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Home My WebLink About183-113MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2X-07 KUPARUK RIV UNIT 2X-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 2X-07 50-029-20991-00-00 183-113-0 W SPT 5671 1831130 1500 2810 2810 2810 2810 540 660 660 660 4YRTST P Brian Bixby 6/3/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2X-07 Inspection Date: Tubing OA Packer Depth 800 1800 1740 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607074116 BBL Pumped:1.4 BBL Returned:1 Wednesday, July 26, 2023 Page 1 of 1          MEMORANDUM TO: Jim Regg P.N V14 I. supervisor o FROM: . Jeff Jones Petroleum Inspector Well Name KUPARUK RIV UNIT 2X-07 Insp Num: tuitJJ190725103247 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 25, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2X-07 KUPARUK RIV UNIT 2X-07 Ste: Inspector Reviewed B�y{:/�;� P.I. Supry NON -CONFIDENTIAL Comm API Well Number 50-029-20991-00-00 Inspector Name: Jeff Jones Permit Number: 183-113-0 Inspection Date: 6/22019 Packer Depth Well 2X-07 ]Type Inj W ;TVD_ r 5671 PTD 1831130 Type Test' SPT iTest psi 1500 BBL Pumped. 2 BBL Returned: 1.5 Interval — avRTST jP/F P Notes: I well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min 45 Min 60 Min z7ao 2740 o _ 1680 0 2000 1910 1890 L OA isazo Thursday, July 25, 2019 Pa -C I of I STATE OF ALASKA • • ALA.OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug 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 r Re-enter Susp Well r Other: Tubing Patch r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Explorator r 183-113 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic j Service r' 50-029-20991-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25645 _ KRU 2X-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7435 feet Plugs(measured) None true vertical 6292 feet Junk(measured) 7128 Effective Depth measured 7330 feet Packer(measured) 6718, 7002 true vertical 6203 feet (true vertical) 5665, 5920 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 109 109 SURFACE 3176 9 5/8 3207 2857 PRODUCTION 7383 7 7413 6273 RECEIVED Perforation depth: Measured depth: 6872-6951, 7083-7093, 7105-7135 MAR 1 7 2017 True Vertical Depth: 5804-5875, 5992-6001,6011-6037 '` AOGCG Tubing(size,grade,MD,and ND) 3.5, J-55, 7024 MD, 5940 TVD Packers&SSSV(type,MD,and ND) PACKER-CAMCO HRP-1-SP RETRIEVABLE PACKER @ 6718 MD and 5665 TVD PACKER-BAKER FB-1 PERMANENT PACKER @ 7002 MD and 5920 TVD SSSV-Camco TRDP-1A Safety Valve @ 1873 MD and 1829 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED /ED -'R I F Hi?, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development r Service 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: 317-007 _ Contact Steve Drake 263-4062 Email Steve.G.Drake@conocophillips.com Printed Name Steve Drake Title Sr. Wells Engineer Signature _GLPhone:263-4062 Date / /4/ / 7_ ." VTC 3/7 //7 RBDMS I/1/Form 10-404 Revised 5/2015 3 /°� ` 2 1017 '4' Submit Original Only • • 2X-07 DTTMSTART JOBTYP SUMMARYOPS 1/3/17 TUBING/ DRIFT W/25'X 2.72" DMY PATCH DOWN TO 7015' RKB. READY FOR CTU. CASING PATCH 1/30/17 TUBING/ PUMPED 40 BBLS OF DIESEL DOWN THE FLOWLINE AND TUBING FOR FREEZE CASING PROTECT. JOB COMPLETE. PATCH 2/1/17 TUBING/ PERFORMED FCO WITH SLICK DIESEL AND DIESEL GEL SWEEPS FROM 6493' CASING CTMD TO LOCKOUT AT 7244.6' CTMD, MAINTAINED 1:1 RETURNS THROUGHOUT PATCH CLEANOUT, F/P WITH DIESEL. READY FOR RELAY. 2/5/17 TUBING/ TAG @ 7197' SLM ( EST. 97' OF RAT HOLE) BRUSH N' FLUSH TBG DOWN TO D-NIP CASING @ 7015' RKB FOCUSING ON PATCH SET AREAS. GAUGED TBG TO 2.77" TO 7015' PATCH RKB. SET LOWER 2.72" PIIP PACKER @ 6960' RKB. IN PROGRESS. 2/6/17 TUBING/ PULLED 2.72" PIIP PACKER @ 6960' RKB. ATTEMPT TO DRIFT TBG WITH 40' x 2.73" CASING DMY PERM PATCH & SETTING TOOL &30' DMY PERM PATCH &SETTING TOOL; PATCH UNABLE TO PASS 4930' SLM. IN PROGRESS. 2/7/17 TUBING/ SET LOWER 2.72" PIIP PACKER MID ELEMENT @ 6959' RKB. SET UPPER 2.72" PIIP CASING PACKER, SPACER PIPE & LATCH SEAL @ 6934' RKB (29' OAL) SET LOWER 2.72" PATCH PIIP PACKER MID ELEMENT @ 6860' RKB. IN PROGRESS. 2/8/17 TUBING/ SET MIDDLE PATCH UPPER ASSEMBLY. LATCH 18.5' MID-ELEMENT TO MID- CASING ELEMENT PATCH INTO PACKER AT 6860'. SET WITH PARAGON II PACKER. SHUT PATCH DOWN FOR WEATHER. 2/17/17 TUBING/ SET 2.72" PIIP PACKER (#CPP35111) MID ELEMENT @ 6795' RKB. CORRELATED TO CASING INJ PROFILE DATED 30-SEP-2013. SET 2.72" PIIP PACKER (#CPP35107), SPACER PATCH PIPE, LATCH SEAL ASSY(#CPAL35055) MID ELEMENT @ 6777' RKB. JOB COMPLETE. 2/22/17 TUBING/ DRIFTED TBG & PATCHES WITH 5'x 1.5" D.D BLR WITHOUT ISSUE. TAGGED @ CASING 7201' SLM ( EST 105' RATHOLE ) READY FOR E/L. PATCH 3/1/17 TUBING/ RIH W/HEAD/4 X EQF-44/1-3/8" LEE PRODUCTION TOOLS W/ FBS. OAL = 37', OAW CASING = 180 LBS, MAX TOOL OD = 1.41 (FBS), CORRELATED TO TUBING TALLY DATED PATCH 1/12/87, WELL INJECTING AT 1400 BWPD, PERFORM UP/DN PASSES AT 40/80/120 FPM OVER INTERVAL 6550-7050FT, PERFORM STATION STOPS AT 6600, 6745, 6815, 6985 FT RKB. NO LEAKS DETECTED IN PATCHES. JOB COMPLETE KUP I 2X-07 • ( � i } e3 Well Attribute () Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status Incl(3 MD(ftKB) Act Btm(ftKB) COooCOPhMips. 500292099100 KUPARUK RIVER UNIT INJ 44.33 3,325.00 7,435.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2X-07,3/16/2017921:06 AM SSSV:TRDP Last WO: 1/12/1987 33.99 8/13/1983 VmOcalsphemax(actual) Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date Last Tag:SLM 7,201.0 2/22/2017 Rev Reason:TAG,GLV C/O 8 SET PATCHS pproven 3/14/2017 HANGER:28.8 I. Zrni , _ -Casing Sings l I Casing Description OD ID ) Top(ftKB) Set Depth(MB) Set Depth D)...Wt/Len(I...Grade Top Thread -t! 9 P (in) (in P (N CONDUCTOR 16 15.250 31.0 109.0 109.0 65.00 H-40 WELDED Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 J-55 BTC »»„,,,,,,,.,,„.,,,,,e.,.,,,,,„„'»,,,, ( 8.835 1 ., Y .�tl Description OD(in)5/8 ID(in) Top(ftKBO 9 Set Depth(ftKB)7 Set Depth(TVD)... 40.00 Wt/Len n(II.PRODUCTION 7 6.276 29.5 7,412.5 6,272.7 26.00(I_'Grade Top Thread ` J-55 BTC TubingStrings g Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection -A-ti CONDUCTOR;31.0-109.0- - TUBING WO 31/2 2.992 26.8 7,024.1 5,940.1 9.30 J-55 EUE8rdABMOD ' Completion Details SAFETY VLV;1,873.1 ?f':.. � Nominal ID Top(ftKB) Top(ND)(ftKB) Top!noir), Item Des Corn (in) 26.8 26.8 0.00 HANGER FMC TUBING HANGER 3.500 1,873.1 1,829.1 28.38SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 6,695.3 5,644.4 25.02 PBR CAMCO OEJ PBR 2.937 6,717.9 5,665.0 25.12 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 SURFACE;30.93,208.7 6.856.5 5,790.7 25.59 BLAST JTS -AVA STEEL BLAST JOINTS(3) 3.000 7,000.5 5,9192 27.59 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;8,652.7 7,001.5 5,920.1 27.61 PACKER BAKER FB-1 PERMANENT PACKER 4.000 7,015.8 5,932.8 27.88 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,023.3 5,939.4 7 28.02 SOS CAMCO SHEAR OUT SUB,ELMD TTL @ 7028'ON 2.992 SWS(PROF 5/18/07 PBR;6,895.3 C Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl PACKER 6,717.9 ,, Top(ftKB) (ftKB) 1') Des Com Run Date ID(In) 6,777.0 5,718.5 24.91 PATCH- 2.72"PIIP(#CPP35107),SPACER PIPE,LATCH 2/17/2017 1.610 Upper SEAL ASSY(#CPAL35055/1.61"ID/19.41'OAL/ INJECTION;8,754.5 <-= ZERO @ BTM) 6,795.0 5,734.8 24.84 PATCH- 2.72"PIIP(#CPP35111/1.62"ID/4.01'OAL) 2/17/2017 1.620 Lower PATCH-Upper,6,777.0 6,842.0 5,777.4 25.39 PATCH- 2.72"PIIP PACKER(CPP35068)14.25'SPACER 2/8/2017 1.610 ii ii Upper PIPE 8 LATCH SEAL(CPAL35060)PATCH(19.16' oal/1.61 MIN ID) PATCH-Lower;6,795.0 6,860.0 5,793.6 25.63 PATCH- 2.72"PIIP PACKER(CPP35112/MIN ID 1.62"/ 2/7/2017 1.620 Lower 4.01 OAL) 6,930.5 5,856.9 26.60 PATCH- UPPER 2.72"PIIP PACKER(CPP35052)21' 2/7/2017 1.620 INJECTION;6,8200 - Upper SPACER PIPE&LATCH SEAL ASSEMBLY (SN:CPAL35057)OAL=28.88'/MIN ID 1.62" 6,959.0 5,882.4 27.00 PATCH- LOWER 2.72"PIIP PACKER(SN:CPP35100/ 2/7/2017 1.620 Lower 1.62"MIN ID/4.01"OAL) PATCH-Upper;6,842.0 .. 7.128.0 6,031.0 29.96 FISH Wobble Washer from DV Lost in Hole 2/28/1992 i' I!' Perforations&Slots snoI PATCH-Loweh 8,860.0 (PERF;8,872.0-8,951.0 I DS Top(ND( Btm(ND) (56004 Top(fBB) 8617(RBB) (IBB) (ftKB) Zone Date ft) Type Com 6,872.0 6,951.0 5,804.4 5,875.2 C-4,UNIT B, 9/10/1983 4.0 IPERF DA Kone Gun 2X-07 7,083.0 7,093.0 5,991.8 6,000.6 A-4,2X-07 12/14/1983 4.0 APERF DA Bar Kone II PATCH-Upper;6,930.5 7,105.0 7,135.0 6,011.0 6,037.0 A-3,2X-07 12/14/1983 ' 4.0 APERF DA Bar Kone II Mandrel Inserts PATCH-Lower;6,959.0 t I'1 St I II ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn INJECTION;6,983.4 - 1 6,652.7 5,605.8 OTIS LBX 1 1/2 GAS LIFT DMY RO-5 0.000 0.0 1/15/1987 2 6,754.5 5,698.1 CAMCO WFG 1 INJ WF RK 0.000 0.0 4/20/2000 MI 9/16 BLAN SEAL ASSY;7,000.5 K SLV 3 6,820.0 5,757.5-CAMCO WFG 11/2 INJ WFIV RK 0.000 0.0 1/1/2017 PACKER;7,001.5 4 6,963.4 5,886.2'CAMCO WFG 1 INJ WF broken 0.000 0.0 11/16/1991 ill 9/16 BLAN K SLV NIPPLE;7,015.8 Notes:General&Safety11 End Date Annotation - 2129/1992 NOTE:Blanking Sleeve GLV#4 has parted RKP Latch. Unable to remove from pocket. 605;7,023.3 4/21/2000 NOTE:Tubing Pressure tested to 3000 psi-GOOD 12/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;7,083.0-7,093.0-. 12/12/2013 NOTE: Mandrel Orientation: 1)2:00 2)8:30 3)4:00 4)12:00 APERF;7,105.0-7,135.0 FISH;7,128.0 ...- ....- PRODUCTION; PRODUCTION;29.5-7,412.5- - M • 60 Y3 W�W V r r �"> _X > N 5.° i �Nz � � � oy 3 a gm � � T h • Y C `' O v C a) 0M _ crrr M m • U En v �= . . u a a c C ) T O @ N W O _° a m C a, T Q Q v C o s m J G Q l9 r n ,n Y a.) u �0 N 7) tIl LL LL O L n3 W C 0ro U - a, ZQ N 00 "O f0 p 4-' Z Q 0 a ic U a, CC C 'a) O C H aJ J J °° c U 42 W w W v+ a) 'C i- v o L L Li Q � > 4 a-)Q a J J J N 0 c tt Z C) < Z Z z u t a, o a, •• CD LL LL fL > To + > C a)gi }' - O Q N V a) _IV V > • � ,n Q Z C 14-.0- f0 ,., U w 0 co vO Y u 1 c G <2 t a. a) n3 a 0 _ C' Q C a, Q 0 C a Lu LL 0 0 a' 0 m cy 9) U .5 z . N 00 to > I t� o 4) r. , � � CZ 1 120 49" z x ld O w 0 R{ «• m c) j a J J J cc Fe" \ • 3 a, V U/ w w LJJ > > > u Z Y Y Y p --..''..V.P.-914P li i I w c4 ce 0 > > 0 +� w_ Q Q Q ` T LL > > > ra 0 X 7) ra ■ W A- � CI N 1 E R lWq ' + �. O O VO r. O O O QJ CV O > ,v O N 2 la ..� W; 0 0 0ro c v Ce ig �I ` O u • N LU ! < O O C Cr V co r r- r) rn o N N N NL Q M O a) 0, c ER O N N i 01 O O O O 4-' 0 a, C0. as w L m aa, ER u C. W Y — C C cia_0 3 d N u — M e Z t, pa ri •o Cl 0 S a ��j•• pC N E 1 2 > X E F- ri m� d Q O N M N N Z a1 co N N Y 40 v ,'ir u cco c aa)i CCD 0 CA $ Q .. All H a a ‘I-TC • ��?\\v/7,tee THE STATE Alaska it and Gas .b "Z�d��•'-9A OfLAS :A Conservation Commission .- - 333 West Seventh Avenue -'' ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .°� Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Steve Drake Senior Wells Engineer SCANNED MAR 3 0 2017. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2X-07 Permit to Drill Number: 183-113 Sundry Number: 317-007 Dear Mr. Drake: 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, P-S7,41v, Cathy P. Foerster �,/.�. Chair DATED this in day of January,2017. RBDMS J—JAN 2 6 2617 r 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 10 2017 APPLICATION FOR SUNDRY APPROVALS AOGCCor-s II nth?7 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations E Fracture Stimulate r Repair Well E Operations Shutdown E Suspend E Perforate E Other Stimulate 1 Pull Tubing E Change Approved Program E Plug for Redrill E Perforate New Pool I- Re-enter Susp Well 1- Alter Casing E Other: Tubing Patch F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory f Development E 183-113 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic E Service , 50-029-20991-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? none Will planned perforations require a spacing exception? Yes i No I i KRU 2X-07, 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25645 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,435'' 6,292', ' 7330 • 6203 2575 none 7128 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 109' 109' Surface 3,176' 95/8" 3,207' 2,857' Production 7,383' 7" 7,413' 6,273' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6872-6951,7083-7093, 5804-5875,5992-6001,6011- 3.500" J-55 7,024' 7105-7135 ' 6037 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 016 PACKER-CAMCO HRP-1-SP RETRIEVABLE PACKER ' MD=6718 TVD=5665 55S-Si/ /V3 PACKER-BAKER FB-1 PERMANENT PACKER ' MD=7002 TVD=5920 12.Attachments: Proposal Summary 2 Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory E Stratigraphic E Development E Service F. 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: N/A OIL E WINJ F , WDSPL E Suspended E 16.Verbal Approval: Date: GAS 1 WAG E GSTOR E SPLUG E Commission Representative: GINJ fl Op Shutdown E Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Steve Drake@263-4062 Email Steve.G.Draker7a.cop.com Printed Name Steve rake Title Sr.Wells Engineer Signature -au_ ��Phone 263-4062 // '9/ /Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -7 - 001 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No }Kr------ Spacing 'JSpacing Exception Required? Yes ❑ Nod Subsequent Form Required: / e — 'J b L� // RBDMS (AAA1l2 6 2017 APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: (/1.'/7 � ' l'l4,47 � n—I 113 tIGINAL Submit Form and 10 3 Revised 11/2015 valid for 12 months from the date of approval. Attachments in Duplicate ate: • • • 2X-07 Multi Patch Well Work Justification&Objectives: Multiple diagnostic runs have been performed to better help A-sand support in this injector. An (PROF run on 9/30/13 identified two leak points in the tubing at 6853' RKB and 6788' RKB. A micro-vertilog was run on 11/15/14 and identified two areas of substantial metal loss on the backside. The first at a depth of 6940-6946 with a calculated metal loss of 57%and the second at a depth of 6952- 6983'with a calculated metal loss of 42.4%. This procedure will outline the steps to set two patches over the upper known leaks as identified by the leak detect log and proactively patch the area of concern that was identified by the micro-vertilog. Risk/Job Concerns: Min ID above work-2.812 Camco TRDP-1A Safety Valve Moderate corkscrewed tubing identified from 2013 gyro survey. 8/12/15-Successfully drifted with 23'x 2.75" dummy patch to 7016 with no problems. 7/11/16-Successfully drifted with 2.78"WRP drift to 6800' RKB. Unable to drift past 6640'with 2.77" full bore @ 186" OAL. Steps: CTU 1. MIRU 2" CTU and related support equipment 2. RIH with nozzle clean out assembly to top of fish at 7128'or as deep as possible, attempting to uncover as much of the A-sand perfs as possible. 3. FP well and turn over to SL. Slickline/Eline or Digital Slickline 1. MIRU SL unit and related support equipment. 2. Brush tubing from surface down to, and including, nipple at 7015' RKB. This will ensure the patch setting areas are clear of debris as well as minimize the probability of the packers becoming caked with scale/debris while RIH. Obtain updated tag. 3. Set CSV on nipple @ 7015' RKB. 4. RIH and pull GLV at 6820' RKB. 5. Set DMY in GLM at 6820' RKB. 6. Pull CSV. 7. RIH with drift for 2.72" PIIP packer past planned set depth of 6960' RKB. (Drift size: 2.72" OD x 5.08' OAL) 8. RIH with drift for 20' of 2 1/16" spacer pipe with 2.75" PIIP on top. (Drift size: 2.72" x 24.58' OAL) 9. Lower Patch-Set lower PIIP packer 6960' RKB(just above GLM at 6963' RKB) • • 10. Lower Patch-Stab into lower packer at 6960' RKB with 20' spacer pipe, placing upper PIIP at 6935' (25' element to element). 11. Middle Patch- Set lower PIIP @ 6860' RKB. 12. Middle Patch-Stab into lower PIIP @ 6860' RKB with 13' spacer pipe (19.91' OAL), placing upper PIIP at 6842' RKB (18'element to element). 13. Upper Patch-Set lower PIIP @ 6795' RKB. 14. Upper Patch-Stab into lower PIIP @ 6795' RKB with 13' spacer piper(19.91'OAL), placing upper PIIP at 6777' RKB (18' element to element). 15. Rig down and turn well over to DSO to return to injection. ELINE/DSL 1. MIRU unit and related support equipment. 2. RIH with slim tools (MIN ID on patch is 1.61")with well on injection to perform LDL over installed patches (RIH below 6962'). 3. Note any anomalies or leaks. 4. RDMO leaving well on injection. KUP I 2X-07 Cono Phi lips a Well Attribut Max Angle TD r Alaska,inn. : Wellbore API/UWI Field Name Wellbore Status not(°) MD(kKB) Act Btm(ftKB) Corwcophitlips`y 500292099100 KUPARUK RIVER UNIT INJ 44.33 3,325.00 7,435.0 .°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-07,1/5120176:4x.53 AM -SSSV:TRDP Last WO: 1/12/1987 33.99 8/13/1983 Ver9cal schemano(aaua0 Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date Last Tag:SLM 7,097.0 7/9/2015 Rev Reason:TAG,GLV C/O lehallf 7/23/2015 HANGER;26.8 j ( Casing Strings -I4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread , CONDUCTOR 16 15.250 31.0 109.0 109.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 30.9 3,206.7 2,857.2 40.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.5 7,412.5 6,272.7 26.00 J-55 BTC l Tubing Strings "moi""11 n,,,.i��"`.","".,n„,i" ' '"Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection .1 J. TUBING WO 31/2 2.992 26.8 7,024.1 5,940.1 9.30 J-55 EUE8rdABMOD Completion Details Nominal ID -^-ti CONDUCTOR;3t.0-109.0- Top(kKB) Top(IVO)(ftKB) Top Incl(°) Item Des Com (in) 26.8 26.8 0.00 HANGER FMC TUBING HANGER 3.500 SAFETYVLV;1,873.1 f1 "'i°'i 1,873.1 1,829.1 28.38 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 �"I 6,695.3 5,644.4 25.02 PBR CAMCO OEJ PBR 2.937 6,717.9 5,665.0 25.12 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,856.8 5,790.7 25.59 BLAST JTS AVA STEEL BLAST JOINTS(3) 3.000 7,000.5 5,919.2 27.59 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 7,001.5 5,920.1 27.61 PACKER BAKER FB-1 PERMANENT PACKER 4.000 7,015.8 5,932.8 27.88 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE;30.83,206.7 7,023.3 5,939.4 28.02 SOS CAMCO SHEAR OUT SUB,ELMD TTL @ 7028'ON 2.992 -� SWS!PROF 5/18/07 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT,6,652 TopkKB � ( ) (kKB) (°) Des Com Run Date ID(in) 7,128.0. 6,031.0 29.96 FISH Wobble Washer from DV Lost in Hole 2/28/1992 Perforations&Slots Shot Dens PER,6,695.3 ll I Top(TVD) Btm(TVD) (shots / Top ) o( ) (ftKB) Zone Date ft) Type Com PACKER;s,71z9 6,872.0 6,951.0 5,804.4 5,875.2 C-4,UNIT B, 9/10/1983 4.0 IPERF DA Kone Gun r�r 2X-07 7,083.0 7,093.0 5,991.8 6,000.6 A-4,2X-07 12/14/1983 4.0 APERF DA Bar Kone II INJECTION;6,754.5 7,105.0 7,135.0 6,011.0 6,037.0 A-3,2X-07 12/14/1983 4.0 APERF DA Bar Kone II t_ Mandrel Inserts St INJECTION',66(200 (_: ad on N Top(TVD) Valve Latch Port Size TRO Run Top 19661 (kKB) Make Mod el OD(in) Sery Type Type (in) (psi) Run Date Com 1 6,652.7 5,605.8 OTIS LBX 1 1/2 GAS LIFT DMY RO-5 0.000 0.0 1/15/1987 2 6,754.5 5,698.1 CAMCO WFG 1 INJ WF RK 0.000 0.0 4/20/2000 9/16 BLAN K SLV (PERF;6,872.0ss51.0-'I I 3 6.820.0 5,757.5 CAMCO WFG 1 INJ WFIV RKP 0.313 0.0 7/11/2015 water 9/16 flood inj vlv , it 4 4,963.4 5,886.2 CAMCO WFG 1 INJ WF broken 0.000 0.0 11/16/1991 9/16 BLAN K SLV INJECTION;8,983.4 Notes:General&Safety End Date Annotation 2/29/1992 NOTE:Blanking Sleeve GLV#4 has parted RKP Latch. Unable to remove from pocket. I. 4/21/2000 NOTE:Tubing Pressure tested to 3000 psi-GOOD SEAL ASSY;7,000.5 12/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 i. .i, 12/12/2013 NOTE:Mandrel Orientation: 1)2:00 2)8:30 3)4:00 4)12:00 PACKER;7,001.5 11 • i NIPPLE;7,015.8 SOS',7023.3 APERF;7,083.07,083 0I APERF;7,105.07,135.0 FISH;7,128.0 ..