,34 N 82 25 W 1,47 N 80 2 1,49 W 1,54 W 1,40 W 1 21 W 0~~93 W 0 48 w 0 01. W 1,34 F., 3 14 F 4:98 E 1,50 N 86 15 w 1.56 S 80 21 W 1,54 S 65 ~2 W 1,6~ $ 48 30 W 1,86 $ 30 b W 2,23 $ 12 33 W 2,84 $ 0 6 W 3,61. $ 21 44 E 4,8~ S 40 35 i 6,28 S 52 23 E b.54 8 19 9!94 11 70 13.44 15.13 16.51. 17,44 18.25 19,26 7,66 S 58 34 E 9,19 $ 63 2 E 1.0.92 $ 65 33 E 12,58 $ 68 25 E 14.11 $ 72 18 g 15,60 $ 75 54 E 16,83 $ 78 41" 17.b~ $ 80 24 ) 18,45 8 81 35 ~ 19,45 $ 82 0 E 20,35 21.35 22.68 26,0g 30.71 35.84 20 5~ $ 81 23 g 21 72 S 79 21E 23 76 S 72 40 E 32 67 $ 52 59 E 47 7~ S 39 59 g 65 11 $ 33 23 E 41.81 F 86,38 $ 26 56 E 46.50 F 109,79 S 25 3 g 49.84 r 137.24 S 21 17 E 53,49 E 170,88 $ 18 14 E A~C~ A L~ ;5I(A, '[' R U F' fi i.J P - S il: A C o ,j R C~ v. ~EASI!Rt?t.) VFt{TICA[, vE~TTCAI,, DEVIA'rlo!~ DEP'i'!'~ DF. PTH DI.','P'rH DEG MTN t)Fl(.; MTN PAGE 2 DATE OF SURV~Y~ 03-FEB-85 KEI, bY ~USHTN~ ELEVATION: 105,00 FT 50Om.nO 4769 02 4604,02 38 ,'~ 5100 O0 4a4'1~ J,'% 47,'{9.36 ]~ 15 590o]00 49~b· 99 4~2n. 99 3~ o 5]00.00 ~005,04 4o0n.04 t7 3~ 540~,00 5084,50 4070.50 ~7 9 5500.00 K164 O~ 505o.~8 IH o 5600.00 5243:16 5138.1~ 3'1 20 57o0.00 g391 ."Ig 5916.75 38 26 5800.0{) g400,28 529~,P8 ]7 5R 5900.00 5479,44 5]74.44 37 20 600o.nu gSS9,'on ~454.50 !1o 6100.o0 5640,20 5~35.79 35 62U0.00 ~721.91 3~16,0~ 6300.00 5804.17 569o.17 Iq 20 6400.00 ~b,bg 57~1.68 'Iq 27 650n.o0 5969.~7 596d.~7 ~ 3 660~.00 6052.4~ 5047.4.2 6700.00 ~l]f),l~ 6831,18 33 1 6~0o.00 6290,'0] ni 15.03 6~65.m0 6274.~3 nloo. K3 33 ! 4non.no 3970.3~ 3~a5.'38 2b 4100.o0 4058,33 30.53,33 30 47on. O0 4143,74 4038.74 32 30 43()0.~(~ ,~,22b.bo ~121 ,60 35 1q 440n,00 4306.96 4901 .g6 38 4 4500.0() 4.3~4,40 497q,~0 40 460o.00 4,t60,54 435K.54 40 21 4700.00 db37,0q 4437.09 ~9 4~ 4000.00 4b14.04 .4sug, 04 39 34 4~00,00 46ql ,2~ 4586.~4 ]9 17 VER'fTCAb DOGG~G RFCTANGUI,~AH. COORDINATES HORIZ, DEPARTURE S~CTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH F'~ET DEG/1.00 FEET ~EET FEET DEG g 5 lO F S 5 23 E $ 5 41 ~ S b 1. F 992,14 $ ,!5 30 ~ 1052,82 $ 7 lg ~ 11.13,~6 S ~ 4~ ~11.74,55 $ 0 17 E 1~36.]4 S 7 33 E 1~59.31 S 8 lg ~ 1410,24 S 9 4 F, 147~,16 $ 9 45 F. 1535.o2 S 10 6 E 1599.76 ~ ~'.) 17 ~ 1649,22 $ ~ 0 37 E 1705,56 $ I0 41 E 1761.06 K !~') 3~ ~ 1~15,64 S 10 31 F~ lg70.88 $ 10 31 F 1905.47 ~07.15 930.03 $ fJ 51 P 210,~8 ,4,31 203,89 g 6 7 ~ Pb7.84 3,"12 250,91 S 't 0 F 309.03 3,40 302.45 g 4 50 F7 365.76 2,95 358,08 S 3 5P E 425,1() ] 54 417,45 $ 4 3q W 48~,21 l:5g 4~0,55 $ 4 5S R 552,93 0,66 545,14 ~ ,i 57 F 617,17 0 27 609.24. ~ 4 56 E 6~0,94 0~38 672,87 S q 49 E 744.39 0,76 736,20 0,35 798 ~ S, I15,68 E 807,15 S 8 .1.4 E 0,28 860~.. S 121 36 E 869,23 $ 8 1E (},7~ 9P2 19' 8' 127~34 F 930,94 S 7 51 E 0,52 983,12 S. 133,6~ E 992,16 S 7 44 E 1.16 1.043,48 S '14,0,2~ E 1052~86 S 7 39 E 1,90 1103.56 S 147,79 F 111.3,41 S 7 37 E 1,61 1164.31 S 155,11 ~ 1174,60 S ? ]5 E O,b3 12~5 7g S 161,86 K 1236,4~ S 7 ]1E 0,76 1287128 $ i68,~6 E 129~,31 $ 7 ~8 E 0.5~ 1347,91 S 176,44 E 1.359,41 $ 7 ~7 E 0,55 0,9~ 0 62 0~6~ 0 69 0~40 0,81 0,00 0,00 0,00 59.64 E 212 43 S 16 18 g 66.78 E 259 65 S 14 54 E 73 66 E 311 79i60 E 366 ~3 69 F~ 425 98 34 E 488 93 7~ ~ 553 99!35 104 86 E 680 ,~0 19 E 744 29 $,13 41 E 84 S 12 32 £ 76 S 11 20 g 60 S 1024 E 15 S 9 47 ~ 29 S 9 lb . 99 $ 8 51 g 40 $ 8 30 g 140'1.27 S 1~4 74 E 1419,34 $ 7 28 E 1465,5~ S 193:53 E 1478 25 ~ 7 31E 1.522,50 S 203 12 E 1535 99 $ 7 35 E 1578.5~ S 212:90 E 1592 81 S 7 40 E 1634 12 $ 2~2,94 ~ 1649 26 S 7 46 E 1689~58 $ 233.08 17~4,i7 S 243,38 E 1761,07 S 7 56 1797,87 S 253,40 1851.44 S 263,36 E 1.870.0~ S 8 5 E 1886,27 S 269,83 E ~905,47 ~ 8 8 E ENGINEER: KOZUSKA PAGE 3 AP, CrI A,L,r,,SKA, TNt. N,ORTH 5f,[..iP[,~,ALASKA DAmE Or SURVEY: 03-FEB-B5 KEL6Y RUSHING EbRVATION: P2.NGTN~EI~: KOZIISt<'A 105,00 1N'i'FRD[II,AT[,,;L~ VAT,I!,F. 5 FnR gv[{:~) 1000 FF.,ET OF t~FASUPED DEPT DEPTI-~ OW.,PmH DgP'r~ D~G ?,lIN [)t;',G ~,iTN VgRTTCAb hbqbgC RF, C?ANGUbA. R COORDINATES HORIZ, DEPARTURE SECTION SEVER.[T~ NORTIi/S~UTH EA~T/~EST DIST, AZIMUTH 0,00 O.UO N 0 O0 E 0,00 N 0 0 E 1,02 0.10 ~ l:4g W 1.50 N 86 15 W 0.44 3.99 S 6.54 ~ ~:66 $ 58 34 £ 4,31 20i 89 $ 59.54 E 212,43 $ 16 18 g 0..]5 7q~:82 S 115,68 ~ 807.15 $ 8 14 E 0.55 1407,27 S 184.74 E 1.419,34 $ 7 ~r ~ 0,00 18~6.2"? S 269,83 E 1905,47 ~ 8 . _ ARCh ;ti'..,~$l<,A, TNt. 2{!.-3 Nr~RTH SIr,OPE,ALASKa, PA~E 4 DATg 'OF' SIJRVKYI~ 03,,,FEB-85 KE[,bY BLISHING F,L, EVA'rTONI 105.00 FT ENGT:NK',ERt KOZIISKA IM'],'ERPO[,ATEF} VAT,!IR5 FnR EVEw 1.00 F't~F.T JIF St, IB-$~A r)EPTN ~EA6IIRFL, VFR~I¢~.L VEPTTCAL D~V~AT!n~'~ A~ . T DEPTH DRPTH DEPTH DEG NIH D~IG PIN n.nO O.On -105.00 0 n 5.0o 5.00 -100.00 0 17 105.nl J, n5.0n n.O0 0 7 2o5.nl 2ns.on 1 On.n0 0 7 3o5.nl, 0 ?00,00 0 7 405,01 4.05,. . 50.5..01 505.00 40n,O0 0 0 60.K.O] 605,()0 500,00 0 5 705,01 705,00 600,00 0 13 ~05.01 805,00 7OO,OO 0 13 905.01 9nb. On 1105.01 11n5,00 loOa. O0 1205.0~ 1205,00 11o0.00 1305.Ol 13n5.(}0 140~.nl ~4n5 un i~OO.nO 160S.O2 lbnSLOO iqOn. O0 1805.05 1805.00 0 ~. 0 7 0 15 0 16 0 25 0 23 1 5 1905.07 1 ~)nS. on .1, non. no 2005.nh 21()5~09 2105.0n 230~.13 2305,u0 2405.14 2405. O0 23uo.o0 2505.1 2605. 2705.17 2';05.0o 2~On.nO 2R05.18 ?~Ob. O0 270o.n0 0 5,1 0 5~ 1 1 1 0 57 0 40 t) 2 q 0 31 2q05. ~ ~ 2905.00 2Pun.no O 3q 300~.19 3005.00 20,)0.00 0 40 310~.?O 3105.0o jnOp.nO 0 57 3205.99 ~205.()o 31on.00 4 4n 3306.27 33nb. On 37~n. oO 9 5~ 3407.9~ ~nS.00 3~un.oO 1 0 ~ 350q.66 350b,oO 34on.o,.) 12 ? ~61~.~5 36n5.0o 3RoO.no 13 3n 3715.48 ~'105. O0 3Run.oO 15 3~ 3820.1~ 3805.on 37on.no lO ~ VERTTC~L D~Jm, t, EG RECTAHGULAR COORDINATES ftORIZ, DEPARTURE $F~CTION SEVERITY NORTH/SOUTH EAST/NEST DIST, AZINUTN ~ F.,E , DLG/100 FE~T FEET FEET DEG MIN 0.00 0,00 0.00 N 0,00 0.00 0,00 0,00 ~! 0,00 -0,35 0,93 0,30 ~ 0,34 -0.34 0.74 0,27 N 0,52 -n,23 0 85 0,13 N 0 68 .o.09 o:9 0.03 s 0:79 0.01 1.26 0,13 $ 0,89 0.08 1,26 0,22 $ 0,96 -ri.n9 0,65 0,07 S 1 13 -0,38 1,15 0,19 N 1:34 -0.4.5 0,67 0 24 N.. 1,45 -0.30 1,i4. 0:09' N 1,49 0,06 0,88 0,285 1,53 n.46 1,20 0 67 S. 1,40 O.gl 0,93 1:09 S 1,20 1.~9 0,87 1,64 S 0,91 2.11 0,92 2,20 $ 0.46 ?.~ 0,97 2.8~ S 0,04 3.53 0,11 3,37 S 1,42 4,10 0.36 3,68 $ 3,23 4.52 0,53 3.84 $ 5,06 4,00 0,53 4,00 $ 6,62 ~.32 1,00 4,19 S 8 28 R.go 1.02 4,53 S 10103 6,23 0,93 4,61. S 11 78 R.14 0,99 4,27 $ ~3:54 5.88 0,93 3.76 $ 15:22 5.59 0,57 3,28 S 1.6 57 5.38 0,63 2,93 S 17.4~ 5.25 1,03 2.08 S 18,29 5.42 0,57 2,'?1 S 19,32 5.97 0.77 3.11 S 20,40 7.07 0,65 4,08 S 21.40 10.63 7,50 7,48 S 22,80 24.25 0.87 20.72 S 26.38 41.95 0,26 37.94 S 31,07 60,89 1,96 56 3o $ 36,44 83.98 0,90 78~36 S 42,43 10g.16 3.53 103,54 S 47,10 140.09 3.66 134,30 S 50,43 0 O0 N 0 0 E O0 N 90 0 46 N 48 42 58 N 62 13 70 N 79 9 79 $ 88 9 W 90 $ 81, 31' 99 $ 77 1 14 S 86 28 W 35 N 81 48 1,47 N 80 28 W 1,49 N 8635 W 1,56 S 79 28 W 1,55 S 64 32 W 1,62 S 47 42 W 2:25 ~ ii 54 ~ 2,88 S 0 42 g 3,65 $ 22 56 E 4,90 $ 4! $6 E 6,35 S 52 45 E 7,73 S 58 50 E 9,28 $ 63 10 E 11,00 S 65 42 E 12 65 S 68 38 E 1.4 19 S 72 30 E 15 OB $ 76 6 16 89 S 78 47 ~7 72 $ 80 28 ~: 18,49 $ 8~ 39 E 19 51 S 82 0 g 20~63 S 81 19 E 21,79 S 79 12 E 24.00 S 71 50 E 33 54 $ 5! 50 E 49:04 $ 39 19 E 67106 $ 32 54 E 89'11. $ 28 26 E lJ~ 75 $ 24 27 ~ 143 45 S 20 34 E PAGE 5 DATE OF SURVg'¥; 03-FEb-85 Kg~,[,,Y RUSHTN~ ~EF,¥'ATXONI 105,00 ~;NGIN~ER: KOZI.ISKA I~I',fF:i(P[)[,ATE!