--. PRODUCTION;29.5-7,412.5--- MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 16,2015 TO: Jim Regg P.I.Supervisor cl �(17IIc SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2X-07 FROM: Johnnie Hill KUPARUK RIV UNIT 2X-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,W— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2X-07 API Well Number 50-029-20991-00-00 Inspector Name: Johnnie Hill Permit Number: 183-113-0 Inspection Date: 6/10/2015 Insp Num: mitJWH150612060808 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2X-07 Type Inj W 'TVD 5671 ' Tubing woo moo - imoo - woo - PTD 183113° " Type Test SPT Test psi 1500 IA 570 1790 - 1730 • 1715 Interval 4YRTST P/F P ✓ OA 340 480 - 480 - 480 Notes: 2.7bbls diesel SCANNED JUL 1 32,0ii Tuesday,June 16,2015 Page 1 of 1 Ima~Project Well History. File' e 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 Organizing (done) Tw' 0-Sided IIIII II IIIIIIIII [] RescanNeeded IIIIIIIIIIIIIIIIIII RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: .~ .... OVERSIZED (Non-Scannable) [] Other: , . :, NOTES: [] : Logs of various kir~ds r' Other BY: .~~REN VINCENT SHERYL MARIA LOWELl. DATE: ~"'~/ Is~ Project Proofing BY: BEVERLY BREN VINCENT(~MARIA LOWELl. DATE:~'6 Scanning Preparation 7 X 30 :~'P~/~ + / BY: BEVERLY BRE~N~SHERYL MARIA LOWELL DATE:~ / Production Scanning IS~ BY:f -- ~BREN VINCENT SHERYL MARIA LOWELL DATE://(:~/S/~~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned (individual page [special attention] scanning completed) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3 NOTScanned.wPd • s ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 30, 2011 R ., � : , a JUL 0 8 all Commissioner Dan Seamount Alaska Oil and Gas Commission i e 'm. .;�ej. "rt�3Siofi 333 West 7 Avenue, Suite 100 3 ' Anchorage, AK 99501 6 Commissioner Dan Seamount: Enclosed please fmd 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 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 on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lo land 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 6130/11 2F,2M,2N,2T,2X,2Z,3B,30 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # _ cement pumped cement date inhibitor sealant date _ ft bbls ft _ gal 2F -19 50029227280000 1962010 8" N/A 23" N/A 13 6/25/2011 2M -09A 50103201770100 1960900 SF N/A 18" N/A 3.5 6/26/2011 2M -14 50103201730000 1920630 SF N/A 19" N/A 3.5 6/26/2011 2M -17 50103201500000 1910180 SF N/A 19" _ N/A 3.5 6/26/2011 2M -26 50103201720000 1920550 SF N/A 21" N/A 3.5 6/26/2011 2N -316 50103203420000 2000900 SF N/A 18" N/A 4 6/27/2011 2N -318A 50103203430100 2090220 10" N/A 27" _ N/A _ 7 6/27/2011 2T -40 50103205280000 2060400 2' N/A 2' N/A 6 6/26/2011 2T -202 50103202540000 1980370 6" N/A 20" N/A 9 6/26/2011 2X -07 50029209910000 1831130 SF N/A 21" - N/A 2 _ 6/25/2011 r .—> 2X -08 50029209920000 1831140 SF N/A 21" N/A 2.5 6/25/2011 2Z -02 50029209600000 _ 1830800 _ 18" N/A 18" _ N/A 2.6 6/24/2011 3B -01 50029213180000 1850560 SF 1.50 17" _ 5/23/2011 _ 6 6/22/2011 30 -12 50029218040000 _ 1880410 SF N/A 22" _ N/A _ 1.7 6/22/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: P.I. Supervisor DATE: Wednesday, June 29, 2011 Jim Rp Pli `7('l l (II SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2X -07 FROM: Jeff Jones KUPARUK RIV UNIT 2X -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J6`"" NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2X - 07 API Well Number: 50 029 - 20991 - 00 - 00 Inspector Name: JeffJones Insp Num: mitJJ110627170736 Permit Number: 183 - 113 - Inspection Date: 6/26/2011 Rel Insp Num: . Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2X -07 Type Inj. N TVD 5671 IA 860 1700 ' 1620 1620 - P.T.D 1831130 'TypeTest 1 SPT Test psi 1500 ' OA 260 — 260 260 260 Interval 4YRTST PIFi P # Tubing 860 870 870 870 Notes: Pad is shut in for water line replacement. 1.1 BBLS diesel pumped. 1 well inspected; 3 exceptions noted. The SVS control panel is leaking hydraulic fluid and the balnce stems are leaking on the master and swab valves. Mr. Colee to initiate repairs. ~:; 41 t(1 "4t4,0) tiL;,v. f' ... , Wednesday, June 29, 2011 Page I of 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • <~:~ , _ , 183-113 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 pum~ed August 20`" -Sept 11th, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13 ,2008. 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. ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Ila+ra Kuparuk Field 9/14/2008 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 1 C-178 203-041 8' 1.50 8" 9/11 /2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11/2008 1Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9/12/2008 1Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12!2008 1 Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13!2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9!13/2008 2X-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 - .~~, ~~_ . ~~' ... ~^ ?iil~~ 06/08/07 Schlumbepgep NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 'iI ':1007 )I..t ¡ ..... JUN 1 4: LOû7 r\ß§ffr~¡~ Oil R1 ()1)[, Gfjn~,. CmTílmis~i¡CA.NNe.D Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~\Y Field: Kuparuk o:rc.- t~ -113 Well Color CD Job # Log Description Date BL 2L-321 11629010 MULTI-FINGER CASING INSPECTION i'J5/12/07 1 2C-16 11629008 PPROFILDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1 C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RSTI WFL 05104/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT 05/25/07 1 2V-08A 11629013 PM IT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1 H-07 11665436 SBHP SURVEY 05/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE 05/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y-11 11632708 INJECTION PROFILE 05/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE 05/29/07 1 1 F-08 11665435 SBHP SURVEY 05/20/07 1 1J-170 11632709 INJECTION PROFILE 05/24/07 1 10-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY 05/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 'MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ki'11 "'/7/°7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2X-07 KUPARUK RIV UNIT 2X-07 Src: Inspector "'l'" \ \ ~ \C60 FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 2X-07 API Well Number: 50-029-20991-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS07060 I 180000 Permit Number: I83-1I3-0 Inspection Date: 6/I/2007 (../ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2X-07 Type Inj. I w TVD 5672 I IA 780 2100 2060 2060 P.T.D 1831130 TypeTest I SPT Test psi 1500 lOA 300 400 400 400 Interval 4YRTST P/F P ,/ Tubing 900 900 900 900 Notes: Pretest pressures were observed and found stable, Well demonstrated good mechanical integrity, /' NON-CONFIDENTIAL Reviewed B):.'. P.I. Suprv~ )f3~ Comm ScANNED JUN2 1 2007 Wednesday, June 06, 2007 Page I of I Schlumbel'gep NO. 3456 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/24/05 t @:2F-~t3 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 :SÇl\NNE[' SEP 0 ? 2005 Field: Well Job# Log Description Date BL 1 E-18 J/») j ··c ì l, 11015713 LEAK DETECTION LOG 08/06/05 1 1 F-01 J -9)... -.1 j 9 11047354 PRODUCTION PROFILE W/DEFT 07/31/05 1 1Y-06A 19T-1 J 'i 11015712 PRODUCTION PROFILE W/DEFT 08/05/05 1 3J-06 iSS" -)... Y 11056679 PRODUCTION PROFILE W/DEFT 08/19/05 1 1Y-31 i tl3 - Of'll:;, 11015708 PRODUCTION PROFILE W/DEFT 08/03/05 1 1 B-1 0 19í -) Jj' 11056671 PRODUCTION PROFILE W/DEFT . 08/12/05 1 3G-10 ¡Cft,- ciJ..,. 11056670 INJECTION PROFILE 08/11/05 1 2Z-23 } qf(- f)I Ù 11015717 INJECTION PROFILE 08/10/05 1 2X-06 8 ~ - j D 11015711 INJECTION PROFILE 08/04/05 1 2X-07 /lP ···IJj 11015710 INJECTION PROFILE 08/04/05 1 1 Y -04 I J j- G t b 11047351 INJECTION PROFILE (REDO) 07/27/05 1 SIGNED: 1/ t (l./~ I !~.. UIkJw.J DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD -" -' t'~)" \J.~ ~~ S-· dì- ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~ - l. 104 '~ tV I-z.., Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.stat~.~us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2X-07 DATE: 10/11/04 OPERATOR REP: Sauvegeau/Rogers AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 2X-07 Type Inj S T.V.D. 5672 Tubing 1200 1200 1200 1200 Interval 0 P.T.D. 1831130 Type Test P Test psi 1500 Casing 1400 3000 2950 2950 P/F P Notes: Diagnostic MIT Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) SCANNED NO\! () 2 2004 MIT Report Form Revised: 05/19/02 MIT KRU 2X-0710-11-04.xls 10/12/2004 MEMORANDUM TO: THRU: FROM: Randy Rueddch Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 27, 2003 'X,'--~'"~-~, ¥'\ ,./) ~/~h ,,~\u\t3~ SUBJECT: Mechanical Integrity Test Jim Regg Conoco Phillips P.I. Supervisor 2X Pad KRU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2X-01 'lType,nj.I s I T.V.D. 15666 I Tubingl 750 1750 1750 I 750 I lntervall 4I P.T.D.I 183-084 ITypetestl P ITestpsil 1417 I Casingl 550 I 20251 20001 20001 P/F IP Notes: ! We,I2X-02IType'nj'{ sI ~.V.D. I~ I~.~,., I~o I~o I ~o I ~o I lntervall 4 P.T.D.I 183-103 ITypetestl P ITestpsil 1439 I Casingl 1200I 2000I 1975I 1975I P/FI -" I Notes: I VVellI 2X-03 P.T.D. I 183-109 Notes: 2X-04 183-1 Notes: I Type,nj.l: s I ~-.V.D. I ~'~o I Tubingl~000 I ~000 I ~000 I~o00 I,nter~a,I 4 I TypetestI P ITestpsil 1438 l CasingI 900 I 2000 I 2000 I 20001 P/F '1 -P Type Inj. Notes: WellI P.T.D.I Notes: 183~ 107 Type,.nj.I s i ~.v.~. i~ I Tubing! lOOO i~ooo i~ooo I ~ooo I,merv.a,I 4 TypetestI P ITestpsil 1418 I CasingI 950 I 19001 19001 19001 P/F I P 183-114 ITypetestl P ITestpsil 1500 ICasingl 13001 20501 20501 2050 I P/F IP I I Type INJ. Fluid Codes F = FRESH WATER IN J, G = GAS IN J. 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) Test's Details I traveled to Conoco Phillips 2x Pad in the Kuparuk field and witnessed the routine 4 year MIT's on the above listed 7 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: Z Attachments: Number of Failures: 0 TOtal Time dudng tests: 4 hours cc: MIT report form 5/12/00 L.G. 2003-0627_M IT_KRU_2X-08_cs.xls 7/11/2003 SCANNED" AUG 0 ~ 2003 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner T°m Maunder, ~ tO/~o~ P. I. Supervisor .\( Chuck Scheve; -petroleum Inspector DATE' January 25, 2001 FROM: SUBJECT: Safety Valve Tests Kuparuk River Unit 2X Pad Thursday, January 25, 200!-·1 traVeled to the KUparuk River Field and witnessed the 90-daY retest of the safety valve syStems on 2X Pad. As the attaChed AOGCC Safety Valve syStem Test Report indicates I witnessed the testing of 12 wells and 24 components With one failure observed. The Surface 'Safety Valve· on Well 2X-14 had a sloW leak when pressure tested. This valve was Serviced and t witnesSed a successful retest on 1-26-01. KRU 2X Pad, 12 wells, 24 components, 15 wellhouse inspections Earnie Barndt conduCted the testing tOday he demonstrated good test procedure and was a Pleasure to work with · All-the wellhouses entered at this lOcation were clean and all related equipment appeared to be in good Condition. Summary: I witnessed the 90-day SVS testing at 2X Pad in the Kuparuk River Field. ' = ~ failure 4.~% fail~re rate Attachment: SVS KRU 2X Pad 1-25-01 CS Unclassified Confidential (Unclassified if doc. Removed) 'SVS KRU 2X Pad 1-25-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Ph!llibs - 'Submitted By: Chuck Seheve Date: 1/25/01 Operator Rep: Eamie Barndt Field/Unit/Pad: ,,Kuparuk / KRU / 2X Pad AOGCC.Rep: Chuck Seheve Separator psi: ' LPS 99 HPS i i i i ii iii ~_:..~!!~ . :.-,' .k'-: ' : Well Pemit Separ Set ~ T~ .T~t T~t Date ~ WAG, Number Number PSI PSI : Trip Code Cod~ Code Pass~ G~ or ~~ '5~-0~ ~83o84o 2X-02 '1831030:~ '3750 2000 18'0b P ' P WAG 2X.03 1831090 . · 2X-~ . 1831180 · 3750 2000 '2000 P P ' ' WAG 2X-05 1831070 . 2X-06 1831100 . 5X_07 ,183i130 37~0 2000 20~ P' ' 'P ' W~G 2X-08 1831140 - 2x-o9 ~84~62o ~ ,o '~o e' e '" , . , . , . 2X-10 1841630 2x.~ 184'~0 ' ~ ' 6o '" 5oP P " 2X'12A 1951760 99 60 · 55 P P OIL - ~ ~, ~ . , , .. 2X-13 1841740 99 60 55 P P OIL . ,. , , ,, ... , , , 2X-14 1841750 ~ 60 55 P 4. 1/26/01 OIL 2X-15 '1841760 ' ' 99 60 55 P P " 'OIL 2X-16 1841720 99 60 '~5 p ~ ...... 0IL 5X-17 '1951710 99 60 60 "~' 'P ' ' '0IL 2X-18 19~ 1600 99 60 ' ' ~ P P ' OIL 2X-19 -: .~1951750 ~ . . , , . ,, , , . ,.. Wells: . Remarks: 12 components: . 24 Failures: 1 Failure Rate: 4.17% C)~o my Surface Safety, on well 2X-14 had v. er~,, slow leak when pressure tested, valve to be serviced and retested ,by operator. , , , RJF 1/16/01 Page 1 of 1 SVS KRU 2X Pad 1-25-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, Commissioner. DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor John H Spaulding, ~ .~. Petroleum Inspector FROM: SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & lX 1E - 8 wells, 16 Components, 1 failure, 9 % failure rate, 12 well house insp. 2X-~-::~ 10-wells~.~20 compnents, 1 failure; 5 % failure rate, 12 well house insp. AttaChment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Submitted By~ John H. Spauld Date: 7/22/00 Operator Rep: E. Barndt Field/Unit/Pad: Kuparuk/Kuparuk R. U./1 AOGCC Rep: John H. Spaulding Separator psi: LPS 91 HPS Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 1E-02 1800500 91 70 65 P P OIL lC-03 1800560i SI lC-05 1800580 lC-06 1800780 SI lC-07 1800800 91 60 55 P P OIL lC-10 1820360 lC-11 1820510 1 E- 12 1820600 SI lC-14 1820790 1 E- 18 1830160 91 60 46 P P OIL lC-19 ' 1830170 lC-20 1830050 91 60 48 P P OIL lC-21 1830020 ! 1E-23 1821840 ~ 1E-24A I971870 91 70 70 P P OIL 1E-26 1821660 SI I 1E-28 1821580 SI 1 E-29 1821540 SI lC-31 1971380 91 70 70 P P OIL 1E-33 1971510' 1E-34 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70i P P OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% l-] 9o Day Remarks: 8/7/00 Page 1 of 1 svs kupamk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Barndt AOGCC Rep: John H. Spa. ulding Submitted By: John Spaulding Date: Field/Unit/Pad: Kupamk/Kupamk R./2X Separator psi: LPS 96 HPS 22'Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code GAS or CYCLE ! 2X-01 1830840 2X-02 1831030 ,2X-03 1831090 2X-04 1:831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000! P P WAG ~~' 1831,130 3500 2000 20001 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL 2X-10 1841630 96 70! 65 P P OIL 2X-11 1:841640 96! 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 2X-14 1841750 2X-15 1841760! 96 70 70 P P OIL i2X-16 1841720 2X-17 1951710 · 96 .60 50 P P OIL 2X-18 , 1951:600! 96 60 50 P P OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% [-3 9o var Remarks: RI1 q/fill Pa~e 1 of 1 svs kuparuk kru 2x 7-22-00js.xls 1. Operations Performed' 0t 151 z Al~ ~A OIL AND GAS CONSERVATION COMI~ 'ION / REPORT OF SUNDRY WELL OPEH TIONS Operation Shutdown Stimulate w Plugging Perforate Other CONVERSION 6. Datum elevation (DF or KB) Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _. Exploratory _ Stratigraphic Service ~ Location of well at surface 450' FSL, 601' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1195' FSL, 1546' FEL, Sec. 4, T11N, R9E, UM At effective depth 1287' FSL, 1340' FEL, Sec. 4, T11 N, R9E, UM At total depth 1310' FSL, 1289' FEL, Sec. 4, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7435' 6294' feet Plugs (measured) feet RKB 106' 7. Unit or Property name Kuparuk River Unit 8. Well number 2X-07 feet 9. Permit number/approval number 10. APl number s0-029-20991 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7 3 3 0' true vertical 6206' Length Size 1.12' 16' 3207' 9 5/8" 7412' 7" measured 6872'-6951 ', true vertical 5807'-5877', Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet Junk (measured) feet Cemented 279 sx AS II 1500 sx AS III & 250 sx AS I 500 sx Class C & 350 sx AS I 7083'-7093', 7105'-7135' 5994'-6003', 601 4'-6040' Measured depth True vertical depth 112' 112' 3207' 2756' 741 2' 6275' Tubing (size, grade, and measured depth) 3 1/2", J-55, tbg s/tail @ 7029' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 6722', FB-1 pkr @ 7006', 7 TRDP-1A SSSV @ 1877' ~13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure J U L 2 Alaska Oil .& Gas Cons. Cornmission Anchorage /o/// 14. Pressure Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Prior to well operation Subsequent to operation 6700 6800 1200 1600 850 3800 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector ~ Daily Report of Well Operations Oilm Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service WAG In!ector Signed Form 10-404 Rev 06/15/88 Title SUBMIT IN DUPLICATE STATE Of ALASKA ~-~' ,/L ALASKA ~,IL AND GAS CONSERVATION COMMISSION WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL 0~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 83-113 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-20991 4. Location of well at surface 9. Unit or Lease Name 450' FSL, 601' FEL, Sec. 4, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1195' FSL, 1546' FWL, Sec. 4, TllN, R9E, UM 2X-7 At Total Depth 11. Field and Pool 1310' FSL, 1289' FWL, Sec. 4, T11N, RgE, UN Kuparuk River Fi'eld 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 106' ADL 25645 ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 08/04/83 08/11/83 08/30/83*I N/A feet MSLI 1 7435'MD, 6294'TVD 7330'MD, 6206'TVD YES [~ NO [] 1877 feetMD 1500' (approx.) 22. Type Electric or Other Logs Run DIL/SFL/GR/Cal, FDC/CNL/GR/SP, BHCS/GR, RFT, CBL/VDL/GR/CCL, Gyro, CCL/HP/Temp. Log~ Fluid Density Log, Spinner 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 ~urf 11 2' 24" 279 sx AS I I 9-5/8" 40.0# J-55 ;urf 3207' 12-1/4" 1500 sx AS Ill & 250 sx A$ I 7" 26.0# J-55 ;urf 7412' 8-1/2" 500 sx Class G & :350 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6872'-6951 'MD 3-1/2" 7029' 6722' & 7083'-7093'MD Perforated w/4 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7105'-7135'MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6998'-7000' 200 sx Cla.~.~ C. 5807 '-5877'TVD 6825'-6827' 50 sx Class 5994'-6003~TVD See at:.t:a~h~.rt A~rl~nrl,,m. rt~-,=~I (%~/9/,/R7 ~,-~,.. ~ __, ..... ; ...... v~, ~ ~, 6014 ' -6040 ' TVD 27. ~/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 IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) 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. i"!