~ VAI,tlF, S FOR EVi,:r~ 100 FEET OF SUB-SEA DEPTU R - $ E A VER'i'TCAb DEPTH VERTTC,AL D£)CLEG RFCTANGULAR COORDINATES HORIZ. DEPARTURE SECTIOI'.i SEVERITY NO~TH/SOUTH ~AST/WEST DIST, AZINUTH F~g'r DEC/l, 00 FEET FEET FEET DEG 3q27.&6 3~(~5. Oa 3RO0.O0 24 25 403R.q4 40c~5.00 3o0~.00 2.8 415~,d0 4105,{,)~ 4D~)O,O0 31 2] 4~73.61 .~2~5.00 ,1! 0~.00 34 49 439~,92 43nS.on ~i90o. O0 ~7 50 4527,09 4405,00 4~0o.00 40 29 4658, ~l. 4bo5,(]~ 44U~.00 39 55 478~,77 4605,0O 45ua,o0 39 35 4917.77 ~'loS,0n 460a.00 ~9 10 5046.01 4805,00 47un. 0~) ]8 26 14 F 17c~.35 4~% F' 2~2R. 12 ~n F 350.62 46 F 505.77 5'7 ~'. 590.44 56 F 673,48 b3 E 755,62 12 F 935,79 517~.33 4905.0n 4n()n.o0 3~{ 7 529e.n5 50n5,00 4oo0.00 37 31 542~.69 ~i05.00 5000.00 ]6 5g 5551.(~6 5205.u0 51Go,no 37 40 567P.~ K305.00 5900.00 3S 30 5R()5,n~ 54ns,on 53(')n, 0() 3'/ 56 593~.07 ~5n5.0o 540o,00 36 5R 6056.47 56(~5.00 5~()0. (1() '~6 6 6301.01 5805,00 570n.oo ~4 2o 997.10 1,0OR 1145.37 13.01,90 ~ ' 137R.~9 1452.6~ 1~24.06 i593.34 · ..q 1 u 17 ? 16ul. ,g 1~ 41 F 1720,60 ,'-.'. 10 31 F 1795,.39 ,~ 10 ~1 F 1R60.32 ~, 10 31 F 1905.47 4,11 1.21 3.07 3,,61 0,28 0 65 0: 0,80 0,67 173.31. 221 51, 278 60 342 99 415 94 498 07 582 5~ ~65 43 747:41 55 62 7O 78 ~3 89 97 104 827,38 S 11.8 01. E 39 F 230 56 ~ 287 30 F 351 59 F 4~4 80 E 506 02 ~ 590 21 E 673 15 F 755 26 E 835 181 83 S 17 36 E 13 S 15 43 g 40 S 14 12 E 81 $ 12 51 E 10 S 10 g ~0 S 9 2' ")~ 4 ,5 8 63 S 8 27 'E 79 $ 8 8 E 0.57 0.52 1,83 0.84 0.66 1.43 1.36 0.67 0,64 905,82 S. '125,73 ~ 914.50 $ 7 54 E 983.09 $ 133 bO F 992,13 S 7 44 E ,105~,85 S 142 01 ~ 1.068,33 S 7 38 E ~135.34 S. i~ 64 F 1145,42 $ 7 36 E 1.212.55 $ ' 44 F 1223.12 S 7 32 E 1290.94 S 169 30 F 1301,99 $ 7 28 E 1167,12 S 179 Ol E {378.79 $ 7 27 E 1440,34 S 1R9 63 ~ 1452'77 S 7 30 E 1510.8o S 2o1,10 F 1.524,13 S 7 34 E 1579.08 $ 213,00 E i593,39 S 7 40 E 0,80 0,7~ 0.00 0,00 1646 52 $ 225,20 1713:23 S 217.55 177';,95 $ 249,70 1841 84 S 2~1,57 1886~27 S 269,83 1661 85 S 7 47 E 1729:62 S 7 53 E 1795 40~ S 7 59 E 1.860,32 8 8 4 E 1905,47 S 8 8 E A6ASKA~ TNC, SI,OPE ~ ALASKA PA~E 6 DATE OF SLlPV~¥: 03-FEB-85 KELLY BUSHING .F..6EV'ATION: 105,00 FT £NGIN~EI~: KOZI1SKA SURFACE LOCATION ~RTGIN= 458'FSL 1066'FWb SEC32 TI, 2N R9E I,IM TVD, RECTANGULAR COORDINATES FPO!~ KB SUB-$E~ NORTH/SOUT~ EAST/WEST 6279,0o 5786.85 5681,85 1566 82 S E371,Oo 5R21,47 57!6,47 1590:~3 $ 6~t~6,()0 5~91.63 5786,63 1637'46 S 6551,00 601~.58 5906.5~ 1717,56 S 6'1;18,0C 6151,27 6046,27 1907,51 $ 6865.00 6~74.5~ 6169.53 1886,27 $ 210 84 E 215 01 223 55 g 238 36 E 255 20 r 269 O3 ~ , ARCh ~b.aSKA, TNC,. 'l',q'r,/~ h DFPTH PAGE 7 DATE OF SUPVEIt 03-FEB-85 KELBY BUStlING EBEVATION: 105.00 ENGTNEEP: KOZUSKA a279,o~ 64~6.0n 655t,00 6865,00 SURFACE bUCATION AT OR~(;I~= 458'FSL i060'FW~ SEC,32 T12N R9E UN TVD RECTANGULAR COORDINATES ~'P(;)~ KB SUB-SEA NORTH/SOUTH EAST/WEST 5786,R5 5~2~.47 5891.63 6011.58 01,5~.27 6274.53 5681 85 5716 47 5780 03 5906 58 6046 27 6169.53 1566,R2 1590,23 1637,465 1717,56 $ 1886, 210 84 E 215 O! g 223 55 E 238 36 E 255 20 269 P t,,.; P'I' f~! OF' PT ~1 P t.2P TH 6865.00 6274.~3 6169.5] Hr)R i ZOt~TAr,, [)PPAi~TURE 1905.4.7 ~ 8 8 E SCHLUMBEROER D I RE C T I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2U-3 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 03-FEB-85 REFERENCE 000070169 WELL: 2U-3 SURFACE LOCATION: 458' 'L, 1066' FWL, S32, T12N, R9E, , VERTICAL PROJECTION - 1000 -SO0 0 0 SOO 1000 1SO0 2000 -Tm.--...-m'±'?--x-m"-~-~-.-~.-_..-m.-.-:..---r-?--x "rT-'.'--"~" "'---..-'r"m'-,-m"'?'"x'-'???:.'"?'?-'":'"?'~'"I"'r"?"?"~'"~':'"? ....... t'":'"~'"?''~. ..... ?"?'~"'?"~" ~'"~'"'.-'?' "~'~...' ~-'F'i~T'"-T'T.'.. '~ ~ ~ T'~-~-Tff'Tn~'~' "~-T-.??T'T-'~- ~?T-:'."~.-~'i-T"?"-t--..-?-'t-v-?-'-t'--t-t ..... t-'t-'?~-T"t-'..."'t"'t · '"t"::.'"t-'r"? t"'t-'r"t"' ~ :'~-? ..--~?'"t-'?-qT-F'T'"-?-?-~-~--T"~ .~-' .~-~ .-f--~.' .~.-'-?"?~-~-' '~'~'"?~?'~'"~"~'"~ '" .~'-~"~-~--t'" .~'"?-+"~ ....... ?"? ~-'-,-----?-'"--,..., .... ~--.+ ..... ~-.-,..,--.? ~-., ..... 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'.,'":"':":"':"~ ...... ....... .......... ....... ....... ........... ..... .......... ....... ........ ..-i.--Li--.L~-..L~..-,-~--.-::-.,.-:--.~+,.-'-...~..+-~ .... ~-+++..i:-~.++.,.:-..-,...:~..:-..~:--.:...,+.+-..~......~-..,.~.~..~...~...~-..,.~ ...... ~-.--,...-~...-~...~-.-~...-~-.--~.-.~ ....... ?-~---.~.+-t-..i...:-..~..-~ ...... i.+.?t...~..~--.?.-.! .~.,'r,-~soo "-??:-":?"t'"?":"-:-'"~"-t'".'.'"?':-T,"?-~"']" .-t-??t'7'.:"-r'7~ -'~'~.:'":'"~'",'"'..-: ~ ? t ~:: ~ ] ....... , ........ .... · ........ : ................... ~ : J, :...~...,L..:...~...~, ....... .~ ...... .L...L...;..4 '......4, ............... -2000 - 1500 - 1000 -SO0 0 BOO ] 000 1500 2000 HEST F_J:~T Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. R, 'WE~ NAME AND NUliBER Reports and Materials to be received by: Date Required Date Received Remarks , , Completion Report Well History Ye Samples Core Chips Cor, ription .. Registered Survey Plat Inclination Survey _ - ........ 7 ~ ~ _5' , ~ ~.~ . ~, Drill stem Test Reports Production Test Reports ~ , < . Log Run -'"; ' ~. . _ = . Digitized Data ..7 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~arch 13, 1985 Mr. C. V. Chatterton Commi ssi oner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the February monthly reports for the following wells' 17-11 2C-11 2U-1 17-12 2C-12 2U-2 L2-30 1Q-6 2U-3 L1-9 1Q-7 2U-4 2C-10 1Q-8 2w-1 2w-2 2W-3 2W-4 If you have any Sincerely, Gruber Associate Engineer JG/tw GRU5/L18 Enclosures questions, please call me at 263-4944. RECEIVED MAR 1 4 1985 Alaska Oil & Gas Coils. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ,,--... STATE OF ALASKA ALASKA (_ _ AND GAS CONSERVATION CO,...~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 458' FSL, 1066' FWL, Sec.32, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 6. Lease Designation and Serial No. ADL 25644 ALK 2575 7. Permit No. 85-6 8. APl Number 50-- 029-21 269 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2U-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1015 hfs, 2/14/85. Drld 12-1/4" hole to 3025'. csg. Drld 8-1/2" hole to 6865'TD (2/18/85). Ran logs. Ran 6718'. Secured well & released rig ~ 1730 hrs, 2/19/85. Ran, cmtd, & tstd 9-5/8" & cmtd 7" csg. PBTD = 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 115'. Installed w/approx 200 cf Poleset. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3008'. Cmtd w/600 sx PF "E" & 600 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 6798'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run FDC/CNL/GR f/68~4' - 6050' DIL/SFL/GR f/6860' - 3009' Cal f/6860' - 5250' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /~~ ~ TITLE A$$o~a~ce E..~n! ..... DATE ~"'/Z"'~' NOTE--Repo~ on this form is required for each calendar month, regardless of the status of ;~e~a~ions, 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 TI"MD Submit in duplicate MEMORANOUM State of Alaska ALASKA OIL Al-ID GAS COI~SERVATION CO~,~ISSION TO: C. V.' on Chairm~Cfv '~ .