-~ i~" ~ ~:'~ ~ ~ ~ ~ · '... :-:,, il; ,..:.: i~,:,L: ',.:.~;,.:.. · NOTE: Well wocked over & reperforated 01/13/87. Ii,~q~ ~ I_ ,1 hA&II WC2:41:DANI Submit in duplicate / Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 30. i;~ ' ' 29. ,,.~._ , ,: GEOLOGIC MARKERS ' - ~ ". '-FORMATI0~N.'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 '6870' 5806' See Well Completion Report, dated 10/17183, Base Upper Sand 6947' 5875' for RFT data. Top Lower Sand .- ~706:3' 5977, Base Lower Sand 7212' 6106' : · 31. LIST OF ATTACHMENTS Addendum (dated 03/24/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .. Signed ~ ~j~_? '~L'~ 2 (~.~ Title Associate Engineer Date z~-/Z~"7 /I 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- 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". Form 10~407 ADDENDUM WELL: 1/19/87 2X-7 Frac Kuparuk "A" sand perfs 7083'-7093' & 7105'-7135' in 7 stages per 12/24/86 procedure by pmp'g: Stage 1: 40 bbls, 145° diesel w/5% Musol @ 5 BPM, 2230 psi Stage 2: 81 bbls gel/diesel pad @ 20 BPM, 4100-3500 psi Stage 3: 18 bbls gel/diesel w/l# 100 mesh @ 20 BPM, 3500 psi Stage 4: 55 bbls gel/diesel spacer @ 20 BPM, 3500 psi Stage 5: 26 bbls gel diesel w/3# 20/40 sand (fly) @ 20 BPM, 3400-3700 psi Stage 6: 39 bbls gel/diesel w/8# 20/40 (batch) @ 20 BPM, 3400-3700 psi Stage 7: 60 bbls gel/diesel flush @ 20 BPM, 3700-3140 psi. (Intentionally underflushed 2.5 bbls.) Fluid to Recover: Sand in Csg: Sand in Zone: Average Pressure: 319 bbls 672# 20/40 800# 100 mesh & 15,708# 20/40 sand 3500 psi Dr i~ng Superv~or ~ D~te STATE OF ALASKA AI~ OIL AND GAS CONSERVATION coMM~,' ~_)ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extensmn _ Stimulate Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) Suspend _ Alter casing _ Repair well Change approved program X Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic 99510 Service ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 450' FSL,601' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1195' FSL, 1546' FWL, Sec. 4, T11N, R9E, UM At effective depth 1287' FSL, 1340' FWL, $ec.4, T11N, R9E, UM At total depth 1310' FSLr 1289' FWLr Sec. 4~ T11N~ R9E~ UM RKB 106' 7. Unit or Property name Ku@aruk River Unit fee~ 8. Well number 2X-07 9. Permit number 83-113 10. APl number so-029-20991 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7 4 3 5' true vertical 62 9 4' Effective depth: measured 7 3 3 0' true vertical 6 20 6' Casing Length Size Structural Conductor I 1 2' 1 6" Surface 3207' 9-5/8" Intermediate Production 741 2' 7" Liner Perforation depth: measured 6872'-6951 ', true vertical 5807'-5877', Tubing (size, grade, and measured depth) 3 1/2" J-55 @ 7029' feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 279sxAS II 112' 112' 1500 sx AS III 3207' 2756' 250 sx AS I 500 sx Class G & 741 2' 6275' 350 sx AS I 7083'-7093', 7105'-7135' RECEIVED 5994'-6003', 6014'-6040' MAY 1 5 !991 Alaska 0ii & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage HRP-I-SP pkr @ 6722'~ FB-1 pkr @ 7006'~ & TRDP-1A SSSV @ 1877. 13. Attachments Description summary of proposal_ Detailed operation program X BOP sketch 'Convert well from water injector to WAG iniector (Alternating water and immisicible gas). 14. Estimated date for commencing operation 115. Status of well classification as: May, 1991 I oi~ _ (~as _ 16. If proposal was verbally approved Name of approv~ Date approved Service WAG In!ector 17. I here/l~ ce~ that the foregoing is true and correct to the best of my knowledge. J. FOR COMMLSSIOR USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance ~ Mechanical Integrity Test m Subsequent form require Approved by order of the Commission Form 10-403 Rev 09/12/90 ORIGINAL SIGNED BY I n~NtF C, SMITH Suspended IApproval No. 10- ~kpproved CoPY Returned ' Commissioner Date SUBMIT IN TRIPLICATE STATE OF ALASKA ~ ALASKA'OiL AND GAS CONSERVATION CC~IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG __ 1. Status of Well Classification of Service Well / OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVlCE[~ Water Tnjector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-113 , 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20991 4. Location of well at surface 9. Unit or Lease Name 450' FSL, 601' FEL, Sec. 4, T11N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1195' FSL, 1546' FWL, Sec. 4, TllN, R9E, UM 2X-7 At Total Depth 11. Field and Pool 1310' FSL, 1289' FWL, Sec. 4, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 106'I ADL 25645, ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. i 15. Water Depth, if offshore 116. No. of Completions 08/04/83 08/11/83 08/30/83*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7435'MD 6294'TVD 7330'MD 6206'TVD YES ~ NO []I 1877' feet MD 1500' (Approx) . 22. Type Electric or Other Logs Run D IL/SFL/GR/Cal, FDC/CNL/GR/SP, BHCS/GR, RFT, CBL/VDL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , , 16" 62.5# U-40 Surf 112' 24" 2,79 ax AS II 9-5/8" 40.0# J-55 Surf 3207' 12-1/4" 1500 sx AS Ill & 250 sx AS I 7" 26.0# J-55 Surf 7412' 8-1/2" 500 sx Class G & 350 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7029' 6722' ~ ?nn~, 6872 ' -6951 'MD '~ , 7083'-7093'MD perforated w/4 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7105'-7135'MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED . 6998 ' -7000' 200 sx £1 as.~ C. 5807'-5877'TVD 6825'-6827' 50 sx Cla.~.~ C 5994 ' -6003 ' TVD · 6014 ' -6040 'TVD 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL G~,SIMCF wALFER-BBL CHOKE S,ZE I GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~l~ OIL-BBL GAS-MCF wATER-BB'L 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 RECEIVED .LViAR ! 2 987 *Note: Well worked over & reperforated 01/13/87. AISS~(~ 0II & GaS I~0rm. Commission Anchorage WC2: 036 :DAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. oEO'LoGiC'MA S -' 'J. '" ' ;'' ;; ~'' / ':: "' J-: .:' ;: .'~"?~F. ORMATiON TESTS · : -. '; - ' , ' ~ ' ' · /' .' . - ; ' : - 'i . :' ~ ' * '" -"' '; '. '*-. ' - ' ' :--' --':': ' ' ~; ' : ' ;':;% - ' "*' .... . ' " ,'*.c;--,," X "~,.;' : . ~ , , ' .'~ '- ~ ;,. '.".'" - Include interval tested, pressure data, all fluids recovered and gravity, NAME MEAS. DEPTH TRUE VERT. DEPTH OCR, and time of each phase. Top Upper Sand 6870' 5806' See Well Completion Report, dated 10/17/83, Base Upper Sand 6947' 5875' for RFT data~ Top Lower Sand 7063' 5977' .'-' - Base Lower Sand 7212' 6106' , . ~ . 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ' Signed (~ ~ ~~L/I~/ Title Asso¢i ate Engi neet Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the Cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cor'eS taken, indicate "none". Form 10-407 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMM-,..~iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate C Plugging [] Perforate~ Pull tubing ~_~ W0RKOVER Alter Casing [] Other ~ 2. Name_of.Ooerator AECO A-[c%-P,a, Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 450' FSL, 601' FEL, Sec. 4, T11N, RgE, UN At top of productive interval 1195' FSL, 1546' FWL, Sec. 4, TllN, RgE, UPi At effective depth 1287' FSL, 1340' FWL, Sec. 4, T11N, RgE, UN At total depth 1310' FSL, 1289' FWL, Sec. 4, T11N, RgE, UN 5. Datum elevation (DF or KB) RKB 106' 6. U. nit or Property name ~uparuk R~ver Unit 7. Well number 2X-7 8. Approval number 580 9. APl number 50-- 029 -20991 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7435'HD 6294'TVD 7330'MD 6206'TVD Casing Length Size Conductor 112 ' 16" Surface 3207 ' 9-5/8" Producti on 741 2 ' 7" feet feet feet feet Plugs (measured) Junk (measured) None None Cemented 279 sx AS II 1500 sx AS III & 250 sx AS I 500 sx Class G & 350 sx AS ! Measured depth 112'MD 3207 'MD 741 2 'MD True Vertical depth 112'TVD 2756 'TVD 6275 ' TVD Perforation depth: measured 6872'-6951'MD, 7083'-7093'MD, 7105'-7135'MD true vertical 5807 '-5877 'TVD, 5994'-6003'TVD, 6014'-6040'TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail @ 7029' Packers and SSSV (type and measured depth) HEP-1-SP pkr @ 6722', FB-1 pkr ~ 7006', & TEDP-1A SSSV ~ 1877' 12. Stimulation or cement squeeze summary Intervals treated (measured) 6998 ' -7000 ', 6825 ' -6827 ' Treatment description including volumes used and final pressure 200 sx Class G, 50 sx Class G 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Obi Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations .~ Copies of Logs and Surveys Run '.~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,,~7~]/ '/~ ,--/,,?-. -~.~ Signed ~'~ Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (DANI) 5W0/170 Submit in Duplicate Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or b gh .... IState Alaska North Slope Borough I Lease or Unit ADL 25645 Title Re comp let ion Field Kuparuk River Auth. or W.O. no. AFE Alaska IWoII no. 2X-7 Nordic #1 API 50-029-20991 Operator lARGO W.I. ARCO Alaska, Inc. 56.24% SpuddedorW.O. begUnworkover JOate 1/3/87 JHour 1515 hrs. IPri°rstatusifaw'O' Date and depth aa of 8:00 a.m. 1/01~/87 thru 1/05/87 . -.. .. /.i;,;i i,,,~.v'~. - .'-'./'; ,_.. - ;~;//.__ ::-' :-:-:: - ..-._'l,/e6/&7:'-':..-: . . . ..~. · .... 1/07/87 . , ~. -. . 1/08/87 · - 1/09/87 Complete record for each day reported 7" @ 7412' 7330' PBTD, Rn CET log Accept ris @ 1515 hfs, 1/3/87. Rill, pull"cite viv f! 6695'. Prop 50 bbls Lites'al pill & dispt.-w/59 (bullhead 99 bbls-tot:al). Monitor well; well NU & ts, BOPE. Pull tbg & chg all..colrS:t-'o./~AB~r~o~;:i'~._ par @ 6758 , POH. RIH w/CET lo . - 7 ~ 7412 - 7330 PBTD, RIB w/6-t/8 bit -- - -. ..-.~'-- ..... ~ CET log f/7242'-5995'. 'RIH, perf 6998':7000' w/BP, aet ~ 7025'. RIH, set retnr ~ 6975',.-.~ Sc II - ; '- :'[~;~ ~:' - 7 e 7~---_. . 7025~ ~<~:-'D~ o~ ~ZSV .-..-_.: -' ~0. ~ gp~ ~ZE & se~ ~ZSV ~ 6970~ ~. ~B ~/s~a~e~, ~&~ ~00 s~ C~ ,g, . w/.85Z D-60, .2% ~-~6 & 5% ~C~ a~d s~a~e ~Co ~o~o~. ~aa~ . . eq= p~e~e = ~300 ~s~. ~ev DUC, g00E ~/sC~se~. 10.0 ppg ~aCl/~aBr ~rl e~t to 7022', e~rc, P00~. RI~ w/R-3 pkr, set 0' 6970~i t~t ' ' ' sqz perfs 0 6998~-7000* to 2000 ps~; bled off i00 The above is correct see Procedures Manual, Section 10, Drilling, Pages 88 and 87. Date Title Drilling Supervisor 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 reporting the entire operation if space is available. I Accounting cost center District County or Parish JState Alaska North Slope Borough / Alaska code Field Kuparuk River Auth. or W.O. no. AFE AK1851 Lease or Unit Title ADL 25645 Recompletion IWell no. 2X-7 Nordic 1 API 50-029-20991 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Workover 1/3/87 I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our 1515 hrs. Prior status if a W.O. Date and depth as of 8:00 a.m. 1/10/87 thru 1/12/87 1/13/87 Complete record for each day reported 7" @ 7412' 7330' PBTD, Perf'g 10.0 ppg NaCl/NaBr TIH w/mill to 7021', mill out BP. RIH to 7245', CBU, POOB. RU WL, perf f/6825'-6827', set Bkr BP @ 6850', set CR @ 6800', RD WL. RIB w/stinger on 3½" DP, est IR @ 1/4 BPM, 3000 psi, sqz 50 sx C1 "G" w/.85% D-60, 5% KC1 & .2% D-46. Sting out of retnr, POOH. Chg out tbg head. NU &tst BOPE. RIB w/BHA, tag retnr, tat csg to 3500 psi. DO CR & cmt to BP. Tat sqz perfs to 2000 psi; OK. Drl BP, TIH to 7237', CBU, POOH. RIB w/bit & scrpr to 7237', CBU, POH, LD 3½" DP. RU WL, perf 6931'-6951' w/4 spf, 90° phasing. RIB w/perf gun #2. 7" @ 7412' 7330' PBTD, RR 6.8'ppg Diesel Perf w/4" gun, 4 SPF, 90° phasing f/6911'-6931'. Make JB/GR rn to 7200'. Set FB-1 pkr @ 7006', RD WL. RIB, set pkr, shear out OEJ & re-lnd tbS. Press tat backside to 2500 psi; OK. Tst SSSV. ND BOPE, NU & tat tree. Displ well w/diesel. RR @ 0600 hfs, 1/13/87. (NOTE: Rn 217 its, 3-1/2", 9.3#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1877', BRP-1-SP @ 6722', FB-1 @ 7006', TT @ 7029') Old TD J New TD PB Depth 7330 PBTD I Released rig ~ Date I Kind of r g 0600 hrs, I 1/13/87 I Rotary Classifications (o11, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Pate Reservoir Producing Interval Oil or gas Test time Production Oil 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5894 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3N-13 3N-14 3I-9 2X-7 2X-7 CET 5-15-86 6342-7768 CET 5-15-86 5882-7328 CET .5-5-86 7090-8949 CET 1-5-87 5995-7242 CET 1-8-87 5995-7011 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Anchcr.~0 Date: Mobil SAPC Unocal BPAE Chevron ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany STATE OF ALASKA ALASKA,,..-~L AND GAS CONSERVATION COMMI~,,.-~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend -- Operation Shutdown ~- Re-enter suspended well ~ Alter casing ~ Time extension - Change approved program ? Plugging ~ Stimulate ~ Pull tubing ~ Amend order ~- Perforate -- Other~' 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anehoraae 4. Location of well at surface 450, FSL, 601' FEL, Sec. 4, T11N, R9E, UN At top of productive interval 1195' FSL, 1546' FWL, Sec. 4, T11N, RgE, UM At effective depth 1287' FSL, 1340' FWL, Sec. 4, T11N, RgE, UH At total depth 1310' FSL, 1289' FWL, Sec. 4, T11N, RgE, UN 5. Datum elevation (DF or KB) 106' RKB feet 6. Unit or Property name Kt~n.-ar~k ~iv~r IIn~'l-; 7. Well number 2x-7 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 112' 3207' 7412' Production 7435'MD 6294'TVD 7330'MD 6206'TVD 8. Permit number 83-113 9. APl number 50.~.29-20991 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet feet Junk (measured) feet None True Vertical depth 112 'TVD 2756 'TVD 6275 'TVD Perforation depth: measured true vertical Size Cemented Measured depth 16" 279 sx AS II 112'MD 9-5/8" 1500 sx AS III 3207'MD 250 sx AS I 7" 500 sx C1 ass G 7412'MD 350 sx AS i 6872' - 6951 'MD, 7083' - 7093'MD 7105' - 7135' 5807' ' - 5877'TVD, 5994' - 6003'TVD, 6014' - 6040'TVD Tubing (size, grade and measured depth) 3-1/2", J-55 @ 6789' Packers and SSSV (type and measured depth) HRP @ 6758' & TRDP @ 1881' Description summary of proposal~' Detailed operations program ~- BOP sketch~ 12.Attachments 13. Estimated date for commencing operation December 21, 1986 Date approved 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ .~A.U..~,~.Jt.~ Title Associate Engineer ~/ Commission Use Only (JWR) 5A/157 Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~- Location clearance Date 1142-~G IApproval No. ,~oC,~ Conditions of approval Approved by Commissioner by order of .. ,.-,"J;t^ ~/ ] the commission Date //'" ~/.2 ~-~ I, Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 2X-7 Conversion to Selective Single Preliminary Procedure 1. Move in and rig up workover rig. Kill well. 2. Nipple down tree. Nipple up and test BOPE. 3. Shear out of SBR. POOH and stand tubing in derrick. 4. Pick up 3-1/2" drill pipe and retrieve packer. POOH. 5. Run CET. Perform cement squeeze between "A" and "C" sands, if required. 6. Run in hole and set retrievable bridge plug. Remove 3M tubing head and install 5M head. Test casing to 3500 psi. Retrieve BP. 7. RIH with casing scrapers and 6-1/8" bit to PBTD. Circulate and condition brine. POOH. 8. Reperforate "C" sand if well is squeezed. Run GR/JB to PBTD. RIH and set permanent packer between "A" and "C" sands. 9. Run 3-1/2" single selective completion assembly. 10. ND BOPE. NU tree and test. 11. Displace well to diesel by reverse circulation. 12. Test annulus and tubing. 13. Secure and release rig. 14. The well will be acidized and/or fracture stimulated after rig release. (Workover Fluid: NaC1 /NaBr) BHP = 2821 psi ~ 5806' TVD (6872' MD) SA/157a:dmr 11-10-86 ANNULAR PREVENTER BLIND* RAILS ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUIMULAT01~ i~SERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. :2. ASSURE THAT ACCUI~JLAT01~ PRESSURE IS ;~000 PS1 WITH 1500 PS! D(TWNSTI~EAM OF THE I~(~JLATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REI~IAININ~ AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE L~R LIMIT IS 45 SECONDS CLOSIN~ TIME AND 1200 PSi REI'IAININ~ PRESSURE. PIPE RAIflS TUBIN~ HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8' 2. 11"-3000 PS1 STARTING HEAD 3. 11"-3000 PSI X 7-1/!6"-5000 PSi ~JBING HEAD 4. 7-1/16" - 5000 PSI PIPE DAMS 5. 7-1 / 16" - $000 PSI BLIND RAMS 6. 7-I/!6' - 5000 PSI ANNULAP Bop STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS AI:~ FULLY I~TRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN L(X:K-OOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCI:~EASE PI:~ESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PPESSURE TO ZERO PSI TO TEST VALVES, TEST REMAINING UNTESTED MANIFOLD VALVES, tF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLO~E BLIND RAMS AND TEST TO 3000 PSI FOf~ 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING PO~I TION, 1 ~. TEST STANDPIPE VALVES TO :3000 PSi. ~2. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. '3 ~ECORD TEST iNFORMATION ON BLOWOUT PREVENTER TEST FORM. SiGN AND SEND TO DRILLING SUPERVISOR, 14 PERFORM COMPLETE B0PE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY _ . ~ dUNE 16, 1986 (NORDIC RIO 9-5/8") Mr. C. V. Chat*orton May 27, 1986 Page 3 Wel 1 Number Date 1L-5 1R-3 of Initial ~e~'~~ ~~Injection profile 10/2 3/25/86 11/19/85 ~ ~- : 3/21/86 lQ- 13 11/16/85 3/18/86 Well Number Date of Initial Injection Date of Injection Profile 1Y-2 3/30/85 8/7/85 1Y-8 3/30/85 8/8/85 1Y- 12 3/30/85 8/10/85 1 Y- 15 10/28/85 3/23/86 Well Number Date of Initial Injection Date of injection Profile 2W-2 11/15/85 3/26/86 2W-8 11/15/85 3/27/86 2W-9 1/13/86 3/28/86 2W- 10 11/15/85 3/29/86 2W- 14 11/15/85 3/31/86 Well Number Date of Initial Injection .Date of Injection Profile 2X-1 2X-2 2X-3 2X-6 2X-7 11/4/85 3/22/86 1/19/85 3/14/86 11/4/85 3/23/86 11/4/85 3/21/86 11/4/85 3/23/86 Well Number Date of Initial Injection Date of Injection Profile 2Z-3 11/4/85 4/3/86 2Z-14 12/2/85 4/2/86 2Z-16 12/1/85 4/6/86 VL F: pg: 0051 RECEIVED NSAY 0 Oil & ARCO Alaska, Inc. Post Officer~.,,..,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Corrrnission 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 1F-4 Convers 1F-5 Convers 1F-8 Convers 1G-3 Convers 1G-4 Convers 1L-3 Convers 1L-5 Convers 1Q-8 Convers 1Q-12 Convers 1Q-14 Convers 1R-3 Convers 1R-10 Convers 1Y-7 Convers 1Y-10 Convers 1Y-15 Convers 1Y-13 Convers 2B-6 Convers 2B-8 Convers 2B-11 Convers 2B-12 Convers 2C-2 Convers 2C-4 Convers 2C-5 Convers 2C-7 Convers 2D-4 Convers 2D-5 Convers 2F-3 Convers 2F-4 Convers 2F-15 Convers 2F-16 Convers 2D-10 Convers 2D-16 Convers on on on on on on on on on on on on on 10/24/85 10/24/85 10/24/85 10125185 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10/25/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 11/5/85 11/5/85 1115185 11/5/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 1116185 11/2/85 1112185 11/2185 11/2/85 11/6/85 11/6/85 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany Mr. C. V. Chatterton, Chairman Page 2 Well Action 2X-1 Conversion 2X-3 Conversion 2X-6 Conversion- 2X-7 Conversion ~ Conversion 2Z-3 Conversion 2Z-6 Conversion 2Z-8 Conversion Date Per fo rmed 10/31/85 10/24185 10124185 10/31/85 1111185 11/1/85 11/1/85 11/1/85 If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. RECEIVED DEC 0 6 1985 Alask:..,,~ ~, ........ ,~. u .... missioff A~;hurage STATE OF ALASKA ALASKA 0TL AND GAS CONSERVATION CO~r~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. N~5,~p~I~Z, SKA, INC. 3. A~r.~SSo. BOX 1 00360, ANCHORAGE, ALASKA 9951 0 OTHER [] 4'L°~,,~i~F°/~EI LOCATION' q50' FSL, 601' FEL, SEC. T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 106' (RKB), PAD 77' 12. 7. Permit No. 83-113 8. APl Number 50- 029-20991 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2X-7 11. Field and Pool KUPARUK RIVER F I ELD 6. Lease Designation and Serial No. KUPARUK R I VER O ! L ADL 256/45, ALK 2576 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other X[] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 31, 1985 Kuparuk well 2X-7 was converted from a producer · to a water injector well as part of the full field waterfiood conversion effort. Water is being injected into both the "A" and "C" sands. t <ECEiVED Alaska 0ii & Gas Cons. C0mm.oo~0r~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~/, /'//~"~--'~ ~____~,~<~~ Title KU PARUK Date 11 / 1 5 / 85 Signed OPERAT i ONS COORD i NATOR The space below for Commission use 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 ARCO Alaska, Inc Post Office~J~.x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern.-Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED S E 0 O~J & G~s Curls. CommJssio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK/,_.;L AND GAS CONSERVATION C, ,,MISSION 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 50- see attached 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 6. Lease Designation and Serial No. see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool . Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other X~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is propOsed that the attached list o~A/~roducing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands.. SEP201.9B5 Gas Cons. Comm~'ss!°n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,/¢~ ~~--- Tit,e Kuparuk Operations Coordinator Date_ 9/18/85 The space below for Commission use Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 COMMISSIONER By Order of ~ ,.~ ~.~ ~:;~--- ,I the Commission Date /- Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 223 237 239 83- 84 103 109 118 107 110 113 114 83- 80 85 77 38 85-138 107 109 21239 21253 21255 029-20963 20982 20987 20995 20985 20988 029-20991 ~ 20992 029-20960 20964 20957 20924 21377 21379 21361 21363 25645 25645 25653 25646 25653 25646 2576 2576 2579 2577 2579 2577 10 10 12 10 12 10 12 12 10 12 10 /15/85 /15185 115185 115185 115185 115185 115185 115185 115185 115185 /15185 10/15/85 10/15/85 10/15/86 10/15/85 12/15/85 12/15/85 12/15/85 12/15/85 MARK:0093 RECEIVED Alaska, Oil & Sas C;ons. Anchorage ARCO Alaska, Inc. Post Office' ,360 Anchorage, ~"r. aska 99510 Telephone 907 277 5637 RETURN TO: -. ~CO ALAS~, INC. ATTN: Records Clerk ATO-1115B Box 100360 //Transmitted herewith are the following it.s. ~ and return one signed copy of this transmittal. Date: 2/05/85 Transmittal No: 4824 Please acknowledge receipt PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 Gearhart -~-~2Z-6/ 9/03/84 Otis 2X-6/ 8/16/84 Gearhart ---- 2X-4/ 8/16/84 Camco --2X-lvj~ 8/16,19/84 Camco ~2V-5/' 8/16,19/84 Dresser ~2V-2/ 9/07/84 Otis ~2F-9/ 8/28/84 Otis / -~2F-SW', 10/08/84 Camco / --2F-7/ 10/07/84 Otis ..... 2B-15/ 9/03/84 Otis ~-2C-5 / 8/17/84 Otis -,-1Y-13/ 8/16/84 Dresser ~lY-9/ 9/07/84 Camco --,1Y-5~ 9/14/84 Camco 1Y-5~ 9/06/84 Otis ~lG-6~ '8/25/84 Otis ~lH-4~ 9/04/84 Otis ~1F-12¥ 9/09/84 Otis ~lF-9F 8/17,18/84 Camco <-lF-8z 8/16,17/84 Camco ~-lg-8/[ 10/12/84 Otis ~lD-5/ 10/07/84 Camco '~iA-4wz 9/02/84 Otis '--iA--3/ 9/02/84 Otis Receipt Acknowledged: "~rP 232" "HP 233" 9/06/84 "SBHP" 9/05/84 "Static BHP" 8/17/84 "PBU"" 8/16/84 "PBU" 10/13/84 "SBHP" "E Line" 10/07/84 "Pressure ?alloff" DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathme!l Well Files ARCO Alaska, Inc. · Post Office B~[-'360 Anchorage, Alaska 99510 Telephone S07 277 5637 January 17, 1984 Chat Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat: Commission Attached in duplicate following wells at the Well Action are subsequent notices on the Kuparuk River Field: Date Performed 1F-9 Perfora 1Y-11 St imul a 1Y-14 Product Test SWPT ~1 Mud aci SWPT ~1 Water I 2X-1 Perfora 2X-2 Perfora 2X-3 Perfora 2X-5 Perfora 2X-6 Perfora 2X-7 Perfora tion 11/30/83 tion 11/14/83 ion/Injectivity 5/24/83 d wash 11/22/83 njection see attached tion 12/9/83 tion 12/10/83 tion 12/11/83 tion 12/12/83 tion 12/13/83 tion 12/14/83 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (Duplicate) Gas Cons. Comm.s,;,lon A~cborage ARCO Alaska. !r,c. is a .subsidiary of AtlanticRichfieldCemp~--qy STATE OF ALASKA ALASKA"i~L AND GAS CONSERVATION C'~'~;)JMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator ARCO ALASKA, !NC, 3. Address P. O..BOX 100360, ANCHORAGE, ALASKA 99510 OTHER 4. Location of Well SURFACE LOCATION' 450' FSL, 601' FEL, SEC. 4, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' (RKB), PAD 77 ' 12. 7. Permit No. 83-113 8. APl Number s0- 029-20991 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2X-7 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RIVER OIL ADL 25645, ALK 2576 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 12-14-83 perforated "A" sand with 4 shots per foot. Intervals' 7083-93'; 7105-35'. Signed--~'~'~ ~¢~1~~'~-'-~"'~¢-' ~~ Title KUPARUK The space below for Commission use OPERAT IONS COORD I NATOR Date /"""' / ? """ ~"~ (~ Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK E'iiGINEERING TRAHSH!TTAL # ~ j~O0 TO' ~ FROM: D. Fay Allison DATE' /' /~)' g,-~ WELL NAME' see Transmitted herewith are the following- PLEASE NOTE:~- BLUELINE, S - SEPIA, F - FILM, T - TAPE,~'~- PHOTOCOPY Well Deseript ion Date Run ] PT AC,,hO,,ILEDGED' DATE' LEASE RETURH RECEIPT TO' ARCO ALAS,,A, INC. ATTH' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 · ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TRANSMITTAL DATE' /, q . ~ ~ WELL NAME' Transmitted herewith are the following' PLEASE NOTE: BL- BLIJELINE, S- SEPIA, F- FII]A, T-TAPE,~- ~PY~ ./-X,.× '- ~, [aZ, c) . RECEI PT ACKNOWLEDGED' qEASERETURN RECEIPT TO: DATE- ARCO ALASKA, INC. ATTN: D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TRANSMiTTAl = - = ~7 7et) FROM- D. Fay A1 lison ,,,ELL NAI',IE- .. ?g~ ~ Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TA~"~ /~I PT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO' ARCO ALASF, A, IHC. ATTII' D. FAY ALLISON - AT0/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 KUP/~K EKG I NEERI FIG TO' William VanAlen D. W. Bose/Shelby J. Matthews DATE: WELL i'~/£ · 2-2-'7 Transmitted herewith are the fot Iowin9' PLEASE NOTE~ ~ - F - FI IA4, T - TAPE, PC - F1-DTOOOPY p~IPT AC_.KNO>~ FTYS: LEASE ~ RECEI PT'TO: ARCO ALASKA, INC. A~' ~E~Y J. k~B~5 ATO/~!~ ,,,,.. Gas 0otis, 6om, msg~o~' ' ' ~' · ' P. O. ~X 100360 Anchera/~o AFl, GE, ,~. 9 9 51 0 Ig. JP/-~,'~tJK ENC, I NEERI hE; TO: William VanAI en Ff'~-,4: D.W. Bose/Shelby J. ~tthews Transmitted herewith are the following: /PLEASE RE'P. JRN RECEIPT' TO: ATTN' SHELBY J. P. O. BOX 100360 AhE]-E)Pc~E;,E, AK. 99510 ARCO Alaska, Inc. Post Office I~o,,~. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 17, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2X-7 Dear Mr. Chatterton: Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG: tw GRU4/LI09 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany f._¢_ STATE OF ALASKA ALASKA LANDGAS CONSERVATION C; -i!MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILX~r~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-113 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20991 4. Location of well at surface 9. Unit or Lease Name 450' FSL, 601' FEL, Sec.4, TllN, RgE, UM T[~C~:FION$1 Kuparuk River Unit VERiFiED At Top Producing Interval 10. Well Number 1195' FSL, 1546' FWL, Sec. 4, T11N, RgE, UM iSurf. ~_ ~ 2X-7 At Total Depth I B, H. ~..-~ 11. Field and Pool 1310' FSL, 1289' FWL, Sec.4, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKB ADL 25645, ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 08/04/83 ,_ 08/11/83 08/30/83J N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 7435'MD,6294'TVD 7330'MD,6206'TVD YES~ NO [] 1881 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/Cal, FDC/CNL/GR/SP, BHCS/GR, RFT, CBL/VDL/GR/CCL, Gyro. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 112' 24" 279 sx AS I I 9-5/8" 40.0# J-55 Surf 3207' 12-1/4" 1500 sx AS Ill & 250 sx /~S I 7" 26.0# J-55 Surf 7412' 8-1/2" 500 sx Class "G" & 350 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 3-1/2" 6789' 6758 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 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 CHOKESITE GAS-OILRATIO TEST PERIOD I~ · 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 A~.ch0rage Form 10-407 GRU4/WC11 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " ' .... : ' GEOI"O~I:C'.'MAi~KERs' -. .i": ::' :-~ :i: ':. i '~? ':,i !~!. :.E°'R~.ioN!:-TE~TS _ 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 6870' 5806' Base Upper Sand 6947' 5875' See attached sheet for RFT results. Top Lower Sand 7063' 5977' Base Lower Sand 7212' 6106' 31. LIST OF ATTACHMENTS Drilling History, Completion Summary, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge L Signed _/~_~/~~,/~.~44~-~A~' TitleArea Dril ling Engr' Date / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing' intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ~i,-~,.,-n I n_nn7 2X-7 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0300 hrs, 08/04/83. Drld 12-1/4" hole to 3237'. Circ and cond hole. Ran 82 jts 9-5/8" 40# J-55 HF-ERW BTC csg w/shoe @ 3207'. Cmtd 9-5/8" csg w/1500 sx AS III & 250 sx AS I. Bumped plug w/2000 psi - floats held - ok. ND 20" Hydril & diverter. Performed top job w/75 sx AS I. Instld FMC wellhead. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt, FS & 10' new form. Tstd form to 11.9 ppg EMW - ok. Drld 8-1/2" hole to 7365'. Ran Cal/DIL/SFL/GR f/7356' to 3206'; FDC/CNL/GR/SP f/7330' to 3206'; BHCS/GR f/7358' to 3206'. Ran RFT's (see attached sheet for data). Cont drlg 8-1/2" hole to 7435' TD as of 08/11/83. Ran 187 jts 7" 26# J-55 HF-ERW BTC csg w/shoe @ 7412'. Cmtd 7" csg w/500 sx Class "G". Bumped plug w/2000 psi. Floats held - ok. ND BOPE. NU & tstd FMC wellhead. Secured well & released rig @ 0100 hrs at 08/13/83. HILL/DH37 09/14/83 RFT DATA Depth MD 6883 6902 6913 6920 6919 6974 7089 7106 7105 7123 7205 7203 6903 6876 Formation Pressure, psi 3013 Tight 3022 3030 3024 3041 3083 Mud Tst 3087 3091 Leaked Tight 3021 3014 Hydrostatic Pressure, psi 3182 3184 3186 3189 3188 3217 3275 3276 3271 3279 3320 3315 3180 3169 HILL/DH37 2X-7 COMPLETION SUMMARY RU Dresser-Atlas. Ran CBL/VDL/CCL/GR f/7305'-4640'. Ran Gyro f/7300'- surface. RD Dresser-Atlas. Secured well. Accepted rig @ 1200 hrs, 08/29/83. ND lower tree assembly. NU BOPE & tstd - ok. Ran 3-1/2" completion assy w/tail @ 6789', pkr @ 6758' & SSSV @ 1881' ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesei followed by Kuparuk crude. Dropped ball & set pkr. Installed BPV. Closed SSSV. Secured well & released rig @ 2200 hrs, 08/30/83. NOTE' Well to be perforated by the Production Department using through-tubing perforating guns. GRU4/CS11 Reservoir Fluid Study ARCO OIL & GAS COMPANY Kuparuk River 2X-7 Well Kuparuk Fi eld North Slope, Alaska RFL 830728 Reservoir Fluid Analysis 7501 STEMMONS FREE' 'lOX 47547, DALLAS. TEXAS 75247 · 214/631-8270 January 13, 1984 CORE LABORATORIES, INC, ARCO Oil & Gas Company P.O. Box 2819 Dallas, TX 75221 P. L. Moses Manager Reservoir Fluid Analysis Attention' Mr. Jerry Haley Subject: Reservoir Fluid Study Kuparuk River 2X-7 Well Kuparuk Fi eld North Slope, Alaska RFL 830728 P.O.: 2380463WL Gentlemen' A subsurface fluid sample was collected from the subject well. This sample was submitted to our Dallas laboratory for use in a reservoir fluid study. Presented in the following report are the results of this study. As a quality check, the room temperature saturation pressure of the sample was initially determined. At 70°F., the subsurface fluid sample in cylinder 123744D was found to have a bubble point pressure of 2463 psig. This value was considered to be in good agreement with the reported bubble point of 2483 psi g at 70°F. The study then proceeded as outlined by ARCO Oil & Gas Company. The hydrocarbon composition of the reservoir fluid was determined by low temperature fractional distillation, along with gas chromatography. The results of the distillation, in terms of both mol percent and weight percent, are presented on page two. A small quantity of the reservoir fluid was charged to a high pressure windowed cell and thermally expanded to the reservoir temperature of 160°F. During a constant composition expansion at this temperature, the fluid was found to have a bubble point pressure at 2913 psig. The results of the pressure-volume relation measurements at reservoir temperature may be found on page four. When subjected to differential pressure depletion at the reservoir temperature, the fluid evolved a total of 558 cubic feet of gas at 14.696 psia and 60°F. per barrel of residual oil at 60°F. The resulting relative oil volume factor was 1.277 barrels of saturated fluid per barrel of residual oil at 60°F. The oil density and the properties of the evolved gases were measured at each point during the differential pressure depletion and these data are included in the summary of the differential depletion data on page five. ARCO Oil & Gas Company Kuparuk River 2X-7 Well Page Two The viscosity of the reservoir fluid was measured over a wide range of pressures at 160°F. in a rolling ball viscosimeter. The viscosity of the fluid was found to vary from a minimum of 1.36 centipoises at the saturation pressure to a maximum of 5.67 centipoises at atmospheric pressure. The results of the viscosity measurements are tabulated on page si x. Three separator tests were performed at specified conditions. The results of these separator tests are tabulated on pages seven, nine and eleven. The separator gas and stock tank gas from each of the three tests were collected and analyzed by chromatography. The results of these gas analyses are tabulated on page eight, ten and twelve. Thank you for the opportunity to perform this reservoir fluid study. If you have any questions or if we may be of further assistance in any way, please feel free to call upon us. Very truly you rs, CORE LABORATORIES, INC. James R. Fortner Area Manager Reservoir Fluid Analysis JRF'DK:jb 17 cc' Addressee CORE LABORATORIES, INC. R eservoir Fluid .d nalysis Company Wel 1 Field ARCO Oil & Gas Company Kuparuk River 2X-7 Kuparuk Page i of File RFL 830728 Date Sampled County North Slope 15 State Alaska FORMATION CHARACTERISTICS Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas/Oil Ratio Production Rate Separator Pressure and Temperature Oil Gravity at 60°F. Datum Original Gas Cap PSIG @ PSIG Ft. SCF/Bbl Bbl/Day °F, °API Ft. Subsea WELL CHARACTERISTICS Elevation Total Depth Producing Interval Tubing Size and Depth Productivity Index Last Reservoir Pressure Date Reservoi r Temperature Status of Well Pressure Gauge Normal Production Rate Gas/Oil Ratio Separator Pressure and Temperature Base Pressure Well Making Water In. to Bbl/D/PSI 0 3100 PSIG ~ Ft. Ft. Ft. Ft. Bbl/Day Ft. 160 °F. 0 Ft. PSIG, Bbl/Day SCF/Rbl °F. PSIA % Cut SAMPLING CONDITIONS Sampl ed at ~ F~J ~£$~'~ Ft. Status of Well Gas/Oil Ratio SCF/Bbl Separator Pressure and Temperature PSIG, °F. Tubing Pressure PSIG Casing Pressure PSIG Sampled by ARCO Type Sampler REMARKS: use, this re~oxt is ~tcle. ~ interpretatJa~s or c~JanJz~s expres_~H__ ~eFesent the best ~ucli~ea~ of Ore laboretoriea, Inc. (a. ll m~,~-,~ ~ exceFted); but Corn baboratc~ies, :[nc. and its offioers a~l en~loyees, ass~e no respcns~bJ.l~ty and ~ke no ~awranty or r~m~se~tat~ as to the CORE LABORATORIES, INC. Reservoir Fluid Analysis Page File Wel 1 2 of RFL 830728 15 Kuparuk River 2X-7 HYDROCARBON ANALYSIS OF RESERVOIR FLUID SAMPLE Component Mol Weight Density, °API Molecular Percent Percent Gm/Cc 0 60°F. @ 60°F. Weight Hydrogen Sulfide 0.00 0.00 Carbon Dioxide 0.50 0.17 Nitrogen 0.08 0.02 Methane 40.78 5.15 Ethane 6.29 1.49 Propane 4.45 1.54 iso-Butane 0.81 0.37 n-Butane 2.03 0.93 iso-Pentane 0.75 0.43 n-Pentane 0.90 0.51 Hexanes 2.22 1.50 Heptanes plus 41.19 87.89 100.00 100.00 0.9069 24.4 271 CORE LABORATORIES, INC. Reservoir Fluid Analysis Page File Wel 1 3 of RFL 830728 15 Kuparuk River 2X-7 VOLUMETRIC DATA OF RESERVOIR FLUID SAMPLE Saturation pressure (bubble point pressure) = 2913 PSIG 0 160°F. Specific volume at saturation pressure = 0.02067 ft 3/lb 0 160°F. Thermal expansion 0 5000 PSIG = 1.04696 V 0 160°F./V 0 70°F. Compressibility Fa. 160°F.: From 5000 PSIG to 4500 PSIG = 7.46 x 10-6 V/V/PSI From 4500 PSIG to 4000 PSIG = 8.00 x 10-6 V/V/PSI From 4000 PSIG to 3500 PSIG = 8.50 x 10-6 V/V/PSI From 3500 PSIG to 2913 PSIG = 9.06 x 10-6 V/V/PSI CORE LABORATORIES. INC. Reservoir Fluid Analysis Page 4 of File RFL 830728 15 Well Kuparuk River 2X-7 PRESSURE-VOLUME RELATIONS AT 160°F. (Constant Composition Expansion.) P ressu re, Rel at i ve Y PSI G Vol ume (.1) Functi on (2) 5000 0.9828 4500 0.9865 4000 0.9905 3500 0.9947 3200 0.9973 3100 0.9982 3000 0.9992 2913 Bubble Point 1.0000 2892 1.0016 2876 1.0029 2815 1.0078 2718 1.0164 2514 1.0374 2273 1.0692 2034 1.1111 1782 1.1720 1538 1.2553 1295 1.3781 1052 1.5692 838 1.8420 650 2.2438 480 2.8963 337 3.9580 4.219 4.043 3.861 3.659 3.467 3.267 3.064 2.889 2.736 2.592 2.474 (1) (2) Relative Volume' V/Vsat is barrels at indicated pressure per barrel at saturation pressure. Y Function : (Psat-P) (Pabsl(V/Vsat-l') CORE LABORATORIES, INC. Reservoir lquid A nalysis Page File Well 5 of 15 RFL 830728 Kuparuk River 2X-7 DIFFERENTIAL VAPORIZATION AT 160°F. Solution Relative Relative Oil Deviation Gas Formation Incremental Pressure, Gas/Oi 1 Oi 1 Total Density, Factor, Volume Gas PSIG Ratio(l) Volume(2) Volume(3) Gm/Cc Z Factor(4) Gravity 2913 558 1.277 1.277 0.7750 2700 520 1.263 1.300 0.7796 0.852 0.00550 0.675 2350 457 1.238 1.351 0.7876 0.851 0.00631 0.669 2000 398 1.218 1.430 0.7940 0.856 0.00744 0.667 1700 342 1.19'7 1.538 0.8009 0.867 0.00886 0.666 1350 284 1.175 1.728 0.8083 0.884 0.01134 0.670 1000 224 1.153 2.081 0.8164 0.905. 