<: F,LE NO: THRU: Lonnie C. Smith :<~7-~-'i~-"/<' D.BHL. 12 Commissioner -"() ~ ~PHONENO:I, FROM: Ben Le]~o ~'l~a~ ~ ~ SUBJECT: Petroleum Inspector Witness ROPE Tests on ARCO's Kuparuk 2U-3, Sec. 32, T12N,RgE,I~, Kuparuk River Unit. Frida%, February~ 15, 1985: I departed my home at 1:50 pm for a ~b' p~ ~hoWUp an8 3:20 pm departure via Alaska Airlines, Flt. #57 for Deadhorse, arriving at 5:00 pm. Weather: -42°F, calm, ice fog. Saturday, February 16~ 1985: ROPE tests on ARCO's Kuparuk 2U-3 began at' 4545 am an8~ Were Completed at 6:15 am. ROPE inspection report is attached. Sunday~, February 17, 1985: ROPE tests on ARCO's Kuparuk 2C-11 were C~mpi~ted,~ -the subject Of a separate report. Mpnd~y, February .18.,_19_85: Setting of plug across 9 5/8" shoe on ARCO's West Sak ~26 '~as completed, the subject of a separate report. Tuesday, February 19, 1985: ROPE tests on ARCO's DS 17-11 began at II-:UO- pm . . . Wednesday ,_ _February 20, 1985: . . . and were completed at 4:00 am, the Subjec~ of-Separate report. i departed Deadhorse at 10:00 am via Alaska Airlines, Flt. #54 arriving in Anchorage at 11:40 am and at my home at 12:10 pm. Thursday, February 21, 1985: Mike Seward, ARCO drilling foreman, ~vi~'ed-~he~KeilY ~'C~ was thawed and tested on,~February 18th. In summary, i witnessed successful ROPE tests on ARCO's Kuparuk 2U-3. , Attachment 02-00IA(Rev. 10/79) O&G tt4 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~ ~~~_ .~~ Operator /~z~~ Well Location: Sec.. ~ T/~R ~-- M ~ Drillin~ Contractor ~/~ Rig ~/ ~ Location, General Representative Permit f~Casing Set @ ~DO~ ft. Representative ~O~ ,~7~ ~ ~ ~ ~ Well Sign ~P~ ACCUMULATOR SYSTEM General Housekeeping _~P~-_Rig ~/~ Reserve Pit ~P/~i_ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Test Pressure Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psiR Full Charge Pressure Attained: psig ~~ psig /~ ~0 min ~ ~ec. ~ min ~ 7sec. psig Controls: Master z~P/~ Remote ~/Z_Blinds switch cover~-~-- Kelly and Floor Safety Valves Upper Kell~ Test Pressure Lower KellM Ball Type Inside BOP Choke Manifold No. ValVes /~ Test Pressure .~00~ Test Pressure ,~Oo Test Pressure .~~_O Test Pressure ~~ No. flanges Check Valve ~~- ~/~--~ Adjustable Chokes / Hydrauically operated choke Test Results: Failures ~:~ Test Time /~- hrs. Repair or Replacement of failed equipment to be made within ~ days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator ~/~ cc - Supervisor Inspector _ ARCO Alaska, Inc. ~ Post Office b,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 25, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Conductor As-Built Location Plats - 2U Pad Wells 1-8, 9-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L77 Enclosure ARCO Alaska, inc. is a Subsidiary of AllanticRichfieldCompany WELL 1 Y = 5,975,841.16 LAT. 70°20'42. 7599" X = 509,642.25 LONG. 149°55'18.2508'' I PAD =_LEV. 68.4 O.G. ELEV. 64. I FSL ~75 FWL 1,096 I WELL 2 Y = 5.975,782.54 LAT. 70°20'42.1835'' X = 509,627.77 LONG. 149°55' 18.6762" _ PAD ELEV. 68.4 O.G. ELEV. 64.1 FSL 517 FWL 1,081 WELL 3 Y = 5,975,724.43 LAT. 70o20'41.6l'22'' X = 509,613.34 LONG. 149°55' 19.0999" PAD ELEV. 68.3 O.G. ELEV. 64.0 FSL 458 FWL I ,066 WELL A Y = 5,975,666.21 LAT. 70°20'41.0397'' X = 509,599.09 LONG. !49o55' !9. 5187" PAD ELEV. 68.4 O.G. ELEV. 63.9 FSL 400 FWL 1,052 WELL 5 Y = 5,975,753.43 LAT. 70020, 41.902" X = 509,2&9.86 LONG. 149°55' 29. 720" PAD EkEV. 68.6 O.G. ELEV. FSL 488 FWL 703 WELL 6 Y = 5,975,811.41 LAT. 70°20' 42.472" · I X = 509,264. 30 LONG. 149°55' 29.296" · ~ PAD ELEV. 6~.6 O.G. ELEV. 64. · 3 FSL 546 FWL ? 18 WELL 7 Y = 5,975,869.59 LAT. ?0°20' X = 509,278.75 LONG. lg9°55' 28.57l" PAD ELEV. 68.6 O,G. ELEV. 64. 3 FS L 604 FWL 73 g WELL 8 Y = 5,975,927.80 LAT. 70°20' L~3.616" X = 509,293.26 LONG. ~l ~2 PAD ELEV. 68.5 O.G. ELEV. 64.2 FSL 662 FWL ,, LOCATED IN PROTRACTED SECTION 32------- -- --- TOWNSHIP 12 N, RANGE 9 E, UMIAT MER. ~'~..' ~ . : ~, ';,.~ ,~,' NOTE: BASIS OF BEARING IS PAD PILING CONTROL ' :a~'.,~-.% LS-650~r-'/.'~-~ N 13+55, E8+30 AND NI3+55, E 11+70 AND t"2"~'"'. / BASIS OF ELEVATION IS 2U-5AND AU-4 PER LHD 8~ ASSOCIATES. -. -...,,. LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF · .,7 ( $ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE z ARE CORRECT AS OF .'--', ARCO Aleske, Inc. ,~~6V ~":~'~ !;~ /L~N ~ kj j IBI;~'~ Kuparuk Project North Slope Dri,l;ng ! ',.- DRILL SITE 2U ]mit_.__ s o,,. ss.ow ,,,,-u~, ~ , J ,,,_~SCALE: I = Drawn By' Hz Dwg. No. NSK9.05.221dl January 16, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re:i Kuparuk River Unit 2U-3 ARCO Alaska, Inc. Permit No. 85-6 Sur. Loc. 458'FSL, 1066'FWL, Sec. 32, T12N, RgE, ~. Btmhole Loc. 1561'FNL, 1354'FWL, Sec. 5, TllS~, R9E, !~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill, the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings 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 digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their .drainage systems 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 commencing 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 regulations promulgated thereunder (Tftle 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. Mr. Jeffrey B. Kewi~ Kuparuk River Unit 2U-3 -2- January 16, 1985 To aid us in scheduling field work, please notify this office 24 hours Prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~There a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very.~rulM yoR_rs, / /'- Cha i~an o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COM3~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 8, 1985 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2U-3 Dear Mr. Chatterton' Enclosed are- o An application for Permit to Drill Kuparuk 2U-3, along a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on February 18, 1985. If you any questions, please call Sincerely, Area Drillina Engineer JBK/HRE/tw PD/L21 Attachments me at 263-4970. with have 1 4 1985 Alaska Oil & O~as Cons. Commission AnclTorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~-- ALASKA OiL AND GAS CONSERVATION COM,v,ISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE 9. Unit or lease name . Kuparuk R~ver 10. Well number 2U-~ 11. Field and pool 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 458' FSL, 1066' FWL, Sec.32, T12N, RgE, UM At top of proposed producing interval 1320' FNL, 1320' FWL, Sec. 5, T11N, RgE, UH At total depth ;~ C~~¢', 1561' FNL, 1354' FI~L,/Sec. 5, T11N, RgE, UH 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 106', PAD 69' I ADL 25644 ALK 2575 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type 5tatewide Surety and/or number #8088-26-27 Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 458' @ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures 2665 MAXIMUM HOLE ANGLE 40 o (see 2OAAC25.035(c) (2) 16. Proposed depth (MD & TVD) 6956' MD, 6264' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 31 66 feet. 21 tl 5. Distance to nearest drilling or completed U-2 well 45' ¢ 900' MD feet 18. Approximate spud date 02/18/85 psig@ 80°F Surface psig@ 5978 ft. TD (TVD) SIZE Hole Casing i24" 16" i12-1/4" 9-5/8" 18-1/2" 7" Weight 62.5# 36. O# 26.0# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH Grade CouplingI Length MD TOP TVD H-40 Wel~~ 80' 35' 135' J-55 J BTCI 2981 ' 35 ' I I 35' HF-ERW [ / ~ J-55 I BTC{6922' 34' I I 34' HF-ERW I M D BOTTOM TV D 115' 115' 3016' 13016' I j 6956' 16264' I I QUANTITY OF CEMENT (include stage data) + 200 cf Poleset 630 sx Permafrost "E" 620 sx Permafrost "C" 260 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6956'MD (6264'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3016'MD (3016'TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (3000 psi for