0.01563 0.679 700 172 1.133 2.697 0.8239 0.928 0.02274 0.695 400 119 1.111 4.264 0.8326 0.955 0.04032 0.736 153 67 1.087 10.044 0.8415 0.982 0.10242 0.878 0 0 1.043 0.8584 1.350 at 60°F. = 1.000 Gravity of Residual Oil = 26.4 °API Fa 60°F. (1) Cubic feet of gas at 0.8951 psia and 60°F. per barrel of residual oil at 60°F. (2) Barrels of oil at indicated pressure and temperature per barrel of residual oil at 60°F. (3) Barrels of oil plus liberated gas at indicated pressure and temperature per barrel of residual oil (4) Cubic feet of gas at indicated pressure and temperature per cubic foot at 14.696 psia and 60°F. at 60°F. These analyses, opinions o~ interpoetatiom~ am based on observations and mate~ial supplied by the client to wh~, and fop ~hose exclusive and oonfidmt~al use, this ~po~t is made. The intea~retations o~ opinic~s exq)ressed ~epresent the best ~udge~ent of Oo~e Laboratories, Inc. (all extols and omissions excepted); b~t Co~e l~bonatories, Inc. and its office~s and employees, ass~e no responsibility and make no wa~anty om mepmsentations as to the prc~um- tivity, p~ope~ operation, or p~ofitableness of any oil, gas'or othe~ minemal well o~ sand in oonnectien with ~hich s~ch ~epo~t ia used o~' ~elied upon. CORE LAEIORATORIE$. INC. Reservoir Fluid Analysis Page File Wel 1 6 of RFL 830728 15 Kuparuk River 2X-7 VISCOSITY DATA AT 160°F. Calculated Oil/Gas Pressure, Oil Viscosity, Gas Viscosity, Viscosity PSIG Centipoise Centipoise Ratio 5000 1.67 4500 1.59 4000 1.52 3500 1.45 3200 1.40 3000 1.37 2913 Bubble Point 1.36 2700 1.45 0.0197 73.6 2350 1.62 0.0182 89.0 2000 1.83 0.0169 108.3 1700 2.02 0.0159 127.0 1350 2.29 0.0149 153.7 1000 2.61 0.0140 186.4 700 2.96 0.0133 222.6 400 3.43 0.0126 272.2 150 4.06 0.0116 350.0 0 5.67 CORE LABORATORIES. INC. Reservoir Fluid ,~ nalysis Page File Wel 1 7 of RFL 830728 ]5 Kuparuk River 2X-7 SEPARATOR TEST OF RESERVOIR FLUID SAMPLE Separator P ressu re, PSIG Gas/Oil Gas/Oil Tank Oil Formation Separator Temp., Ratio Ratio Gravity, Volume Volume Gas °F. (1) (2) oAPI (a 60OF. Factor(3) Factor(4) Gravity 75 100 498 523 to 0 150 37 38 1.050 0.736* 26.5 1.295 1.038 1.419' *Collected and analyzed in the laboratory. (2) (3) (4) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F. per barrel of oil at indicated pressure and temperature. Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F. per barrel of stock tank oil at 60°F. Formation Volume Factor is barrels of saturated oil at 2913 psig and 160°F. per barrel of stock tank oil at 60°F. Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. mFS); ~t ~m ~t~, ~, ~ its off~ ~ ~~, ~ ~ ;~i~ ~ ~ m ~ ~ m~at~ ~ to ~ ~ CORE LABORATORIES. INC. Reservoir Fluid ~tnalysis Page File Wel 1 8 of RFL 830728 15 . .Ku. paruk River 2X-7 HYDROCARBON ANALYSES OF SEPARATOR GAS SAMPLES Component Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus 75 PSIG, lO0°F. 0 PSIG, 150°F. Mol Mol Percent GPM Percent GPM 0.00 0.00 0.81 0.78 0.20 0.00 78.21 25.33 11.16 2.977 ~19.47 5.193 6.08 1.669 25.15 6.903 0.80 0.261 5.06 1.651 1.56 0.491 12.08 3.798 0.34 0.124 3.48 1.270 0.35 0.127 3.81 1.377 0.23 0.094 2.59 1.054 0.26 0.118 2.25 1.019 100.00 5.861 100.00 22.265 Gas gravity (Ai r:l .000): Gross heating value (BTU per cubic foot of dry gas at 14.696 psia and 60°F.): Gas Viscosity: 0.736 1.419 1271 2333 0.0106 0.0094 CORE LABORATORIES. INC. Reservoir Fluid .4 nalysis Page File Wel 1 9 of 15 RFL 830728 Kuparuk River 2X-7 SEPARATOR TEST OF 2000 PSIG DV OIL SAMPLE Separator Pressu re, PSIG 75 to 0 Temp., OF, 100 150 Gas/Oil Gas/Oil Tank Oil Formation Ratio Ratio Gravity, Volume (1) . (2) °API ~ 60°F. Factor(3) 341 360 40 42 26.2 1.245 Separator Vol ume Gas Factor(4) Gravity 1.057 0.761' 1.038 1.358' *Collected and analyzed in the laboratory. (1) Gas/Oil Ratio in cubic feet of gas at at indicated pressure and temperature (2) Gas/Oil Ratio in cubic feet of gas at tank oil at 60°F. (3) Formation Volume Factor is barrels of per barrel of stock tank oil at 60°F. (4) Separator Volume Factor is barrels of 14.696 psia and 60°F. per barrel of oil 14.696 psia and 60°F. per barrel of stock saturated oil at 2000 psig and 160°F. oil at indicated pressure and temperature- per barrel of stock tank oil at 60°F. analyses, op~ ~); ~t ~m CORE LABORATORIES. INC. Reservoir Fluid Analysis Page File Wel 1 10 of RFL 830728 15 Kuparuk River 2X-7 HYDROCARBON ANALYSES OF SEPARATOR GAS SAMPLES Component Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus 75 PSIG, IO0°F. Mol Percent GPM 0 PSIG, 150°F. Mol Percent GPM 0.00 0.00 1.01 0.84 0.09 0.00 75.25 25.67 12.80 3.414 21.05 6.90 1.894 26.67 0.89 0.290 5.19 1.74 0.547 11.71 0.37 0.135 3.11 0.39 0.141 3.11 0.26 0.106 1.63 0.30 0.136 1.02 5.615 7.320 1.693 3.682 1.135 1.124 0.663 O. 462 100.00 6.663 100.00 21.694 Gas gravity (Ai r=l. 000): Gross heating value (BTU per cubic foot of dry gas at 14.696 psia and 60°F.): Gas Viscosity: 0.761 1.358 1306 2237 0.0106 0.0095 use, this l, epoz-t is ,aaa,. 'l"he ~ntp_rl~tatic~ c~ opird~ ~~ ~t ~ ~ j~ ~ ~ ~t~, ~. (~1 ~=~6 ~ ~~ e~); ~t ~ ~t~, ~. ~ its off~ ~ ~1~, ~ ~ ~~ ~ ~ ~ ~ ~ ~~t~ ~ to ~ ~ CORE LABORATORIES. INC. Reservoir Fluid Analysis Page File Wel 1 11 of 15 RFL 830728 Kuparuk River 2X-7 SEPARATOR TEST OF 1000 PSIG DV OIL SAMPLE Separator Pressure, PSIG Temp., OF. Gas/Oil Gas/Oil Tank Oil Formation Ratio Ratio Gravity, Volume (1) (2) oAPI (a 60OF. Factor(3) 75 100 168 176 to 0 150 49 51 Separator Vol ume Factor(a) 1.047 Gas Gravity 0.797* 26.9 1.162 1.038 1.430' *Collected and analyzed in the laboratory. (1) Gas/Oil Ratio in cu at indicated pressu (2) Gas/Oil Ratio in cu tank oil at 60°F. (3) Formation Volume Fa per barrel of stock (4) Separator Volume Fa bic feet of gas at 14.696 psia and 60°F. per barrel of oil re and temperature. bic feet of gas at 14.696 psia and 60°F. per barrel of stock ctor is barrels of saturated oil at 1000 psig and 160°F. tank oil at 60°F. ctor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. e~); ~t ~m ~t~i~, ~. ~ its off~ ~ ~~, ~ ~ ~~ ~ ~ ~_~ ~ m~t~ ~ t~.~ ~ CORE LABORATORIES. INC. Reservoir Fluid Analysis Page 12 of File RFL 830728 15 Well Kuparuk River 2X-7 HYDROCARBON ANALYSES OF SEPARATOR GAS SAMPLES Component Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane i so-Pentane n-Pentane Hexanes Heptanes plus 75 PSIG, IO0°F. Mol Percent GPM 0 PSIG, 150°F. Mol Percent GPM 0.00 0.00 1.22 0.80 0.12 0.00 69.77 19.73 16.43 4.383 23.21 8.35 2.292 28.63 0.99 0.323 5.29 1.84 0.579 12.05 0.38 0.139 3.21 0.37 0.134 3.36 0.24 0.098 2.04 0.29 0.131 1.68 100.00 8.079 100.00 6.191 7.858 1.726 3.788 1.172 1.214 0.830 0.761 23.540 Gas gravity (Ai r=l .000): Gross heating value (BTU per cubic foot of dry gas at 14.696 psia and 60°F.): Gas Viscosity: 0.797 1.430 1355 235O 0.0104 0.0094 _._~. CORE LABORATORIES, INC. '~-~ Page , 13 of 1,5 Petroleum Reservoir Engineering ' DALLAS, TEXAS File RFL 830728 DIFFERENTIAL VAPORIZATION OF RESERVOIR FLUID AT 160°Fo 1000 Company Well Field ARCO OIL & GAS COMPANY KUPARUK RIVER 2X-7 KUPARUK Formation Coumy NORTH SLOPE Stme ALASKA 9O0 800 700 600 500 400 300 200 100 0 0 lOO0 2000 PRESSURE' PSIG 3OOO 4000 1.50 1.45 1.40 1.35 "-1.30 1.25 1.20 1.15 1.10 1.05 1.00 CORE LABORATORIES, INC. Petroleum Reserooir Engineering DALLAS, TEXAS Page 14 of 15 File RFL 830728 DIFFERENTIAL VAPORIZATION OF RESERVOIR FLUID AT 160°F. Company ARCO OIL & GAS COMPANY Formation Well KUPARUK RIVER 2X-7 Co=nb/ NORTH SLOPE Field KUPARU K State ALASKA ~1 I! IIII !1 I! III I II II Ii II I I II III ii I I I I I1 I1 I I ! Ii I !11 I! III I ! I IIII I III I II II I I II II I I I I I I I I i I I I I I II I ,.],1,,,,,,,,,,,, IIIIIIIiIIIIII~,~I IIllllllllillll! 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':::. '" · ,"'~, , :~ '' ~ ~'""~: , · :~:j:~ii::::::::::~:.::~"..:~:~`~{:..:~`:.t?'~''~::.~?;:~'~.:.~h!:]:!~:~.{.{::.~$:::~:..:.!: ......... ~3~::i:~?..~(~:::::::::::?!.i:~:~v'~]r:!f!hil. ;:h!.. ' ' '::,u:::"::':~':; :::'].i:.i: i.:! ': :: ::] i:: . ':.:.. "::'i.:] ! :'. ". ,; '] :[":.::'::':: ::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ' :":':::':: ".':': .:" ::!':' :""i: '"' :: :':: 'u:" ':" ,':"' . :. · :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ...... ::': :.:~,?~::::"..':'.-~.':!i!:!:!:!.:?' 7:~!: ..::.::::':.::,": :::::::::::::::::::::: :..': .~?./~ . : ~..:. :,. :::::::::::::::::::::::::::::::::::::::::::: :~::.:Z:~"~L~.:,:. /~.~%/~'~J,~,~'-~/~..~,~"'~,'l'.~,~:=,~l:l ~;~:~::' '..... ::.<: . ~::::-::~':;~-:~::~.:-~'.:~:.::~,~=~ ....................... :--:~ ................................. ~'x ........................................................... :~,~~~~~" ~.~ ~,,,,~,.~.~,, , ~. ~~~E~ ............. ~ ...... , ..... ~ ~ · . _ ..... KUPARLIK ~ ' ..... AUGUST ~6, 1~8a dob NUMBER AK-Bu-~oo. ~ ALASKA ~ KELLY BUSHING ELEV. = 106.00 FT. ~,:~,~',','.'.','m~'~.:.;,~'-' ,,':,~,'~'..:.': '.:-..:..,'. ~'"'.:"~ ............ ~i~;~ ................ ~ ~n ~-~i~ ~'~"~1 ~w~ ~B~ ~ I ~ I ~ MEASURED VERT ICAE VERT ICAE INCLINATION DIRECTION SEVER I TY RECTANGULAR COORD INATE8 VERT ICAE DEPTH DEPTH DEPTH DEG , MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST SECTION 300 299.~ ',1~3.~ 0 2~ S 5.~ W 0.03 1.85 S 0.01 E -0.47 400 3~.~ 2~3.~ 0 10 S 20.10 E 0.2~ 2.38 S 0.03 E -0.~1 900 899.9~ 79:3.99 0 ~ N ~1.3~ E 0.12 2.98 S 0.81 E -1.52 1000 999.98 893.98 I 2 N 79.19 W 1.12 2.77 8 0.01 W -0.67 [~J~J~:~:~:~[~ J~ [~j~ ?:~~~?"'"::"'":~j~~~~~nc~T.' .. ............ : n r.':~~?. :~::~,:~:'.'~i~j~[:~:::~..~[~/:~[j[~'u rn:~u:~u::'~[~ ]~ ?.~? ':? ~.~:~[~"'¥""~:?.: ~:%::'.[:::.~[::f:~:~:~:~:[:~??~i~[~:~':~':[?'<'?.?j~'.?' ¥.~[:~::[?~:~[~?~[~?~[::~:/:[~?::~::~[::[:~]~]~?`..~:~??.:.~~:: ........................... :::~J::?:~ ::]~?.:?~??~¢~:~::~:~¢~ .............. . : '.., :~.' . .......... .... " .............. :~ : ~.: '.::~u~q..~.:.~;~::: ~f~:::]".' .~.. ~ ............ .~ . :..,~, '::.: . ~ ' 1500 14e~.58 1888.53 1~ 21 N 7~.10 H 8.1~ 10.~73 N es.~e w 88.94 ~ 1600 1582.69 1476.69 23 11 N 77.19 W 3.90 18.43 N 124.48 W 125.19 ............................................ .......................... ........... ................. , ......................... ..., ......................... ..................................................... .............................. ............... . 2100 2025.08 1Dl~.08 33 25 N 76.10 W 2.01 72.42 N 349.21 W 356.29 2200 2107.01 2001.01 3~ 31 N 74,69 W 3.20 86.8'~ N 404.66 W 413.60 2700 2486, 76 2380.76 41 . 53 N 71,,80 W 0.46 178. ~2 N 716.27 W 738.27 2800 ~ 2561.08 2455.08 '42 5 N 71.~ W 0,20 1~. 88 N 779.81 W 805.02 ::~:: ~ :::::::::::::::::::::::::::::::::::: :::: ::::: ::::::::::::::: :::::::::: :::::::::::::::::::::::::: ~?:::~:: ::: ::::::::::??:i: ~:~ ::: :~::~:::: ::~? ::~ ::::::::::::::::::::: ::::::::::::::: :::%:::::~ ::::::::::::::::::::::::: ::: ~:~:::~: ::::::::::::::::::::::::::: :::?:::: :::::~::::: :::::::::::::::::::::::::: ::::::::::::::::::::: :~: ~::::::~: :::::: ::::::::~ :::: :::::::::::::::::::::::::::::::::::::::::: :::::::: ::::::::::::::::::::::::: ::::::::::::::~ ::?:: ::::::::::::::::::::::::: ::::::::::::::::::::: ::::: :~ ~:~:::: :::::J::::: :::::::::::::::::: :?:::: :: ?:? ::::::: :: ::::':::::': :::::::'::::: :::::::::::::::::::::::::: ::::: '::::::':: :: ::~:::~:::::: :': ::":::::' ' :: :.:::::?.:: .: :? :::::.:: ..:. :::::. :..:?::: .:: :::::... ::: ?.:::::j :.:, ::::::::::::::::::::::::::::: .:: ::...: :,:.:::..::.:.:::: ?::?::::.: :::::::::::::::::::::::::::::::::::::::::::::::::: ?::::::::::.:.:. ..... :..:: . : 0 KUPARUK ~..-,._ ~.j? ~ AUGUST 26, 1983 dOB NUMBER AK-BO-300~ KELLY BUSHING ELEV. = 106.00 FT. MEASURED VERTICAL VERTICAL INCLINATION OIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH OEG MIN DEGREES DEG/100 NO~TH/SOUTH EAST/WEST SECTION ...:. ~ . ~nA ~.::~::~.~;<~..:::~]~..:::..~'~::,.~:~l.~.:~:~.~ ........................................ .'~: ~ ................ _ ........... ., ~- ....... , - .~- . ~,4 N 1100 38 W 1141 97 ~L~O0 292~.61 2823.61 43 52 N 71 50 W 0.91 306. = - · 3400 3001.9~ 2895.9~ 43 22 N 71. 0 W 0.60 328.72 N 1165.71 W 1210.75 .......................... . ................................. . ................................... ~.~:~ ................. ~:~::. ...................... ........................ ~ ............... ~ ..................................... ~ .......... , .................................... ~ .......... ,.,.,.:,:,,~. ::::, ........................ ..: .......... ~ .... , .............. .::,::, :...~, :, 3~00 3374.23 3268.23 42 9 N 84.50 H 1.44 408. ~0 N 1488.16 W 1543.01 4000 3448.52 3342.52 41 53 N 84. 0 W 0.43 ' 415.61 N 1554.77 W 160~.2.'3 '. 4500 3825.41 ~71~.41 3~ 57 N 82. 0 W 0.83 455.~1 N 1880.84 W 1935.12 4600 3~02.31 37~6.31 ~, 3~ 30 N 81 , 8~ W O. 4~ 4~4.56 N 1~44.13 W 19'~8.67 ......................................... ~': .......... :'~:'::~':'~: ':::~.' ............ ....... ~ ......... ~' ................. ~::'""~"~~;~:'.'~:?""":~:~ :" '~"~:~:' ~:"~::' ~'~:~! ~~:'~':~0~::~ ~ ~ :~:~ ~:~:~"~':~'~:?'~'.:'~?, ~'.~'.':~'"'." ': ..... ~:' ..... :'~ '.: ~'.~"?~ ~ :~. ':~:~:. ' .... ~'.~?~7:~ ~:'-~ ........ ~..'~'.N:.Sl'.:~:'.~:~'.~'~:'.~'::'.:~: ~: ~::~.'.'~:~:~:~ ........ ::~.~.~:.~:~:'. ~ .~. ' ................................. "::::::~ 0 .......... .......... ~0~8":~ ....................... .:~,.:~:~':~: ................... ......... '. .............. '". ........ :::':.'.. ..... ................ ~: ............ ::~::':~.::' ......................................... ':::' ..................................... :~ .......................... '. ............. ~"~:...:.' ::~ :.~.~::~;::%:~:':~i',~":'""':~':~:.::?:~:.~::~:~:.~::?:?~:::?:?~S:::' ................ ~ ......................... 8..~ ..................................... ~ .............. ~:..~ ........................................................ ~ ~ .......... ~ ....................... :~'.:. ~;'~::2..:'.' ........................ ' ..... ~,:~,:, ................................... ~ ............................................ ~ ~ ~ .......................... ~'t,..~..'1 ......................................... ~..oe ........................ . :~:,.~ .................... .::~o.~.~:,::~ ........................... ~:~ ......... ...:~:. ......... .::::~:~:.~,:~ ...... ~:..,~ ......... ~ .......................................................................... : .......................... . .......... :.. ......... ~ ............. .. '.~i~:!~:i~i~i!~i~]~ip,:', ~: :',:'.i:~:i:~,]:~:~:~ ~ ~ [J ::::::::::::::::::::::::::::::::::::::::: ~:'~':':~ ":'~:'":'~:' ~ """?"' ""'"'"'"~"' ~' . .... :~ '= 5100 4297.00 4191.00 36 55' N 80.60 W 0.24 510.99 N .2247.45 W 2304.10 5200 4377.12 4271.12 36 34 N 7~.80 W 0.59 521.18 N ' 2306.42 W 2363.76 ......... ~ .................. ':.':' ......... ' .... .............................. ':':: ........................ "~::':: ~ ................... ~ ~,. ~...H ................... ..... ,,::: ~ .............. :.:::. .............. , ..................................... ,,;~ .......................... ~.~ ,..~..::::H ........ ~ ............. ~ .......... ~ ............................... , .............. · ..... ;,: ........ ........ ~ ~..:.~..: ....... N .:~.~, .... O....H ................................ ~ ......................................................................................................................... ., ....................................... .............. 5700 4785.4~ 467~.49 33 52 N 78.19 W 0.4~ 576.14 N 2589.53 W 2651.69 5800 486~.03 4763.03 32 48 N 77..50 W 1.14 587.71 N~ 2643.26 W 2706.62 © 0 KUPARUK AUGUST 26, 1983 dOB NUMBER AK-BO-30096 ALASKA KELLY BUSHING ELEV. = 106.00 FT. MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEO MIN DEGREES DEO/100 NORTH/SOUTH EAST/WEST SECT I ON 6300 5296.52 5190.52 29 40 N ~'1.89 W 1.38 ~52.40 N 2894.15 W 2'~65.71 6400 5S83,77 5277.77 ~8 48 N 70. lO W i.23 668.29 N 2940. S3 N S0~4.38 .6900 5832.44 5726.44 ~6 10 . N 66.10 W 1. o6 750.75 N 3144, 63 W 3232.69 7000 5921 63 5815.63 27 ~5 N 66.1'9 W 1 42 769 03 N 3185.98 W 3277 . . ~ ~ . .~ ~ ~ ~, ,~ ] .~.'~ .-~.-,.~ :'+~-:.:'.',,'..:.X..,,,..,,,,'.'.,,,:v.'.',",',".".".'.,,,'..,', ...... '..,'....~,b,X',.,.,' '.'..-'.','.'..:,,..'.'~,'..,',,,,,.:,,~ ...... :,.,X,~',' .... ~X;'.:,',~''",'~' ' ', '~+:<'>?: '"'' ' · +' .............. · ............... : ..... "'"-' ''"""'"'-: ......... :''"':'""" '"" '"":"" ..... ' ....... :': .......... '"':'" ........ :''"": ......... '. '".'"''"':' ' '~"' · ' ;,.~ :]: x ,, ::.: ,. :: ,. ,,:: ,, :.:,~: ::,, ,,:: ,,. :: ,,.:x:..,v,<,:: :~ .'.: ,,, x:: :;v, :: :: ::,.::::I: ;,.x ::,,: :,.x:,r:::t x p.: ~: :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~t: 7435 62')4, 45 6188.45 32 31 N 65,60 W O. Ob 85~. '~4 N 33t~0, 42 N 34~7, 78 C"') O © O KUPARUK AUGUST 26, 1983 dOB NUMBER AK-BO-30096 , ALASKA KELLY BUSHING ELEV. = 106.00 FT. :::::::::::::::::::::::::::::::::::::::::: :::: ::::::::::::::::::.. ,. x,.x,,::.x.:,.:,:.~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.:~:::x:: ~.:;:::::::.:...~ .:x? ...' :':..;:~:::~:~.lx.:.)~.::.:~C~:~:~...~::::~:~:~:m::~:~:::L::::~:::>:~>~l:~:~lll~l~)~(~:~lx.~l~:F~;~::~ .'T: ~:i~:~ 2:i~i~::~'~'?:~:ii!L~.::':~'~i~:!?xi:~.x?., .. :" '?: .~':~ ..::~'~! '.' -: ~ ~.:f :-. : .. · . TRUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES , MD-TVD VERT I CAL 2000 1940.67 1834.67 59.46 N 297.20 W 59.33 59.31 3000 270'B. 71 2~03.71 241 . 45 N ~07.01 W 290.29 230.96 .... . ......... ~~~C~::.::::.: .......................................... s ........................................................... .:::::::: ............... . .............. 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E:ii~iSi !i!!]~!i! D=i~i i iiDii!!Si?.i:]i! iS= i Si~iF]~!+E!i!!%DF i li:S~i!?iSS!ilS:,!ii?,il:,i i!iiS:= =E!i: i i i i iii: i j?i il i= i:iiiiS!iE !S!c~! :S !:i:iE!E '.!i Y, lis!iLi:] S:,!?iEL: iS i!i= i=~J~i]: !".~ ~: .. :: DERIVED US INi] D IL DEPTHS AND SPERRY SUN SURVEY DATA TO~ UPPER ,S~ND 6~70 5805.52 5699..52 745.39N 3132.54W .~~~ ~,~'E~ ~n~n : A ~ ~87~_ A2 s~A~ A~-, : ...... 7~~N~~.~'~'.. ]~:::::~:' :,':::],,] ' E:E::: ':~ ':.:: .. ' ::?~ ';' ';: ..... h::~EEEE~E}]~]~EE:E~EEEH~ ~'"':F ~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ':;:~" 'h:::::~'~ ~:h:~:~:::J,:: ":.: :,"~:" "]:::::"~'::'"': :~: : ::::::: ::',E ::: '::::: : : : E: :::' ":"':;.':',:: :: .::' '.::' .: . ~.~ ~:': TOT~L DEPTH 7435 &294.45 61SS. 45 ~o~.'~ ~'~ 94N ~'~""- 'o ~¢.]. 42H Suggested form to he inserted in each "Active" well folder to check for timely compliance with our regulations. ' 'Operatdr,' ~1 i'~a~ and N'6mber f Reports and Materials to 'be received by: ~--~ Date Required Date Received Remarks ,. Cc~-rrp le~2.on Report Yes S~les ~ -, ~'~,, . Core ~scrip~on . __Registered ~ey Plat Inclination S~ey Drill St~ Test Re~s Pr~u~ion T~t Re~rts ,.,.., ..... ~. . .:..,:, 1~ - 1.5,.