annular). Expected maximum surface pressure is 2665 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 3-1/2", 9.2#, J-55, EUE 8rd 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 (see attached sheet) 23. I hereby cer/t,i~hat the foregoing is true and correct to the best of my knowledge // SIGNED / TITLE Area Drilling Engineer CONDITIONS OF APPROVAL Samples required []YES eNO Permit number APPROVED BY Form 10-401 (HRE) PD/PD21 Mud log required DYES Approval date _ 01116/85 Directional Survey required I APl number ~Y_ES i--INO I 50- ~t,-~ - ~.i~- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE 3anuary 16, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2U-3 installed and tested upon completion of the job. 2U-3 will be the seventh well drilled on the pad. It is ±45' away from 2U-2 at 900'MD. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 5404'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off location, the well will be fracture stimulated. Alaska Oil & Gas Cons. Anchorage ~-~. ! ................. t ........ t ...... ~ · - f ~ ....... .......................... ~ ........... j ......... i - ~ .! -- .................. . ....... ! .... J .- I j ,.~r .... ;,~_:~. :;'J;';'~ '. i ....... ~ ' ~ ....... ~-. ~ .... j ........... ~ '' '~ ~ ~' i ......... ~'L&/~~ '-LZ-';~ '~J_L__-'L: L ;~ ~'. ~ ~ J' ' ~ ' ' ..... · ............. =.=~: ..... : .-=-: TTT · . ~ ' i . · ~ ~ - . ' ~ ............ !- ~ ', ' ] ..- . . ~ . : : · : - ~a::!::.~-:~.-~:.:-.-: ::i:'.:: .':~ :: ~ - . ~.. . ~.. ~__ ~ ~0._.~0: 2.,~ -MI N- I " ' --~ ..... ~ ............ ~ - ~ ---I - ': ' , : ' : .... ~~ ~ .... ~ .... '~-~ ........ ~=--- -. ~ · ' ~ : :~ / ' ;NDS ~TV~(~44 ~=6~[04 0EP'1682' ...... } ;'' ~ r A~:;si~ u~J & Gas icons. OcmmJsslo~ J ''' - - ' ..... ~ ' ' ~ ' : Anch~rag~ , , .~ ........ ~ .......... ~ ,,, ~ '' :.- ~ - I ..... ~ .[ . ~ .~ _ . :"'~::::::---- . :.j::: :--- j .... ~ I ... , ..... '::"- ........... :'---:--: .... '::::': '" t " ' -' 'i{! i!l~ .:i : ...... - ............................................................... -~'~"!~!, !'.' ............................. ;'i ........ i Fi i-.-~ : -:--- ; . . . ....... ~ ~ , ~ , ,: · __ ; . .............................. t ...... ~ - ' - i ~ ~ : . . ...... .... ~ ....... ~ .... ~ .... ~ I~00~ ~000 _ ~ ~ ~ ~ .... ~,,, ........... ~ ........... } .... ~ .... ~ - ~ .--~ ' I i ~ ) ~ . . ~ .... / ~ ~ i [ _ . ~ i ~ ~A; I · &'l ~ ~ ~ ............. ...... ~ ....... ~ .... ~ .... ~ ...... ~ .... ~. .............. ~ i ' . _ ........ { .......... : ........ {- - ....... ~ : _.~ . , .... i ~ , - - ~ ~ ~ .... ~ ..... ~ · ~ ..--'~, '--u'~' ~ : - , ~c_. ~ ... ~ ~' ~nnn~ ,~ ~ - ~ ' ~ ', ~ : : ~ ' - .... I : ......... : ~ i ...... } - . · . ] ' ......... ~ . .. ~ ~ ~ ~ : · ~ ; . ...... ~ ~+ : : ........ ! ................................................................. t .................... ~ : [ ~ ~ 1796' ' ~ , ~ D ~r-. ' · ~ ~ ~ ._ ~ ......... :._. :;a_~,~_1 ~..L~ ....... ~ .............. ' Alaska Oil & ,4 , , i , , ,i, ! ~ ' ' I000 I 1 O0 1200 ~1300 1400 1 500 600 I 1'800 ' '! 90 i . ~ ~ ? ..... , , ; .... ~ ...... , . . , , : .. , ; , ~ + , , ~ ........ ,AD.2:J~.WEi.L; 1-2.,3-4 PROP[S ~ ~: ....... ~..,. . : ..~.''' ~UPAR:J~ FII~LD,.IIORTH SLOPE", 'ALtSK~ } .: ~"' I { 4 } ..... , i , . ~ ~ , . ~ ~ , ....... ' ............. . , . ,, , : ,, ~ -~ ~ ; ~ , , , ........... '~4~'~,,, ' " ',' i ~{ ~ ) .... ~ ....... ;" ~ ...... ~ ..... -..~.-.i ........... ~ .... ~ ................................... ' ...... % : .... ; .... ; ' ....... ...... '..,;~L.~:'~.:'..;.'.L.'.. , :~ - ~ ; '. ,, . ' , i ' , ~ I .... ~~' ' ~1~' ' ~~' ; : ~iti 'i '.,:~ ,' ~ ,' ~..: ,'; ~' ' ' ' ' 'h' ' '.,,' ' ..... : ' ' N's~ . ' '' , ,.