- ¢:~._..g ARCO Alaska, Inc Post Office~-m3~'~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Hr. C. V. Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Commission Attached are notices of intention to perforate the following wells in the Kuparuk "A" sand: 2X-1 2X-2 2X-3 2X-6 2X-7 If you have any questions, please call me at 263-4527. harles K. House uparuk Operations Coordinator CKH/kmc At%achment (In Triplicate) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA"OI~L AND GAS CONSERVATION C~'I~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 450' FSL, 601' FEL, SEC. 4, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 106' (RKB), PAD 77' 12. 7. Permit No. 83-113 8. APl Number 50- 029-20991 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 2X-7 1 1. Field and Pool KUPARUK RIVER I 6. Lease Designation and Serial No. KU P A R U K ADL 25645, ALK 2576 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD RIVER OIL NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate X~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly stal~e all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate the following depths in the Kuparuk Sand' 7083-7093' and 7105-7135' All perforating will be conducted with 4 SPF through-tubing guns. ~ 3000 psi lubricator will be used on all wireline work. Lubricator will be pressure tested prior to doing the work. All circulated and flowed fluids will be diverted to tankage on location. Expected start date' 14' I hereb/~7~e f~~and c°rrect t° the best °f mY kn°wledge'KUPARUK Signed (,/'~' ¥,~'- ~ ' - Title OPERATIONS The space below for Commission use COORDINATOR Date Conditions of Approval, if any: Approved by ,,.kpproved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 11, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-7 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/GRU4L95'tw Enclosure If Oil & G~s Corm. OommL~io~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ..__~_ AND GAS CONSERVATION C(.._.,~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-113 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20991 4.,.Location of Well Surface: 450' FSL, 601' FEL, Sec.4, TllN, R9E, UN 5. Elevationinfeet(indicate KB, DF, etc.) 106' RKB 6. Lease Designation and Serial No. ADL 25645 ALK 2576 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2X-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). RU Dresser - Atlas. Ran CBL/VDL/GR/CCL f/7305' - 4640'. Ran Gyro f/7300' - surface. RD Dresser - Atlas. Secured well. Accepted rig 8 1200 hfs, 08/29/83. ND lower tree assembly. NU BOPE & tstd - ok. Ran 3-1/2" completion assembly w/tail @ 6789', pkr ~ 6758' & SSSV ~ 1881'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel followed by Kuparuk crude. Dropped ball & set pkr. Installed BPV. Closed SSSV. Secured well & released rig @ 2200 hfs, 08/30/83. NOTE: Well to be perforated by the Production Department using through-tubing perforating guns. OCT t 3 ,~,,~ Alaska 0il & 6as Cons. Anct~0rage 14. I hereby cer~fy that the foregoing is true and correct to the best of my knowledge. Signed Title ^rea Dri 1 1 ing Engi neet ~o~m ission use Conditio al, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU4/SN50 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 'ARCO Alaska, ~' Post Oh,--.. 'lox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State 2X-3 2X-4 2X-6 2X-7 Commi ssion Thank you. Sincerely, P. A. VanDusen District Drilling Engineer PAV/SH9:sm EncloSures Reports 2X-8 2C-5 tG-9 1G-10 for the following wells: ARCO Alaska, Inc. Is a Subsidiary of Allanti{:RichfieldCompany · STATE OF ALASKA ~LASK/~....,IL AND GAS CONSERVATION C~.)IMISSION ' MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONSd i 1. Drilling well []~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-113 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 029-20991 50- 9. Unit or Lease Name 450' FSL, 601' FEL, Sec. 4, T11N, R9E, UN Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 77' 106' RKB I6. Lease Designation and Serial No. ADL 25645 ALK 2576 10. Well No. 2X-7 11. Field and Pool Kuparuk River Fie]d Kuparuk River 0it Pool August 83 For the Month of. ,19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ~ Spudded well @ 0300 hfs, 08/04/83. Drld 12-1/4" hole to 3237'. Ran, cmtd, & tstd 9,5/8" csg. Performed top job. Drld 8-1/2" hole to 7365'. Ran logs, ran RFT. Cont drlg · 8-1/2" hole to 7435' TD. Ran, cmtd, & tstd 7" csg. Secured well & released rig ~ 0100 hfs on 08/13/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40# J-55 HF-ERW BTC csg w/shoe ~ 3207'. Cmtd w/1500 sx AS III 7" 26# J-55 HF-ERW BTC csg w/shoe L~ 7412'. Cmtd w/500 sx Class "G". & 250 sx AS I. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/Cal f/7356' to 3206' FDC/CNL/GR/SP f/7330' to 3206' BHCS/GR f/7358' to 3206' Ran RFT (see attached Drlg History) 16. 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. SIGN ED ~ _ ,-, * _ _ . TITLE DATE 'be filed in duplicate with the Alaska NOTE--R~uired for each ca!endar month, regardless of the status of operations, and must 'f Oil and G~~ sion by the 15th of the succeeding month, unless otherwise directed. Form 10-404 v H I L L/MR57 Submit in duplicate 2X-7 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0300 hrs, 08/04/83. Drld 12-1/4" hole to 3237'. Circ and cond hole. Ran 82 jts 9-5/8" 40# J-55 HF-ERW BTC csg w/shoe @ 3207'. Cmtd 9-5/8" csg w/1500 sx AS III & 250 sx AS I. Bumped plug w/2000 psi - floats held - ok. ND 20" Hydril & diverter. Performed top job w/75 sx AS I. Instld FMC wellhead. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt, FS & 10' new form. Tstd form to 11.9 ppg EMW - ok. Drld 8-1/2" hole to 7365'. Ran Cal/DIL/SFL/GR f/7356' to 3206'; FDC/CNL/GR/SP f/7330' to 3206'; BHCS/GR f/7358' to 3206'. Ran RFT's (see attached sheet for data). Cont drlg 8-1/2" hole to 7435' TD as of 08/11/83. Ran 187 jts 7" 26# J-55 HF-ERW BTC csg w/shoe @ 7412'. Cmtd 7" csg w/500 sx Class "G". Bumped plug w/2000 psi. Floats held - ok. ND BOPE. NU & tstd FMC wellhead. Secured well & released rig @ 0100 hrs at 08/13/83. HILL/DH37 09/14/83 RFT DATA Depth MD 6883 6902 6913 6920 6919 6974 7089 7106 7105 7123 7205 7203 6903 6876 Formation Pressure, psi 3013 Tight 3022 3030 3024 3041 3083 Mud Tst 3087 3091 Leaked Tight 3021 3014 Hydrostatic Pressure, psi 3182 3184 3186 3189 3188 3217 3275 3276 3271 3279 3320 3315 3180 3169 HILL/DH37 KIJP>~JK EikE; ! NEERI ~ TO: William VanAlen ~: D.W. Bose/Shelby J. Matthews DATE: ' , Y'¢:~-¢,,~ $¥ELL N/:~/~E- ~X 7 Transmitted herewith are the fo l I owing- PLEASE ROLE: BL - BLUELINE, S - SEPIA, F - FILM, T~--~ - Pt-E)TEX3DPY MEMORANDUM Statb of Alaska ~.~.ASKA OIL AND -GAS CONSERVATION COMMISSION TO: C.~~at:terton DATE: August 10, 1983 TELEPHONE NO: TI{RU: Lonnie C. Smith/~- Corn mi s s ione r Edgar W. Sipple, Jr Petroleum Inspector FROM: SUBJECT: Witness BOPE Test on ARCO's Kuparuk 2X-7 Sec 4,TiLN,R9E, U~4 Permit ~. 83-113 Parker Drilling Rig 141. saturday August 6, 1983: I left Doyon Rig 9 (subjeCt of another report) and. traveled to ARCC Kuparuk 2X-7, Parker Drilling Rig 141. The drilling contractor was in the process of running casing. The BOPE test commenced at 7~ 05 pm and ~s concluded at 8:20 pm. There were no failures. I filled out the A.O.G.C.C. BOPE Inspection Report which is attached to this report. In. sum. mary, I witnessed the BOPE test on ARCO's Kuparu2{ 2X-7, Parker Drilling Rig 141. Attachment 02-O01AfRev. 10/79) o~ ~ 4 4/8o STATE OP AI,ASKA ALASKA OIL & CAS CONSE}~VATION COHHISSION B.O.P.E. Inst)cction Report Well ~ Xu.~_ Representative 6#4flE,~ ~S ~er~ , rS--II 3 _~ Casing Set e 3~-~7 ft. 'Representativ- ~8 ~¢~¢ Location, General Well Sign General Housekeeping. Reserve pit Rig ,0 ~_ BOPE Stack Test Pres sure ACCUtlULATOR S'YS Full Charge Pressu Pressure After Cio T re, ~1 SO ps.ig sure /~ psig 200 psig Above Precharge Attained: I rain /~sec Full, Charge Pressure At.~ined: ~ min~s'I Cqntrols: Master ..... ~o=~:~._~ Blinds switch cover Kelly and Floor Safety ValVes- o~ ~ y Pipe Rams Blind R~s ChOg~e L~in~e V al v es H.C..R~ V~lve ~ilf ~ine 9aiVes ~ck Valve ~per ~ellY ~)~ Test Pressure LoWer Kelly~ ~ Test Pressure Ball Type ~ ~' Test Pressure Inside BOP ~'' O~ Test Pressure Choke HanifOld Test PresSure No. Valves ~ NO. flanges Adjustable Chokes tlydrauically operated choke ~" ~r, Test Results: Failures '-~) Test Time Repair or Replacement of failed equipment to be made within . a Inspector/Commission office notified. · Remarks, 'W~u~ ~ ~ C~_ .~[~ ' "' Distribution orig' - AO&GCC cc - Operator cc - Supervisor / .... ARCO Alaska, Inc. Post Office "~,,~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 28, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commiss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2X- 7 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on August 25, 1983, your earliest appr. oval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kewin Area Drilling Engineer JBK/JG: tw E~c[osures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK~OIL AND GAS CONSERVATION ~-OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER ,~[]X 2. Name of Operator 7. Permit N°. ARCO Alaska, Inc. 83-113 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20991 4. Location of Well Surface: 450' FSL, 601' FEL, Sec. 4, TllN, RgE, UM 5. Elevationinfeet(indicate KB, DF, etc.) 106' RKB 12. 6. Lease Designation and Serial No. ADL 25645 ALK 2576 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2X-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~X Pulling Tubing [] (Note: Report multiple completions on Form 10.407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1, The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/V~L/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1~", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: August 25, 1983 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~"'~"° ~~ ~i~l,,''~~ Title Area Drilling Engineer Date ~'/' ~I~-(~ --~ The space below for Commission use Conditions of Approval, if any: Approved by ORIGINAL SIGNED BY I. ONHIE G. SMITH Returned By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 ..... GRU4/SN1 July 26, 1983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2X-7 ARCO Alaska, Inc. Permit No. 83-113 Sur. Loc. 450'FSL, 601'FEL, Sec. 4, TIlN, R9E, Btmhole Loc. 1384'FSL, 1081'~L, Sec. 4, Ti1N, R9E, Dear Mr. Kewin~ Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well 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. M~ny 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 co~encing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the re.~ulations promulgated thereunder (Title 18, Alaska Administrativ'~ Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contact.ed by a representative of the Department of Enviromnentat Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of tlle blowout Mr. Jeffrey B. K~in Kuparuk River Unit 2X-7 July 26,. 1983 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. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give .this office adequate advance notification so that we may have a witness present. ~.~Vtruly~ Y°u-r~i~' ~ / Chairman of Alaska Oil and Gas Conservation Commission be, 6:H/A Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~_~,i00360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 14, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2X-7 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2X-7, along with a $100 application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. A diagram and description of the surface hole diverter system. ° Diagrams and description of the BOP equipment. Since we estimate spudding this well on August 1, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A~~Engineer JBK/GRU3L77: sm Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 0TL AND GAS CONSERVATION COY~VIlSSION P£RMIT TO DRILL 2O AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~0( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 450' FSL, 601' FEL, Sec. 4, T11N, RgE, UM ~ Target: 1320~ FSL~ 1320' F~L~ Sec. ~ T11N~ At total depth 1384' FSL, 1081' FWL, Sec. 4, T11N, R9E, UN 9. Unit or lease name Kuparuk River Unit 10. Well number 2X-7 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial n~;:~ RKB 106', PAD 77' I ADL 25645 ALK 2576 12. Bond information (see 20 AAC 25.025) I-ederal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 32 mi. NW of Deadhorse miles 4679' FWL @ Surface feet 17. Number of acres in lease fe~.t 2560 20. Anticipated pressures 2624 MAXIMUM HOLE ANGLE :39 o (see 20AAC25.035(c) (2) :3104 16. Proposed depth (MD & TVD) 7520' MD, 6253' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1000 feet. 21 15. Distance to nearest drilling or completed 2~(-6 well 60' ~ surface feet 18. Approximate spud date ~ 08/0118:3 psig@ 60°F Surface psig@ 6098 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE I Hole 2-114" 8-1/2" 7" Casing 6" 9-5/8" CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Weight Grade Couplir g Length / MD TOP - TV~D:MD BO~-~TOM TVD (include sta-~~e d~ta~-- 65.5# H-40 PEB I 80' 29' I 29' I 109'1 109' ± 200 cf 40.0# J-55 BTC I 3097' 29' 29' I 3126'I12843' 1000 sx AS ill & HF-ERW I ' J I 250 sx AS I 26# BTC I 7 92, I I 28, / 248 HF-ERW ,: ~ ~1 ~ II , proposes to dri 1 a Ku)aruk River Field development well to approximately 7520' MD (6253' ARCO Aiaska, inc TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2624 psig. Pressure calculations are based on latest reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported.on subsequent reports. A downhole safety valve will be installed and tested upon comple- tion of the job. 2X-Pwill be 60' away from 2X-7 @ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed @ 5934' MD, approx. 1000' MD above the Kuparuk sands. Reserve pit fluid will be disposed down the 9-5/8" x 7" annulus of this well. The 9-5/8" x 7" annulus ~vil] be left w~ a non-freezing fiuid during any i~rruption i-n the disposal process. // Th e space bel ~/~r~o~m/on use v - - /- CONDITIONS OF APPROVAL Samples required Mud log required []YES >~,NO []YES ~NO Permit number Approval date Directional Survey required APl number ,~ES ~NO 5o-~. - ZOq~_ l SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 26, 1983 by order of the Commission Submit in triplicate , · · 400 300 500._ ~ 400 - 1702 200 ALASKA. I:NC. 2X, ~.~ WELl..-;NO' :i$-6-7--8 :PROPOSED KUPARUK FIELD,: .NORTH .SLOPE..-ALASKA EASTMAN WHIPSTOCK. INC. NOTE, WELL PATHS EXTEND BEYOND ......... THIS VIEWIN8 WINDOW 1455 300 ............................... 127'7 .......... _ 200 ..... ' ....- ...... ,.:_ .-._~_-: .......... '__ . .... 21 2041 ............................ 1955 . 1 O0 - - irt? -. _ - _ · · -' ~ .... i'. '-~ '~4~ ........ ~ .............. / .................. 300 ;~00 Surface Oiverter S,vs~em · 1. 16" - 2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lO" side outl ets. 5· 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automat'ically upon closure of annular preventer. 20" 2000 psi annular'preventer. 20" bell ni'pple. · Maintenance & Operation 1. Upon initial ins%allation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines 'every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor imm ANNULAR PREVENTER BLIND RAMS 8 PIPE RAMS 7 DRILLING I ,i C' PIPE ~.AMS f D[AGRAM .-.'1 13-5/8" SO00 PS! RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" o 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" - 5000 psi pipe rams 6. 13-5/8" o 5000 psi drilling spool w/choke and kill lines 13-5/8" - 5000 psi pipe rams 8. 13-5/8' - $000 psi blind rams 9. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACIl~f TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1S00 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORO ON ~LAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME ANO 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. ,CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- FO. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT ANO' SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAl). 3. CLOSE ANNULAR PREVENTER AND CtIOKES AND BYPASS VALVES ON MANIFOLO. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM' OF VALVE AND ZERO PSI DOWNSTREAM. BLEEO SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 11. lZ. ~3. 16. MINUTES BLEEO TO ZERO PSI. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT ANO PULL OUT OF HOLE. CLOSE BLINO RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCICS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN ANO SENO TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. ANNULAR ] "'~ PREVENTER ! ) BLIND RAMS '"~' I0 , , ' . , ii PIPE ~${S ~ ) 9 f PIPE ~2~S HD 2 CSG HD 3 O I AGR;/4 m2 13-5/8" 5000 PSI RSRRA 80P STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7oi/16" - 3000 psi x 11" - 3000 psi double studded adapter 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and ki!l lines 9. 13-5/8" - 5000 psi pipe rams 10. 13-5/8" o 5000 psi blind rams 11. I3-5/8" - 5000 psi annular 13. 1S. ACCUMULATOR CAPACITY TEST 1o CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND i200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK ANO MANIFOLD WITH ARCTI.C DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT Itl WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER ANO__CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. $. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI P,ND HOLD' FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. ll. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFOPJ4 COMPLETE BOPE TEST ONCE A WEEK AND FUNC- T IONAL L Y 0 PERATE BO P E DA I L Y. /. 70°19 '~8. '/'. :. Z. : b :Z ',Z'. .=. ~. ARCO Alaska, Inc. Kuparuk Project North Slope Drilling CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO REMARKS Fee .~~ 7-2~ -~-.-'.~ (2 thru 8) 1. Is the permit fee attached .......................................... ~__ 2~ 3. 4. 5. 6. 7. 8. Is well to be located in a defined pool ............................. /~ Is well located proper distance from property line .................. ~ Is well located proper distance from other wells .................... M~ Is sufficient undedicated acreage available in this pool ............ ~ Is well to be deviated and is well bore plat included ............... ~ Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... (3) Admin .~~. ~o~-~ (9 thru 11) 9~ 10. 11. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... (4) Casg ~z~ (12 thru 20) (5) BO PE /~/,~7'7"/ 7-,gi-¢ (21 thru 24) (6) Add: ~-~/~ 7--~/-~ · 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................................ ff~ __ 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 ................. ,/f~.~ Will surface casing protect fresh water zones ..11 ..... ] .