+;,,~'~ i . ' ' ~ ~ , , ::,'~:, ': ~ ;,,:, t 7 6 3 2 7. !3"5/8" ~ STACK T~$T FILL ~ S~',~4CX ~ C~ )~N~'iFO. D DIE~L. F~LY ~~. ~T TEST ~T~ ~I,~ JT ~ ~ IN ~ ~ ~~ ~ ~D ~~ TO 0 ~I. ~N ~TT~ ~I~ ~ ~ ~I. ~ ~I. GaS CONS, Anchorage ~i~¥ : i I Surface Dive~ter S~vstem 16"-2000 psi Tankco startincj heaO. Tenkco ~uicZ connect assy. I$" X 20" 2000 psi double s~udoe~ ac:apter. 20" 2000 psi drilling sI3OO~ ,v/lC" sloe outlets. 10" bell valves, hyc)raulically actuated, w/10" lines to reserve pit. Valves to open automatically ul~on closure of annular preventer. 20" 2000 ~si annular ~reventer. 20" Dell nipple. Maintenance i. Upon initial installation close ~nnu!ar ~reventer ~ne verify that ~ail valves qeve oDenec ~roOer!¥. 2. Close annular ~reve~ter an~ ~io~ air t~rou~ civerter lines every ~2 hours. Close annular preventer in the event t~at ~as or f~ui¢ flow to surface is 0etecte¢. :~ necessary, manuaiiv overrioe eno close Deli valve to ~owinC civerter line. Do not shut in well uncer amy c~-cumstances. Conclucter Alaska OJj& Gas Cons. Commission Anchorag~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ,~-~,. ~ thru (8) ' '" (3) Admin (<~£.~~ !-.. ,,I ":.?'? ,., ~i~,~/ (10 and (4) Cass 'i,"',:, ,' (I3 thru ~1) 1. IS 2. Is 3. Is 4. Is 5. Is 6. Is well to be deviated and is wellbore plat included ............ 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait ................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Company ..~ Lease & Well No. YES NO the permit fee attached ......................................... well to be located in a defined pool ............................. ~_, , well located proper distance from property line . . . well located proper distance from other wells .......... sufficient undedicated acreage available in this ~ool e · °°° Does operator have a bond in force ................ ~ ................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate eleeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee~..f~'" 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 wellbore separation proposed eeeeeeeleeeleeeeeeeeeeeeeeee ,,,,j (5) BOPE '" .... ' ...... (22 thru 26) (6) Add: -,-- 22. 23. 24. 25. 26. 27. REMARKS Is a diverter system required ..... ~ ............................. Are necessary diagrams of diverter and BOP equipment'attachgd ....... Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ ~ ~,r f~-~'IuD ~'~'-, A~,.'~i~i ~E ~ ,~,?~,,+~;,,: Geology:., ~ngineerin~: HWK ~ LCS ',, ,,~.' BEW ~ WVA ~K~~/HJHJAL -- rev: 10/29/84 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA NO. SHORE / o / Well Histo.ry File APPENDIX Information of detailed nature that is not particularly 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. LVP ~io. H02 VEPlV',[C'A'~iON LTS'rIUG PAGE I SERVIC;~ ~,~A M E :EDIT DATE ORIGIN :0000 TAPE N a ~!q ~ :0097 CONTIN~ATIr~N .~ :01 PRMVT[)~ T A DF', ** INFDR~AmI,r..)N R~CORD5 ** UNIT TYPE CATE SIZE CODE CN : laCO ALASKA INC 000 000 01.6 065 WN ~ ~l.J-3 000 000 006 065 WN ~ ~I]PA~UK 000 000 008 065 ~A~'G~ ~!~ 0o0 000 002 065 TOWN: 12~! 000 000 004 065 SECT: ~2 0~0 000 002 065 CO~IN! N,SLOP~ 000 000 012 065 STn'r: ~LIS~A OOO 000 006 065 CT~Y: ~$~ 0~0 000 003 065 ************************************************************************************ * SC ttLUMi~FRGE~ LVD Oln ,~(,)2 VE~IFICATI~.I~ LTSTI.tG PAGE 2 , ~IFLn = KT,~PARTTK MT~TR = AT~ASKn DE;NSTTY VISCOSITY 3,460 La 63.0 PF ~ DF' 3,100 {4 63, 2.060 {a 63, 1,670 0 118.0 r)~TJJur SPECTF'!ChTT(]~{ ~I, DCgS MNE.~k SFRV..[CE SF, Rt/'I(TE {!NTT A~I bPI ~Pi ,~PT ~[L,E SIZF: 5PI, REPR ,in O~?DFR ~ hnG TYPE CT. 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