~ ... ~-~ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ................. ' .......... Is a diverter system required ........ ' · Are necessary dis.grams of diverte~ ;~'~';~u;~ent';;;;~;~ iiii[ii ~~-- Does BOPE have sufficient pressure rating- Test to ~Z~f~ ~ ..... Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. ~p~-' Additional requirements ............................................. Additional Remarks:' Geology: Engin~.r ing: WVA <-":,?.~, JKT~HJH 7~ rev: 12/06/82 ...... INITIAL GEO. UNIT ON/OFF' POOL CLASS STATUS AREA NO. SHORE Well History 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 effod has been made to chronologically organize this category of information. ~mmmm~,mmmmmmmmmm~mmm~ ~ .... $CMLUMBE~ER .... ~ ~m~mmmm, mmmmmmmmm~mmmm~ LIS TAPE VERIFICATION LISTING .,VP O~0.H02 V~RIFICATIOM LISTIMG PAGE ~* R~EL HEADE~R ** ~ERVICM NAME :EDIT )ATE ]RIgIM : ~EEL HAME :~35463~ ~O TINUATIOM ~ )REVIOUS REEh : ~OMMENTS :LIBRARY TA~E ~* TAPE HEADER ** ~ERVICE NAME .EDI~ )ATE :83/08/22 3RI~IN :0000 ~APE NAME :8495 ~ONTINUATION ~ :0~ ~REVIOUS TAPE ~D~MENTS :LIBRARY TAPE ********** EOF ********** ~R FILE MEADE ** ~ILE NA~E :EDIT .00~ ~ERVICE NAME fER$ION ~ : ),ATE : ~AXIMUM LMNGTM : 10~4 ~ILE TYPE ~REVIOUS ~ILE INFORMATION RECORDS ** CONTENTS iN : ARCO ALASKA ~M : ~X-7 ~N : KUPARt!K ~ANG: 9E ~ECT: 4 ~~OUN: N.SLO~E ~TAT: ALASKA /TRY: USA COMMENTS ** UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 004 065 000 000 008 065 000 000 002 055 000 000 004 065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 004 065 dVP 01.0.}~02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ABASK;~. CD~P TING ~ONPANY = ARC[] ALASKA INC. ~ELL = ~X~ 7 ;'IELD : KUPARUK ~OUNTY = ~ORTH SL. OPR BOROUGH ~TATE = ALASKA JOB NUMBER AT ACC: 68495 ~[JN ~1, DATE LOGGED: lJ.'AUC~:'83 ~DP :: HGH .'ASING = 9 625" ¢. 3206' ' BIT SIZ~' -- 8 I/2" ~YPE FLUID =' ~' X; C :iPOLY:.~ER iSCOSITY ~ 4 ~ ~,F ~. 4.94 0 S 68,0 DF ~H 8. RMC 3.540 ~ 68 0 DF ~LUID LOSS -- 8.~ C3 R~ AT BH.T - ~.724 P ~4~'0 :DF ~ATRI× SANDSTONE .,VP 010.H02 VERIFICATION LISTING PAGE 3 DATA FORMAT ]NTRY BbOCKS RECORD TYPE 4 9 0 )ATU~ SPECIFICATION BLOCKS ~NE~ SERVICE SERVICE ID ORDER # )EPT IbM DIL [;,D DIL ~P DIL ;~ )T BHC ;R BHC ~PHI FDM )RHO FDN ~HOB FDN ~CNb FDN ~CNL f'DN ~ALI FDN 4RAT FDN {NRA FDN ~R FDN UNIT AP1 b 0 G OH~E ~API US/F 60 GAPI 60 G/C3 4~ G/C3 42 CPS 42 CPS IN 42 42 42 GAPI 42 SIZE REPR CODE AP1 API API FIbE TYPE CLASS ~OD NO. 0 0 0 0 0 0 0 0 o o 0 0 0 3i 32 0 0 52 32 0 0 31 3~ 0 0 68 2 0 0 44 0 0 0 35 1 0 0 34 92 0 0 34 93 0 0 28 3 0 0 42 1 0 0 0 0 0 0 31 32 0 0 SI ENTRY ,/IN 0 Z%~ PROCESS bEVE5 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 1 ! ! ! ! COD~ 68 68 DATA ** )EPT ~P ~PHI ~CNb )EPT ' ~PHI ~CNL ]EPT 7405.0000 999,2B00 -g99,2500 -999,2500 7400.0000 -999.2500 -999.2500 -999.2500 -999.2500 7300.0000 SFLU GR DRMO CALl SFLU GR DRMO CALI SFLU -999.~500 -999,~500 DT -999.2500 RHOB -999.2500 NRAT -999.2500 -999.2500 DT -999,2500 -999.2500 NRAT 3.1035 I5~ -999.2500 96.9375 GR -999.2500 NCNb -999,2500 RNRA '999.2500 ILD 96,9375 GR -999,2500 NCNb -999.2500 RNRA 2.6680 -999,2500 86.6875 .-999,2500 999,2500 -999.2500 86,6875 -999,2500-999.2500 2.9102 ,,VP OlO,M02 VERIFICATION LISTING 'PAGE 4 IP tPHI )EDT ~PHI "CNL 22.~156 GR 40, 855 DRHO 69. 000 CALI 109,1875 720 3 85 9 0 0000 2 7266 4 2285 7 0000 0 1250 GR CAL~ oooo IPHI 32,3242 ~RAHO ~CNL 800. 5000 ~R 7O.7500 )EPT ;P IPHI ;R )EPT ~P ~IPHI ~CNL )EPT ~P 4PHI )EPT {P ~PHI CCNL 109.1875 DT ~.0308 R~OB ,789I NRAT )EPT ~P ~PHI ?CNL )EPT ~P 4PHI rCNL )EPT 7,6094 90'1250 DT 0,0200 8,8828 NRAT 70,7344 · 7500 0.0181 R~OB .0625 NRAT 7.O 0.0 46 32 50 81 687 G .0801 DRHO .0000 CALI .4375 6,2578 IbM 81,4375 DT 0,0479 RNOB I0-0625 NRAT 6900 '69 61 0000 SFLU 0625 GR 1328 DRHO 0000 CALI 5938 75,4375 61'5938 DT 0.0366 9,1016 NRAT 680~. 0000 SFLU 4 .8437 GR 46,4355 DRHO 471.5000 CALI 115.1250 ,4238 ILM , 1250 DT 0 ~133 RMOB g ] 578 NRAT 67O0 0000 SFLU -42~8750 GR 48.1934 DRHO 461,0000 CALl 111,5000 2 1.953 IL~ 11.1~5000 DT 0.0181 RHOB 10.9297 NRAT 6.6~0 0000 SFI.,U 0;5000 GR -999.2500 DP, HO -999.2500 C4LI 234.0000 3.2578 IbM 234.0000 DT -999,2500 RMOB 9.3125 NRAT 00.0000 SFLU 6~47.7813 GR -999.2500 DRHO -999.2500 CALI 121,1875 3.5059 IbM 121.1875 DT -999.2500 RHOB 10.8047 NRAT 6400,0000 SFLU 3.5781 IbM 96.2500 GR 2.4844 NCNb 3.3418 RJRA 6,3945 ILD 92.9375 GR 2,347~ NCNb 3.017 RNRA 0000 GR 3574 NCNb ~9414 RNRA .3477 ILD 9 .6250 GR , 59 RNRA 39,4063 ILD 78.8125 GR 2,7793 NCNb 3,1406 RNRA 1,4004 ILD 119'1250 GR 2,4082 NCNb 3'7676 RNRA 1,9043 ILD 1,17.8750 GR 2.3320 NCNb 3.9473 RNRA 2,5820 IbD 114.0625 GR -999.2400 NCNb -999.2500 RNRA 2.9648 ILD 110.6250 GR -999.2400 NCNb -999.2500 RNRA 2.7520 97.9375 1901.0000 ,3477 0 664 ,0000 255~.0000 9:785 235~,0000 '9395 5,~883 000 78, 2224,0000 2,9648 61,4688 62,5313 1947.0000 3.0508 1.2461 114,9375 1574,0000 3.3379 1 7939 12525625 1749.0000 3.7930 2.4258 246,0000 -999,2500 -999.250O 2.8750 136,0000 999.2500 2.7188 0.10,[{02 VERIF/CATION I_,ISTING PAGE 5 'CNL ~EPT 'CNL 'EPT ~PH I 'C N L ;R ~EPT ;P 'CNb ~EPT ~P IPHI 'CNb )EPT ;P !PHI 'CNL )EPT ~PHI )EPT ~P ~PHI ~CN I., )EPT ~P 4PHI "CNL )F. PT -.37 7500 GR -999 2500 DR~ -999 2500 CALI 1~! 3750 1:~:I.3750 DT -999,2500 R~OB ~0~1641 NRAT 6300 -47 -999 -999 8O 0000 S~SU 9375 G 2500 2500 0625 5 2695 Ib~ 80:: 0625 DT -999,2500 RNOB 10. 9531 NRAT 0000 SFLU 6200, 437 :GR -34,~ '999. ~00 DRHO -999,~ 00 CALI 124.4375 2734 4375 DT -999,~500 [{HOB 234 N R A T 6~00.0000 SFbU 41.9375 GR -999,2500 D~HO -999.2500 CALl 126.~250 3,0488 IbM 126'12~0 PT -999,2500 RHOB 10.671:9 NRAT 60~0,0000 SFLU 1,1875 GR -999.2500 DRHO -999 2500 CALI 10639375 .~441 IbM 10~, 375 DT -999,2500 RHOB 10"6016 NRAT 5900 0000 SFLU . '36,281~ GR '999,2500 DRHO -999.2500 CALI 121,0000 3,6094 IbM 121.0000 DT -99~,~500 RHOB .1 .6406 NRAT 58oo oooo SF ,U · .3327813 GR -999.2500 DRHO -999,2500 CALI 147.2500 3 4824 IbM 1,4722500 DT -999. ~500 RHOB il.4375 NRAT 5700.0000 SFLU -24.5313 GR -999.2500 DRHO -999.2500 CALl 136.3750 1 6885 IbM 136:3750 DT -999.2500 RHOB 9.5547 NRAT 00 0000 SFLU : oo -999 2500 CALl 107:8750 1 4365 IbM 107:8750 DT -999,~.500 RHOF 10,2578 NRAT 5500,0000 SFLU 2.0352 IbM 112.2500 GR -999,2400 aCNL -999.2500 RNRA · 500 GR .-999,2400 NCN'L 999.2:500 RNRA 934 ooo -999,2400 NCNb . 999o~500 RNRA 437:5 GR -999,2400 NCNb -999,2500 RNRA 3,3~01 ILD 98,9 75 GR -999,2400 N'CNL "9 3.6563 ILD ~,04.3750 GR -999.2400 NCNb -999.2500 RNRA 3.1699 117.8750 -999.2400 NCNb -999.2500 RNRA 1,4326 102.4375 GR -999.2400 NCNb -999.2500 RNRA 1.5742 ILD 116,2500 GR -999.2400 NCNb -999.2500 RNRA 1.951.2 ILD 117,9375 999.2500 ~999.2500 4,5508 82. 875O 999,2500 :o 9. soo ,0645 13 .1250 -999,2500 -999.2500 2,8066 128.8750 -999,~500 -999' 500 3,2734 109.7500 -999.2500 '999.~500 3,61~3 125,68 5 :999,2500 999.2500 3,1543 151,3750 -999.2500 -999,2500 1.2344 126.6875 -999,2500 -999.2500 1.5322 122.0000 -999.2500 -999.2500 1.9707 5VP 010.H02 VERIFICATION LISTING PAGE 6 5P -25 75OO GR ~P~I -999~2500 DRHO FCN5 -999.2500 CABI ~R 160.6250 )EPT 5400,0000 SFLU SP -26,0313GR ,PHI -999.25~§ ~CNL '~gg. 25 CALI 120.8750 )EPT 5300.0000 ~P -17.7656 gPHI -999,2500 DRHO ~CNL -999.2500 CABI ~R 92.~875 )EPT 5200 0000 SFI.~U ~P -35 21!87 GR ~PHI -990 2500 DRHO FCNL -999 2500 CALI ;R 99.6875 )EPT 5~00.0000 SFLU SP . 38,31~5 GR 9PHI .999,~500 DR~O ~CN[, 999. 500 CALI 107.6250 ]£PT 5000.~000 SFLU ~P -3~. 375 GR 9PMI -999,~500 DRMO ?CNL -999. 500 CAI~I 92.6250 0000 SFLU sP3EPT 4~:0000 GR ~P}{I -999.~500 DRHO ~CNL -999 2500 CALI ~R 10~0000 )EPT 4700.0000 SFLU ~P -22.5156 GR ~PHI -999.2500 ORHO ~CNI~ -999.2500 CALI ~R 96.3125 )EPT 4600.0000 SFLU 160,6250 -999,2500 RHOB t0,0547 NRAT 2,5996 120,:87!50 DT -999.2500 RHOB 10.3672 NRAT 9~.1875 DT -999.2500 RHOB I0,1953 NRAT 92,4121 I5~ g , 6895 DT -999,2500 RHOB 9.6719 NRAT ,994J. IBM 1:0~.6250 DT -99~,2500 RHOB .7344 NRAT , 8 I -999,~500 RHOB 7. 242 NR~AT 2 3555 108~0000 DT -999,2500 R~OB 10,0234 NRAT 2.7422 II.~M 97.8125 DT -999 2500 RHOB 9:8906 NRAT 2.7324 96.3125 DT -999.2500 RHOB 10.2422 NRAT 3.1.543 IbM 1.15,7500 GR 999,~2400 NCNb -'999.2500 RNRA I -999 -999 7578 II~D 9375 OR 2400 NCNB 2500. 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TYPE · E×T FIL~ NAME ElF ********** * FILF HEADEP ** IbM NA~E :RFT ,004 ERV ICE'. NA~E : !{,OG ERSION ~ : 24. ATE :83/00/]5 AXIMUM LE~GTH :1024 ILE TYPE : P~ REVIOUS FIbE : * IN~OR~ATION RECO)!,Do ** ABLE TYP~' :AYER 'ABLE TYPE :EXPR TS .ALbO 3079.7500 ( TflhS - TENA * EX00 PISA 0,0000 EX01 DIS~ 0,0000 E~02 DISA 0.0000 FXO3 [)ISA 0,0000 EX04 DISA 0,0000 ZE~O ~LL, O 0.0000 ZE~O : 0 LCON ~xP2 ~EbL VALU TS Al, bO TS .AND ZERO 5 WTSM OFF 0 WA00 DISA ZERO .AqO ZERO 32767 AbAR OFF 0 NAO1 DISA Z~(] .AND ZERO 32767 ALA~ OFF 0 32767 ALAR OFF 0 ~VP 010.H02 VERIfIC.~TION DISTING PA~E 18 ISA ZERO . AND ZERO 67 ,A L A.R OFF 0 ~ABLE TYPE :T~OL ~ABLE TYPE :CONS f~ P E N IN IN 0 . 0000 i F P 8192.0000 1,0000 2'0000 PH × PS~G FTES BOTH DEGF DEGF 152.0000 FT FT 6901.~994 PSIA P$IA 14, 000 o~<;~' ~,~ ~o.oooo ~ ~ s~ ~oooo. SING S S ~,1980 S S 18.0000 PRET HORN ,WP 0..I. 0 HO2 VERIF~C,ATIOI,~ Llc, TT. NC: PAGg 19 .?OOL,STiCKING* . ALARM' . ALARM . OFF. PUNI T UNI VAbU I]NAL T,N IN gNAt, OHMN. OH~ 1,0000 UNAL FEET UNAL FEET U N: A L F g g T UNAL SHOR U NAb 19 ~ 3 UNAL 7 UMAb 26 :ABt, E TYPF :CONS ~VP 010.HO2 YERIFICATI, ON 'LISTING PAGE 20 C 0 U N LMF PD~,T APIN OS2 0S3 OS 4. 086 T L A ~ TCS TN1 TN2 TN 4 TN5 TN7 TN8 TNq TNI0 ~N12 ~ECT NSS g FS S ~CSS CLA5 CS2 BS2 L U ~ OPF, R LCC TL ! ,, UNAL UNAL UN A L UNAL UN A L U N A 5 LIN A: L {,J N A L UNAb UN'AB [JNAL U N A L UNAL U N A UNA:L UNAL UN A L UN AL IJN~B UNAL UNAL, UN A L UNAL UN~L UNAb UNA~ U N A L UNAL UNAL U N A L U ~' A L UNA5 U N A L UNAL UN~L UNAL UNAt, UNAb U N A L UNAb UN AG UNAL UNAL UN~L UNAL UNAL UNAL STATE COUNTY INCL 0 0 0 440 0.0000 0.0000 0.0000 0.0000 0.0000 ~VP 010 H02 VERIF'ICATI(3~,I LI,~TING PAGE 21 DATA FORe, AT RECORD ** ]F!TRY PLUCKS TYPE 1 2 4 5 6 7 9 11 i3 15 16 0 )ATU~ SPECIFICATION ~NEM SEPVICE SERVICE ID O~DER ~ ~TIW RFT ~ENS RFT ~SPE RFT SIZE 1 2 1 1 4 1 1 4 1 1 REPR CODE 66 66 79 66 66 73 65 73 65 66 66 65 66 66 66 bLOCKS UNIT API AP1 t,OG TYPE CI, ASS S 9~ 636 21 LB 9~ 635 21 RPS 98 970 01 F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 ~G~ DEGF DEaF ENTRY 0 0 3O 255 311 INCH 12 33 1 .lIN 73 1 0 API F!I.E SIZE I',! 0 D NO. 0 4 4 0 4 2 0 4 2 SPL REPR CODE 1 68 1 49 1 49 0.000:0 0,0000 0;0000 :oooo 0000 0.0000 0.0000 0,0000 0.00:00 0.0000 0.0000 0,0000 0.0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0.000:0 §:oooo '0000 0,0000 0,0000 0.0000 0.0000 0.0000 PROCESS (OCTAL) 04000000000000 04000000000000 04000000000000 YP OlO.H02 VE~F'~C~TIOf~ I.,TS"J?~r,;G .PAG~ 22 PRE RFT DIO PFT ONE ~FT TEN RFT HUN ~T THQ RFT 00 0 4 4 O0 0 4 2 O0 ~ 0 4 2 00 0 4 2 00 0 4 2 00 0 ~ 2 00 0 4 2 O0 0 4 2 O0 0 4. 2 00 0 4 2 1 68 041,00000000000 1 49 04000000000000 49 04000000000000 , 49 04000000000000 49 04000000000000 i 49 04200~0000000~ i 49 04200 0000000 1 49 04200000000000 ! 49 04200000000000 1 49 04000000000000 DATA FORMAT ,%~ T P, Y BLOCKS TYPE 5 1 3 0 .ATUN SPECIFICATION ~L, OCKS !NE,~ SERVICE SER¥I£E UNIT ID f~RDER ~ :TI ~'i WFT S 'ENS RFT LB [SPE ~FT R~S ;dP RFT 'RES PFT PSIG '.PRE PFT PSIG ~DIO RFT '020 ~FT 'ONE RFT 'TEN FFT ~HUN 'THO RFT ',R RFT GAPI SIZE 2 1 4 4 REPRCODE 66 66 79 66 66 73 65 73 66 66 65 66 66 66 AP1 AP1 LOG TYPE CLASS 98 636 21 99 635 21 98 970 98 814 O0 98 814 O0 98 814 O0 9~ 8!4 O0 98 81~ O0 98 8~4 O0 98 814 O0 98 814 O0 98 814 00 9~ 3!0 00 A?I FILE MOD NO. 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 SI ENTRY 0 0 30 255 0 311 1.2 33 t .lin 73 1 0 ZE SPL 4 2 4 2 2 2 2 2 2 REPR PROCESS CO[)E (OCTAL) 68 04000000000000 49 04000000000000 49 04000000000000 68 04100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 04200000000000 49 04200000000000 4~ 04200000000000 49 04000000000000 'TI~ 0.2990 TENS ******** DEPTN FEET 6551.0,1016 3114,0000 ******** METERS 19967.4785 MSPg 9.2031 SCP 3184.0000 VP 010.H02 V'~..TRI..'FICATTO!~ [., ]l'] G '!' :[ ;',~ (.:.; PAGE TIN lg~,0977 TENS REo B!96 0000 RDRE ONE 8,0000 P T,. Et.a 3200.0(,00 9.0000 PD10 0.0659 P H U ~:! 1.00 O 0 ******** DEPTH ******** 6557 ~. ,6484 19986.2]8] 31~0,0000 ~.~SPE 47.6875 3~,~6.0000 P:Di0 g. O00O PWg~: ~ ,0o00 PD20 PT~O SGP P T .~ O 0.0620 3.0000 3 1 84. 0000 0.06~5 3,0000 * FILE TRAILER ** IbM N a t,~E :RFT ,O04 ER¥1CE NAIVE :l,OO ERSION ~ : 24.1 A, TK :83/00/35 aXI~'Uk~ bENGTH' :1024 'ILE ~YP~": :P~ MXT FILE NAIF. ~ * FIbE HEADMm ** 'Ibf ~!A~E :RFT ,ERV I'CM NAME :LOG 'ERSJO~t # : 24,1 ~TE :83/00/35 AXI~tI~ LENGTH :1024 'ILE TYPE: :PR 'REVIf]US FIbE :* INFORmS-aT'ION RECOPDS ** 'ABLE TYPE ~.~Et~' ST~,T OUTP DCON VALU TEa~ ~ ~[,br] TENS 2 0,0000 AVO0 DISA. DI]J~N} 1 0,0000 AVO1 DISA DI. JqM 1, 0,0000 AV02 OISA DUM~ 1 0.0000 ~ABLE TYPE ....... .................... 'PS al,~,m - ~ · EXO0 ?)ISA 0,0000 lXO~. DISA 0,0000 VP 010.H02 VERIFI ..... AII[)N LIS INfl P.~GE 24 ABLE TYPE :WARN ZERO = 0 W'AO0 PISa ZERO . AND ZERO 32767 AhAI~ OFF · 0 w ~0 ] PISA Z~RC . AND ZE~O 32767: ALA~ ~:FF 0 WA02 PISA Z..RD . AND ZERO ~ ~ 7.67 A L A R O F ~ 0 WA03 PISA ZERO . AND ZE~O 32767 iLAR: OFF 0 ABLE TYPE !TOOL A .... LE TYPE Cc]NS ~NE~ STAT PUNI TUNI VALU BH3 UN~L OPEN CSIZ UNAL IN IN O. I~VD UN~L SD UNAh FNU~ UNAL FEXP UNAL FDHI UNAL RPU UNAL SGSO LINAL AOFF UNAL ~FTT AL, LO FDEP UNAL ~ UNAL ATEM UNAb q'PPE UNAL 0000 1 F F 8192.0000 1.0000 2 0000 PSIG FTES BOTH DEaF IDEGF 152.0000 FT ET 6913.0996 PSIA P$I~ 14.7000 DEGF DEGF 70,0000 PSIG PSIG 0.0000 58809 SING ,VP 01.0.}')02 VE;R!FIC~TIDN LISTING PA~E 25 54.5959 17 101.0 ~O~N . TOOl,, .STICKING* .ALARM. .ALARM.OFF. STAT DISh T PUN I TIJl~I V[LU L !u IN 8,5000 L OHMM OHMM 1.0000 L FE~T L FEET b FEET L 1.983 ~ ? L 26 TYPE : CONS ,VP 010.H02 VERIFICATION LISTING PAGE 26 ~4~ UNAL H I DE UN A L W bi U ~ A b C N U M A b L U N A L FBI [JNA~ L U L U:N A ~ N G I U N A b W I T N U N A b LONG UNA LATI UNhL STAT UNAL CC) U N ~N AL [, M F U N A PDAT U NAL APIN UNAL 081 UNAL 0S2 UNAL 0$3 UNAL 0S4 UNAL 0S5 UNAL OS 6 U N TI, AB UNAL TN1 UNAL TNP UNAL TN3 UNAL Ta~ 4 O N AL TN5 UNAL T N 6 U N AL TN~ UN~b ~'NF~ UNA[, ~N9 UNAb TN ~ 0 T~T1 1 UNAL TN12 UNAL SECT UNAL T~WN UNAL RANG UNAL ~ATI UNAL CONT UNAL ~SS UNAL MFSS UNAb ,VP 010,HO2 VERIFICATION LISTING PAGE 27 DATA POP,AT RECORD ** CNTRY BLOCKS TYPE I. SIZE 1, ! CODE 66 66 F F F F F F LBtF F LB/F F F I,B/F F F DEGF DEGF ],,BIG S C3 OH~N OHMM DEGF DEGF DEGF ENTRY 0 0 STATE COUNTY INCL 0 0 0 440 0,0000 0,0000 0,000'0 0,0000 0;0000 0.0000 0.0000 0.0000 0'0000 0,0000 0.0000 0,0000 0'0000 0,0000 0.0000 0.0000 0.0000 0.0000 0,0000 0.0000 O.OO00 0,0000 0.0000 0.0000 0.0000 0.0000 0,0000 0.0000 0000 :oooo 0.0000 0.0000 0,0000 ,VP 010.H02 VF, RIF$CaT1OI,~' LISTING PAGE 28 3 5 7 9 1 15 0 2 79 30 I 66 255 , 66 0 ~ 73 ~11 4 65 4 65 .~IN 1 66 ~ 66 a 65 .lin 66 73 0 SPECIFICATION B[,OCK .... S,''E. PVIC~ SEPVI(..E~... U~IT. AP1 API API API FII,E SIZE SPb REPR ID ~DE~ ~ LOG T ~ . YPE CLASS MOD 'NO CODE ;TIM RPT S 98 636 2~ 0 5 4 EN~ RFT LB 98 635 21 0 5 2 !gPM RFT RPS 98 970 Ol 0 5 2 ;GP ~FT PSiG Q:~ 814 O0 0 5 n, 'RES RF . P~IG 98 814 00 0 5 ~ ~P~E RFT FSIG :98 .~i4 O0 0 5 2 'D10 RFT 9g 8!4 00 0 5 2 'D20 RFT 98 8 14 O0 0 5 2 'ONE PFT 9R 81~, 00 0 5 2 ,TEN R'F'T g8 8 ~ O0 0 5 2 'HUN RFT 9~ ~ ~ O0 0 5 2 ,TUO ~T ~ 8~4 oo o 5 2 PROC~S (OCTAL~ I o o oooooooo§§ o,oooooooooo o oooooooooooo o4 ,ooooooooooo o oooooooooooo :1 49 040000:00000000 1 4q 040000o0000000 ! 49 04000000000000 1 4q 04~00000000000 I 49 04200000000000 1 ~9 04200000000000 ~ 49 04200000000000 1 49 04000000000000 DATA FORMAT RECORD ** ;NT~Y ~!.,OCKS TYPE SIZE REPR CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 30 4 I 66 255 5 1 66 0 6 4 73 311 7 4 65 INCH ~ 4 73 12 9 ~ 65 ,lin 11 1 66 33 1.3 1 66 1 !4 4 65 .lin 15 ~ 66 73 16 ! 66 1 0 t 66 0 )ATU~, SPECIFIC~'rlON BLOCKS ~NE:.~ SERVICE SERVICE UNIT API AP1 API API FILE SIZE SPL REPR PROCESS !O (IRL)~ ~ I.,[IG TYPE CLASS Mr3D NO. CODE (OCTAL) iTI~ RFT S 98 636 21 0 5 4 1 68 04000000000000 TENS RFT l,g 95 635 21. 0 5 2 1 49 04000000000000 ,VP 010,H02 VERIFICATION LISTING PAGE 29 SPE RFT .GP RFT 'RES RFT PRE RFT 'DiO raFT 'D20 RFT ~ONE RFT 'TEN ~FT '~UN RFT 'THg RFT :R RFT RP8 98 970 PSIG 9, 81.4 PSIG G~PI O1 O0 O0 o~ 814 O0 92 81,4 O0 98 814 :00 98 814 O0 9g 814 00 98 310 O0 0 0 0 0 0 0 0 0 0 0 0 49 04000000000000 68 04100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 4904200000000000: 39 04200000000000 49 04200000000000 04200000000000 49 04000000000000 * DATA ** :TIM 'RES 'ONE ******** DEPTH 6551~,1016 19967.4785 o.3ooo . l o,oooo 8.87 o 3202 ~000 RPRE 320~.0000 PD10 0.0679 2: 000 PTEN .0000 PHUN 2.0000 29.~Q69 :TI~4 'RES 'ONE ******** DEPTH ~ ~.ET ~ETERS 65565,1484 19984.2578 162.9007 TENS 3044.0000 MSPE 47.4063 3202.0000 RPRE 3202 0000 PI)lO 0.0669 0.0000 PTE~ O~ 000 P~UN 2 0000 160.8750 FILE TRa. IL, ER ** 'ILE NAME :RFT .005 ;ERVICE NAME :LOG 'ER$10N # : 24.1 ~,~.TE :83/00/35 !AXIMU~, bFNGTH :1024 'ILE TYPE :PR EOF SGP 3188-0000 PO20 0.0615 PTHO 3.0000 SGP 3186.0000 PI)20 0 0615 PTMO 3 .'0000 :* VILE HEADER ** '!LF NA~E :RVT ,006 ;ERVICE NAME :LOG 'ERSION # : 24.1 ~ATE :93/00/35 !AXIMUN LFNGTM :1024 'ILE Type 'REVIOUS FILE : :* INFORMATIF)~! RECORDS ** VP OIO.HO2 VER'IFIC^TIO~ bISTING PAGe2 30 'A.BLFi TYPE :M×PR 5 WTS~ OFF 0 Wa OO l)ISg ZERO . AND ZERO 32767 ALAR OFF 0 WAO 1 DISA ZERO . AND ZERO 32767 A 1L,.l% R CFF 0 WA 02 DISA ZERO . AND ZERO ~2767 3I..,A~ OFF 0 W~ 03 OIS~ ZERO . AND Z~RO 32767 ~[,AP OFF 0 ,ABLE TYP[': :TQOL ~h~EM STAT L, EMG hEIG HEIG O T ? A L L O 0 0 O ~FT Al, LO 214 709 0 SGTE ~LLO 60 ~7 214 ?_~BLE TYPE :CONS P.~NEM $.TAT PUMI Tb blI VALU vp OlO.H02 VERIFICATION LISTING ,P~GE 31 IN psI~ S IN F DE;GF FT PSIA PSIG S $ OPEN o,0000 1 8192,0000 1,0000 ~. ~oooo PSI~ 10K FTE$ BOTH 152.0000 6919,9990 14,7000 7§:oooo 0000 58809 SING 5~,0999 2 .o000 PRET HORN .TOOL.STICKING* ,ALARm. .ALARm.OFF, VP 01¢).H02 VF:PlFI'C~,TI[it~? LiSTI~!C PAGE 32 ~BLE TYPE :CONS PUNI TUNI VALU ............................................'' ID~ 'I N [)HP~M OHi~,,~M FEH2[~I 0000 SHOR 1983 R 1 UNAL R2 UNAL R 3 U N A L R 4 UNAL H I' DE UNA:L w N U N A L CN UNAL WN tINAb FL UNAL FL 1. UNAL LUL UNAL ENG I UN AL WITN UNAL DFT UNAL LONG UNAL LA, TI UNAL STAT UNAL CDt.IN UNAL D P F U N A L L~F IIMAL PDAT UNA, L APIN T.]NAL OS1 UNAL OS~ UNAL OS3 UNAL 0 S 4 t.t D~ A L 0S5 UNAL 056 t~NAL TLAB UNA5 TCS Uh, AL VP O]O.H02 VEPIFICATION LISTIM(,; PAGE 33 T~I TN2 TN 3 TM5 TN7 TN8 TM9 TNll SECT TOw ~ NATI CONT MSS ~FSS ~CSS SL,~B CLUB C~. CS2 CS 3 BS3 P U ~"~ L U M bCC EDF TDL CBDI Cmbl CW 2 ~BD2 CBD2 CW3 CBO3 CBD3 F F F F F F F F F LB/F F F LB/F F F F LB/F F F F F F F F F F F LB/F F F I.,B/F F F LBtF F F STATE COUNTY INCh 0 0 0 440 0.0000 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0.0OOO 0.0000 0.0000 0.0000 0.0000 0.0000 0,0000 0,0000 0.0000 0.0000 0,0000 0.OO00 0,0000 0.0000 :'1"~ I'1 [! 1 i il iI:-t i[! [:-1: ,VP 010.H0~ VEgIFICgTION LISTING PAGE ~4 0.0:0:00 0.0000 0,0000 ,0000 ~,0000 ~,0000 .0000 0,~000 O. 000 0,0000 0,0000 0,0000 DATA FORMAT RECORD** ]NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 66 0 66 0 3 ~ ~9 30 4 6 255 ,. 73 311 7 4 65 IMCM 8 4 73 12 9 a 65 .lin 1! 1 66 33 ~.3 1 66 1 14 4 65 .lin 15 1 66 73 16 ~. 66 1 0 1 56 0 )ATUM SPF. CIFTCATIOli B.hOCKS 4NEE SEPVICM SERVIC~.I UNIT API API APi API F'ILE SIZE SPL REPR ID ORDER # LOG TYPC CLASS MOD ~0. ~TIM RFT S 98 636 21 0 6 4 ~ENS PFT L~ 99 635 21 0 6 2 4SPE RFT RPS 9~ 970 01 0 6 2 5GP ~FT PSiG qR 814 00 0 6 4 )RES RFT MSIG 98 814 00 0 6 2 ~PRF RFT PSIG 9~ 814 00 0 6 2 ~OlO RFT 98 814 00 0 6 2 ~D20 RFT 9~ 814 00 0 6 2 ~ONE RFT 98 814 00 0 6 2 ~TEN ~F· 98 814 00 0 6 2 ?~UN RFT 9~ 814 00 0 6 2 ~THO PFT 98 814 00 0 6 2 3R PFT GAPI g9 310 00 0 6 2 PROCESS CODE (OCTAL) 68 04000000000000 49 04000000000000 49 04000000000000 6~ 04100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 04000000000000 DaTA FORe, AT qECORD sNTRY EI:DCKS TYPE SIZE F:EPR CODF. I 1 66 TRY 0 010_.HO2 V~:RtFIt~I...OI~'~' '~ f, ISTI~('; PAGE 35 )ATUM SPECIFICATIO~ R[~OCKS ]NE~ SERVICE SE~VI E UNIT API API ID ORDEP ~ ]TIM RFT S 'ENS ~FT L~:,~ 9~ 635 ~SPE RFT RPS 98 970 ;GP RFT ~RES ~FT ~PRE RFT PSIG 98 ~D10 RFT 98 ~D20 RF'T 9~ )ONE R~T 98 ~TEN RFT 9~ ~THO pwT 98 ;R RFT GAPi 9R API API FISE LOG TYPE CLASS I~0D NO. 98 636 i ~1 0 6 0 ~ 00 0 6 00 0 6 8~4 O0 0 6 814 00 0 6 8~4 O0 0 6 814, O0 0 6 ~ Of) 0 6 :1. 4 00 0 6 8.14 O0 0 6 310 O0 0 6 SIZE SP 4 2 2 2 2 2 2 REPR PROCESS CODE (OCTAL) 68 04000000000000 4~ 04000000000000 49 04000000000000 6~ 04100000000000 49 0400000000000:0 49 04000000000000 49 04000000000000 4g 04000000000000 49 04200000000000 49 04200000000000 4~ 04200000000000 49 0420000000000~ 49 04000000000000 ~TI~! 0.3000 TENS ~RE8 3202.0000 RP~E ~ONE 3.0000 PTKN ;R 31.3125 ]TIN 255.9012 TENS ~RES 3202.0000 RPRE 'ONK 2.0000 PTEN ;~ 15~.~'750 FILE TRAIDER ** ?ILE .~] A ~i E :RFT .005 ~ERVICE ~:,~h~F :LOG ******** DEPTg ******** FEET METERS 65510 1036 1996'1.4795 3202,oooo pOlO 0,0000 ******** D~PTH ******** FEET M~TERS 65~96.63~B 19993.8535 3044.0000 ~SPE 3~02,0000 PDIO 0.0000 PHU~ 9.4219 0.0659 2.0O00 21.5156 0.0669 2.0000 SGP 3189,0000 PO20 0.0620 PT~O 3.0000 SGP 3188.0000 PD20 0 0615 PTHO 310000 VP 010 MO2 VEPIFICAT*"N . ti LISTING 'PAGE 36 ERSIEI~, ~ ATF :83100/35 A×IMUbl ,LTCNGTR :1024 ILF. TYPE EXT WILE ILE NAME :RFT ,007 ERvICE NAME :LOG ERSION ~ : 24.1 aTE :83/00/35 'AXI~UM LENGT?~ :1024 '!LE TYP~ ~RE¥IO~IS FILE , INwr~RM~TION R~,CO~,D,,, ** TYPE : AVEP !~BLE :I'YPE :EMPR ~NF:~ STAT VALtl KXPR TS ~!Ln EXO0 DISA 0,0000 EXO1 DISh 0,0000 E~02 [)!SA 0.0000 ~X03 OlSA 0.0000 ~X04 OIS~ 0.0000 ZEPO ~LLO 0.0000 ZEFO = 0 !AB[,E TYP~ :W.ARk! ~;~g~ STAT ~×PI [,CON EXP2 FREO ACTI BgLL VALU mmmmm~mmmmmm~mm ~ m · S ~[,[,0 TS ZERO 5 WTSM OFF 0 wAO0 DISA ZERO .A~!D ZERO 32767 AI,,~R OFF 0 WAO1 DISA ZERO ,AMD ZERO ,VP 0.10.H02 VERIFTCAT.'£ON LISTING PAGE 37 32767 ALAR f)FF 0 WA02 [)ISA ZER.. , AND ZERO 3P767 ALAR OFF 0 WA03 ~ [)!SA ZERO ,AqD ZERO OF~ 0 32767 A. LAP ~ !ABLE YYPE .,TOOL ?AB[,E TYPE :CONS CSIZ INVD FNU~ ~'PHI gPU PFTT FDEP ~TE~' SCSN TO~T CVOL PLOT LCO1 LC02 L, C 0 ~ LC04 bC06 !,CO7 LeO 9 LCIO LC12 STAT PUNI TUNI VALU OPEN IN IN 0,0000 F F 8192 0000 2oooo 2,0000 PHIX FTYS BOTH DEGF DEGF 1,52.0000 FT FT 6918,9990 PSI~ PSIA ~4.7000 DEGF DEGF 70,0000 PSIG PSIG 0.0000 58809 5ING S S 56.0999 $ S 21.3001 PPET N~RN ,¥P OlO.H02 VFRIFICATION LI&TING PAGE 38 .,tOOL.STICKING* .ALARM, .ALARM-OFF. 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TEN~ ~tbn TE NS ? 000 ~V00 PISA DUMM 1 O. 0000 ~V01 PISA gLl~~, 1 O. 0000 ~.V02 PISA DU~ ~ 0.00C)0 TYPE : EXPR T E Z b!C~ STAT V~bU EXPR $ A!..,LO 3093.7500 ( TENS XO0 PISA 0.0000 X, O1 [)ISA 0,0000 X02 [)ISA 0,0000 X0~ PISA 0,0000 X04 PISA 0.0000 EPO ~I,[,~ 0.0000 ZE~O TYPE : WARM VP 010.HO2 VERIFICATION LISTING PAGE 75 ZERO ,~ND ZE ,0 ALA.~ OFF 0 ZE?RO , AND ZERO ALAR OFF 0 767 AL~]~: ~FF 0 DIS A ZERO , ~ND ZERO 767 A 5 A R 0 ~ F 0 ABLE TYFE :TOOL I PFT .~l,~ 214 70H 0 oGmE ALLO 60 87 214 'ABI.~Ei TYP~] :CONS MNE~, ST AT PUNI TUNI VAbU i BHS UNAL OPEN CS I5 UNAb IN 311N O. 0000 IHVD UNAL SD UN&L F F 819~. 0000 FNUM UNAL 1 , 0000 .. 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IN .000 RW UNA5 OHMM OHMM 1,0000 KPDU UNAL FEET O~DU UNAL FEET ~OU !.INAL, FEET PF UNAL SHOR YEAR U~AL 1983 MONT UNAL 7 PAY UNAL 26 ~ABLE TYPE :CONS ' ~NgM STAT PUli TUNI VALU SON UNAb ~* ** ~1 UNAL ~2 UNAL P3 UNAI, P4 UNA~ ~llP~ UNAL ,VP 0~O.H02 VMPIFICATION LiSTIh'G PAGE 77 STATE COUNTY VP 010.1{02 V~.TR[FICATION LISTIMG PAGE 78 F F F F B/F F F LB/F F B/F F DEGF DEGF LB/G S C3 0 H M M OHMM DEGF DEGF F F F F' B/F F /F F F B/F DEGF DEGF LBtG C3 DEGF DEGF DEGF 44 0 0 0 0.0000 0,0000 0'0000 0,~000 0 . 000 0,0000 0.0000 ,0000 .0000 0,0000 0.0000 0,0000 0.0000 ,0000 ,0000 0,0000 0.0000 ,0000 '0000 0,~000 0. 000 0,0000 0,0000 0.0000 0.0000 0,0000 0.0000 0,0000 0.0000 0.0000 0.0000 0.0000 0.0000 ~* Dg'rg FORKAT RECO~D ** ~NTPY BLOCKS TYPE 2 4 5 6 7 9 11 ~3 14 SIZE 1 REPR CODE 66 66 79 66 66 73 65 73 65 6~ 66 65 ENTRY 0 0 30 255 0 INCH ~2 , ,VP 010,El02 VERIFICgTIOF! bISTJN(; PAGE 79 15 66 66 66 ~ATUM SPECIFICiqTION !~tE~! .SE~VICE SE~VICE; ID OROER ~ U.%~ I T f~PI S G~PI AP[ AP1 AFI FILE TYPE CLASS MOD I~O. 92 636 21 0 13 9~ 635 21 0 13 ~8 970 O1 0 13 9~ 814 O0 0 ~!4 00 O 13 9 ~14 O0 0 13 9~ 81.4 O0 0 13 98 814 O0 0 1 3 08 ~1.~ 00 0 13 9~ t14 O0 0 13 q~ 9!~ O0 0 13 98 8!4 O0 0 13 9~ 310 O0 0 13 :, DAT.Z% FORMI%T RECORD ** ;NTRY BI'~OCKS TYPE 2 4 5 7 ~3 ~4 0 SIZE 1 4 4 4 1 1 1 1 REP~ CODE 66 66 79 66 6~ 73 65 73 65 66 66 65 66 66 SPECIFICATION L%bOCKS SERVICE SERVICE UNIT NRll) E',P ~ ]TI~ RFT ~SPE PFT ;GP FFT {PRF RFT ~DiO PFT ~20 RFT ~ONE ~FT ~TEN ~HUN FFT ~THO P5IG PS I (; API 9~ 98 9~ 9S 9~ 9a 9~. 9a SIZE 4 2 4 2 2 2 2 AP1 AP1 &PI FILE SIZE; TYPE CLASS ~OD NO. 636 21 0 13 4 635 21 0 1.3 2 970 O1 0 13 2 ~1,,4 O0 0 13 4 814 00 0 13 2 8i4 O0 0 13 2 ~14 O0 0 13 2 814 O0 0 13 2 814 O0 0 13 2 81a OD o 13 2 814 O0 0 13 2 8ia oo o 13 2 73 1 0 SPL 1 1 1 1 ! 1 1 YNTRY 0 0 30 255 0 311 1 NCH 12 . 1 I N 33 .lin 7 SP REPR CODE 49 49 49 49 49 49 49 PROCESS [OCTAl,) 04000000000000 04000000000000 04000000000000 04100000000000 04000000000000 04000000000000 04000000000000 04000000000000 04200000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 0400()000000000 l, REPP PROCESS CODE (OCTAL) 1 68 04000000000000 1 49 04000000000000 1 49 04000000000000 1 68 04100000000000 1 49 04000000000000 1 49 04000000000000 ~ 49 04000000000000 1 ~9 04000000000000 ! 49 04200000000000 t 40 04200000000000 1 49 04200000000000 1 ~9 04200000000000 VP O10 H02 VF. 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ON !ISTIS;G PAGF~ 83 FEET FEET FEET SHOR 1983 A:BLE TYPE :CONS ~N FL ~L1 L U L gNGI WITN DFT LONG L;TI STAT COUN PDAT API. M OS1 083 TLA B T~3 TN6 ,VP 010.H02 VERIFICATION LISTING PAGE 84 TN 11 SECT TOWN CONT ~SS NFSS MC$S SLAB CLUB Cgi CS2 gl~ D LIJN OPER LCC ~,I TLI EPD TDD T D b RSD1 CBD1 CBL 1 CW2 ~SD2 CBD~ BSr>B CB[,3 STEM MRT DFD DFPR ~S R~CS U NAL U N A b UNA[, tlNAL '0 N :A L UNAL UN AL UNAL UN AL UI~AL ONAL U N A[ U:N AIl UN'AL UNAL U N A ' U ~ A L UN Ab U N U N A L UNAL UNAL UNAL UNAL U N A L U N Ab UN Ab UNA b UNAL [JNAL UNAL UNAL UNA5 UNAL UNAL UNAL U N Ab U~:AL UNAL UNAL UNAL UNAb ~NAL UNAL U N A L U~AL UNAI., UNAL [.T N A L UNAL F F F F F F F F LB/F .F F F LB/F F F F LB/F F F F DEGF DEGF LBIG OHM~ D~G? F F F F F F F F LB/F F F F LB/F F F F I.!B/F F F F DEGF DF.C-F LB/(; C3 OH~ OHM M DEGF STATE COUNTY INC6 0 0 0 44 0 ,0000 .0000 0.0000 0.000:0 O. 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S 98 636 21 0 14 b~, 9~ 635 21 0 ~4 ~PS 9~ 970 01 0 14 PSIG 98 814 00 0 14 P$IG 98 814 00 0 14 PSIG 98 814 00 0 14 98 814 00 0 14 99 814 00 0 14 98 814 00 0 14 9~ 814 00 0 14 98 814 00 0 14 9~ 8%~ O0 0 GAPi 99 310 00 0 14 DATA FO~ltAT RECORD *~ ]NTRY BI, OCKS TYPE SIZE REPR CODE 1 1 66 2 1 66 3 2 79 4 1 66 5 1 66 6 4 73 7 4 65 6 4 73 9 4 65 ~1 1 66 13 1 66 ENTRY 0 0 30 ~55 I ~i C }~ 33 :IN 73 0 SIZE SPL 4 1 2 1 2 4 1 2 1 2 1 2 1 2 1 2 1 2 1 2 2 1 2 1 ~NTRY 0 0 3O 255 0 31I 12 .!IN 33 1 0.0000 0.0000 REPR PROCESS CODE (OCTAL) 6'8 04000000000000 49 04000000000000 49 04000000000000 68 0~100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 04200000000000 04200000000000 49 04200000000000 49 04000000000000 IVP 010.H09,, VS]RIFICAT',[O?~ LISTINC PAGFi 86 15 16 I~T'I. Jr~ SPETCIFICATION BbOCKS [r,{E~! SEPVICE; SERVICE UMIT AP1 A:PI ID ORDER # I,OG TYPF :TIN RFT S 98 636 'ENS RFT [,B Qg 635 [SPE RFT RPS 9g 97~ ',GP RFT PSI(4 9~ 814 'RES ~'T PSIG 9~ 814 ',PRE RFT PSIG 9~ 81,~ ~D10 R¢T 98 814 'D20 RFT 9g 814 'ONE PF'T 98 814 ~TEN RFT 98 814 ~HU~I PFT 98 81~ ~T~O PFT ~8 8~ 4 ;R RFT G~PI 98 ~10 65 66 66 66 API A, PI FILet CLASS ~OD 2I 0 21 0 14 01, 0 1,4 00 0 O0 0 14 cio 0 1.4 o0 0 14 00 0 O0 0 1,4 00 0 14 00 0 00 0 1 00 0 SI . !IN 7 3 1 0 Z~ SPh REPR C 0 D E 2 1, 2 I, 9 4 1 68 2 I 49 2 I 49 2 I 49 2 I. 2 1 ~9 2 1 49 2 1 49 2 1 49 2 1 49 PROCESS (OCTAL) 04000000000000 04000000000000 04000000000000 04100000000000 04000000000000 04000000000000 04000000000000 04000000000000 04200000000000 04200000000000 Oa200000000000 04200000000000 04000000000000 DATa ]TIM 0.3000 TENS ~RES 3326,0000 RPRE ~ONE 0.0000 PTEN ;R 30.7969 ;TIM 198,6008 TENS ~RES 3330,0000 R~?~] >ONE 8,0000 PTEN ;R 89,0625 FgET ~ETERS 655!0,1,0~ 19967.4785 3t54 0000 MSPE: 3326.0000 PDIO 3.0000 PHUN FEET ~ETER8 65577 2344 19987.9~1q 3{54.0000 ~330.0000 2.0000 9. 500O 0. 0669 3,0000 8.7031 0.0669 3.0000 8GP PO2O P T b 0 SGP Pt)20 PTHU 3316.0000 0.0615 3.0000 3314.0000 0.0615 3.0000 i~, FlUE TRAII, F.R PILE ~ERVICE NAME :LOG /ERSICN ~ : 24,1 )~TE :g3/00/35 ~ILE ~:* FII.,E. ~'EADEP ** YP 010.H02 VERIFICATION bISTING PAGE 87 , INFDR,~ATION PECORDS *~ 'ABLE ?:YPE :AVER TS EX() EXO M ST~T,~ VALU EXPR ~I~,LO 3153.7500 (T~N$- T~NA ~ 0 OISA 1 LISA :0000 0000 ~ OISA ~,0000 3 DISA .0000 4, DIS~ O.O000 C) ALbO 0.0000 ..... RRO = 0 TYPE : WARN ~N~;~ STAT ~XP! LCON EXP2 FREO ACTI BELL VALU TS ~I,LO TS .AND ZERO 5 ~TSM riFF 0 WA00 LISA ZERO .AND ZERO 32767 ALAR OFF 0 WA01 LISA ZERO .AND ZERO 3276'7 ALAR OFF 0 WA02 OISA ZERO .AND ZERO 32767 AL~ OFF 0 W~03 DISA ZE~O .AND ZE~O 32767 AI~AR OFF 0 TYPE :TOO[, YP OIO.H02 VERiFICATIO~ LISTISiG PA, GE 8~ D T T .~ L L ~ F '~ ~ L b 0 S G W E; A L b 0 TYPE :COMS 0 O 0 214 708 0 60 87 214 MIN ~4 ST;~T BHS U~L CSIZ UN~L I H VD UN AL SD UNAL F N U ~ U:N ~ L FEX P U ~ Ab F P H I UN A L RPU UN'~L SGS 0 {iN ~:h PFTT ALhO TP~E UN~L SGSN UNAL T OFT UN T~'T UN ~,.L CV[)b UNAL PLgT UNAI, Leo 1 UNAL !5 C 02 U N A L LC 03 UNAL LC 04 U N AL LC05 UNAL LC 06 UN LC07 ,]NAb LC 08 UNAL LC09 UN'AL LC ~ 0 UNAL LC ~ t UNAL LC 12 LJN LC ~ ~ UNAL LC 14 LCd5 UNA5 bC ~ 6 tJ~'~AL bC 1, 7 UNAL LC ! ~ UNAL LC ! 9 UNAL LC20 Ub~AL l, C2 1 UNAL LC22 UNAL PUNI TUNI VAbU [)PEN I N I N 0 . 0000 1 F F 819~0000 '0000 2,0000 PHIX P~IG 1. OK FTgS BOTH DEGF DEGF 152.0000 FT FT 6902'9990 PSIA PSI~ 14,7000 DEGF DEGF 70.0000 PSIG PSIG 0 0000 5880~ SING $ S 53,0999 S S 84 3006 PRE~ HnRN VP 010.}~02 VF.P, IFIC.~TION' LISTING PAGE 89 .~OOL.STICKING* ,ALARM, .bLARE,OFF. BS UN~L IN IN 8,5000 [~w UNAL OHMM ~}H'M M I, 0000 KPDU UNAL FEE r tD~DU UNAL FEET ~U UMAL FEET P F U N: A b S H 0 R YEAR UNAL 1983 mO N T U'N ~ b 7 DAY UNAL 26 ABLE TYP~7 :COI S VP 010.H02 VERIFICA?IOM LISTING PAGE 90 APIN Og4 ~S5 TCS TN3 TN4 TN6 TN9 T~O ~N'll ~.:N ~ 2 SECT TOWN MATI CONT ~CSS CLAB CS2 CS3 L U ;¢ OPER L C C BLI TI.I E DF C~D1 F F F F F F F F LB/F F F F F F F F F F F F I,B/F F STATE COUNTY INC[, 0 0 0 440 0.0000 0.0000 0.0000 0.0000 0,0000 O,O000 0,0000 0.0000 0,0000 0,0000 0,0000 0.0000 VP 01.0 ........ H'02 VEP,'rFICATIO[~ t.,ISTI~I(',~ PAGE 91 0,0000 0.0000 0.0000 0,0000 0.000:0 0,0000 0,0000 0.0000 0.0000 0,0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 ,0000 ;0000 0.0000 0.0000 DATA FOR~,,tAT RECORD ',NTR Y B[,OCKS T'¥ PE 5 $ 7 9 13 14 !5 0 )ATUM SPECIFICATION INg~ SERV'ICE SERVICE r[[) ORDER ~ CTI~ RFT ~SP~: RFT ;GP RFT >PES PFT ~PRE RFT )DiO RFT >ONE RFT ~TEN S I Z REPR CODE 66 6'6 66 66 '13 '73 65 66 ~5 66 66 BLOCKS IJNIT ~PI APl API API FILE LOG TYPE ChAS$ MOD NO. 8 98 636 21 0 15 LB 9~ 635 21 0 15 RPS 9~ 970 O1 0 15 PSIG 98 814 O0 0 15 PSIG 98 814 OO 0 15 PSIG 98 814 00 0 15 98 814 00 0 15 98 81.4 O0 0 15 9~ 814 00 0 15 q~ 814 00 0 15 ENTRY 0 0 255 0 31.1 INCH 12 .lin ,~ 3 1 · 73 1 0 SIZE 4 2 2 4 ? 2 2 2 2 2 REPR PROCESS COOE (OCTAL) 6~ 04000000000000 49 04000000000000 ~9 04000000000000 68 04100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 40 04200000000000 VP 010.H02 VERIFiCATIO~! LISTING PAGE 92 'HUN R'FT FFT R FT 98 81.4 O0 0::15 814 O0 0 15 310 : O0 0 1 5 I 49 04200000000000 1 49 04200000000000 1 49 04000000000000 * DATa, FORe, AT RECORD ** :NTRY BLOCKS TYPE SIZE REP~ CODE 1 ~ 66 7~ 6 fi 11 1 66 ~ 65 )ATU~ SPECIFICATION !NE'~ SERVICE SERVICE ID ORDE~R ~ BLOCKS U k( I T AP~ API AP1 AP1FIbE LOG TYPE CLASS MOD NO. S 9~ 636 ~1 0 15 LB 98:635 21 0 15 RPS 98 970 01 0 15 PSIG 98 814 O0 0 15 PSIG 98 814 O0 0 15 PSIC 98 814 O0 0 !5 q8 814 O0 0 15 98 814 O0 0 15 98 8!~ O0 0 15 98 814 O0 0 15 q~ 814 O0 0 15 98 814 O0 0 15 GAPI 98 310 O0 0 15 SI ~NTRY 0 0 .] 0 I~CH 12 .,lIN .lin 73 ZE SPL 4 2 2 1 4 I 2 1 2 1 2 1 2 1 2 1 2 1 2 1 2 1 2 1 REPR PROCESS CODE (OCTAL) 68 04000000000000 49 04000000000000 49 04000000000000 68 04~,00000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 04~00000000000 49 04200000000000 49 04200000000000 49 04000000000000 DATA ** ,2TIM .~RES .~ONE ;R 0.3(;00 3196.0000 7.0000 31.109~ TENS ******** DEPTH ~******* FEET METERS 65510.1016 19967.4785 3120.0000 ~SPF 3196.0000 PDiO 9.0000 PHU~ 9.2500 0.0679 1.O000 **%***** FEET 65626.0859 DEPTH ******** 20002.8320 SGP 3183.0000 PO20 0.0615 PTHO 3.0000 VP 010.H02 V~TRIFICATIDN LISTING PAGE 93 TIM 342. 8987 TES.iS RES 31CJ6,0000 [luRE o. L 4,0000 P~EN R 15~.5000 * FILE TRAIL~P ILE N A ~}'F. :RFT 015 ERVICE NI~E ERSION ~ : 24.1 ATE :83/00/35 AXIMI..{~ LENGTH :102~], 'ILE TYPE EXT FILE 31.96,0000 PD!0 9.0000 PHUN EOF 13.0~59 0.0669 1.0000 ,. PD20 PT~O 3180.0000 0.0615 3.0000 * FILE MEgDER ** 'ILE ~g~ :RFT ;ERVICE Mi~E :LOG ~ATE :~3/00/35 [AXIMUg bENCT}~ :1024 'ILE TYPE :PR 'REVIOUS FILE ~ABLE 'IYPE : ~!FM STAT OUTP DCON VALU TENA ALLO TENS 2 0,0000 A¥OO DI. SA D[.I~M I 0,0000 aVO1 [)ISA DU~ 1 0.0000 AV02 DISA I')U~ t 0.0000 TYPE :EXPP STAT VALU I.,LO 3119,7 0 TENS - TENA DISA 0.0000 0ISA 0. 0000 DISA 0,0000 OISA 0. 0000 ~I,LO 0.0000 ZERO = 0 ,V~ 010,~02 VERIF.TCATIOtl LISTING PAGE 94 STAT EXPl bCON EXP2 F R El O A C T I B F i., L V A L U , .'"' ~!TSM OFF wgo0 ZERO , AND ZE~O wa 0 1 DISA ZEPO . A~ID ZERO 32767: AL~R OFF 0 OFF 'ABLE ~Y.. E .,~OOL ~'. E STAT bEN ,= . ...................... D T T A L L 0 0 0 0 ~FT ~bbO ~14 708 0 SGTE ALbO 60 87 214 ~ABI, E TYPE :CONS CSIZ IHVD SD FNUM FEXP FPHI RPU S~S.O ~,OFF RFTT APRE ,ATEM SGSM P~OD TOFT TPT CVOL PLOT LC01 bC02 LC03 STAT PUNI TUNI VALU UNAL OPEN UNAL IN IN 0.0000 UNAL 1 UNAL F F 8192,0000 UNAL 1,0000 UNAL 2.0000 UNAL PHIX UNAL PSIG UNAL IOK UNA5 FTES UNAL BOTH ~LLO DEGF DgGF 152,0000 UNAL FT FT 6876.0996 UNAL PSIA PSIA 14,7000 UNAL OEGF DEGF 70,0000 tJN~b PSIG PSIG 0.0000 UNAL 58809 [,]NAL SING UNAh S $ 50.6999 UNAb S S 24.6001 UNAL PRET UNAL HORN UNAL UNAL VP 01.0,H02 VERIFICATION LIMTING PRGF.; 95 UNAL UN:AL U ~,> A L IJ:N:g L U N A L U NAb UN~L U N A L U N A b UNAL U N A b U t~ A b UM Ab UNAL U N AL, [JN A UNA LbO , TOOL, STICKING* ALLO , ALARM. OFF. D IS A ~ ~ISA DISA STAT PI,JN I TUN I PUNI TUNi VALU IN IN 8.5000 OB~ OH:q~ 1 · 0000 FE~T FEET FEET SHOR ~983 7 26 Mt.3MM STAT PUNI TUN I V ALU R 1 UNAL R2 UNAL VP 0~O,k~02 VE~IFIC, ATICtM LISTIN('~ P~GE 96 FI; .1 L I,! L ~4GI WITN DFT LONG L~TI STAT C 0 U N PDAT APIN 0S3 0S5 TCS TN2 ~5Y3 TN ~ TN5 TN7 T~ TNIO TNll TN12 SECT TOWN RANG MATI CONT ~SS MFSS MCSS SLAB CLAM CS2 CS3 STATE COUNTY VP 010.H02 VERIFICATIOM LISTING PAGE 97 INCh 0 0 0 440 0,0000 0.0000 0.0000 0,0000 0~0000 0.0000 0.0000 0.0000 0,0000 0,0000 0,0000 0,0000 0.0000 0.0000 0.0000 0.0000 §:oooo 0000 0,0000 0.0000 0,0000 0,0000 0,0000 0,0000 0,0000 :oooo oo00 0.0000 0,0000 0.0000 0.0000 0.0000 0.0000 $I ZE 1 1 2 4 4 REPR CODE 66 66 79 66 73 65 73 65 T R Y 0 0 30 255 0 311 .1 i"i , VP n ~. 0, Fl 02 V F: !':E ..F. F I C ~ "i'' .l (,~ i'~.. t I S T .!' N G P A G F,. 9 B ,NE~ SF:RV T t") ~ ~ P E P F T ,GP 'RES E~P'T 'D10 F;FT ' D 2 O 'ONE 'Ng N~hi'~ ..... ' ' T H (') ~;' F' T CIF'IC,ITIr)~ IATU~ SPECIFICATION 1NEE SEPVICE SMRVIC? !D ORDER :TI~ RFT ~ENS RFT !SPY RFT ;GP RFT )RES RFT IPRF RFT 'DIO RFT '020 RFT ~ONE PFT :J & ('ii C K S UiqIT APl APl P~PI ~., ('.'~ G T Y P F; C 1.., ..~ S s 9~ 636 21 ~S ~q 970 'P S l G 9 ~,~ 8 1/~ o 0 PSIG 9:a 8~,~4 00 PSIC oR 814 O0 9~ 814 0o 9 '~ 8.1 4 0 9~ a~4 O0 9 ~ 814 00 G~PI 98 310 O0 ~;"YPF': SIZE 1 2 1 3 2 4 5 ~ 4 8 4 ~ 4 11 1 13 1 1.4 4 15 0 1 BLOCKS UNIT LB RPS PSIG PSIG PSIG ~PI API AP1 LOG TYPE CLASS 98 636 21 98 635 21 98 970 O1 98 814 O0 98 814 O0 98 814 O0 9~ ~14 O0 98 814 O0 98 8~.4 O0 66 66 '/9 66 66 73 65 73 66 66 65 66 66 66 SI 2 1 2 2 2 2 2 ~:hTRY 0 0 30 255 0 31.1 INCH 12 ,1IN 1 ,tin 73 0 AP1 FI£,E SIZE SPL MOD NO. 0 16 4 1 0 16 2 1 0 16 2 1 0 16 4 0 !6 2 0 16 2 1 0 16 2 1 0 16 2 1 0 16 2 I C 0 :() E 49 49 4:9 49 49 4 q, PROCESS {OCTAI, ) 0 ft 0000 C) 0400OuO0000000 0000000 00000000000 0~000000000000 0000000 040(.)nO00000000 r) 000000 0~200000000000 0~200{~00000000 49 04200000000000 4q 042(10000a00000 49 0400o000000000 REPR CODE 68 49 49 68 49 49 49 49 49 PROCESS (OCTAL) 04000000000000 04000000000000 04000000000000 04100000000000 04000000000000 04000000000000 o4000000000000 04000000000000 04200000000000 VP 010 H02 VBRIFIC.~rI[)~3 LISTING PAGE 99 TEN RFT HUN THO RFT ~ RFT 98 814 O0 0 16 O0 0 16 9~ 310 O0 0 16 1 49 04200000000000 1 49 04200000000000 1 49 042000000000:00 1 49 04000000000000 2990 TEE~ FEET 65510.1016 o:oooo o ******** DEPTH ******** ~TERS 20003'6973 3060,0000 3184.0000 PDiO ~,0000 PHUN * FILE TRAI'I, ER ** ERVICE NA~E :LOG 'ERSION ~ : 24.1 ,ATE :83/00/35 AXIt4UM LENCTP :1024 'TI, F, TYPF7 :PR {EXT FIbE N~MF : ********** EOF ********** ,8203 .0~79 1.0o0o ~.2656 0.0660 ~.0000 SGP 3i67,000 PD20 0.061~ [>THO 3.0000 SGP 3169,0000 PD20 0.0615 PTHfl 3,0000 :* FII,E ~EADER ** 'ILE ~A~E: :RFT .017 ;ERVICE i~iS~ :LOG ~'rE ~3/00/35 IAXIMUN LENGTH :1024 '!LE TYPE :PA ~REV!OUS FILE : :* INFORMATION RECORDS ** ~ABL, E T'~PE :AVER U, NK~ STAT OUTP DCON VAL[ q'ENA ~LL[] TENS tVP 010.M~02 VERIFICATION LISTING PAGE 100 AV00 AV021 ~ V 0 'ABLE TYPE DI:SA DUMM 1 0,0000 LISA ~UMM 0.0000 LISA UMM 0,0000 .RXPR TS EXO0 ~X01 ~X06 Ebb0 311~ 7500 :ISA .'0000 )ISA 5:iS~ .0000 LISA g,O000 .000:0 ~bhO 0.0000 ( TENS - TENA * ZERO = 0 'ABLE TYPE TS ~LLO TS .A~D ZERO 5 :WTS~ OFF 0 t,~00 LISA ZERO .AND ZERO 32767 AL:AR OFF 0 w~01 LISA ZERO .A~D ZE~O 32767 ~LAR OFF 0 wA02 LISA ZE~O .AND ZERO 32767 ALAR OFF 0 WA03 DISA ZERO .AND ZERO 3~767 ALAR DFF 0 ?~BLE TYPE :TOOL ~ggM STAT LENG WEIG HEIG DTT ALLO 0 0 0 RFT ~LLO 214 70~ 0 SGTh: ~ LLO 60 87 214 ~FM STAT PUNI TUNI VALU CSTZ I)N~L iN IN 0,0000 I~VI) UNAb SD []NAL F F 8192.0000 FNIiM IINAI, 1,0000 FEYD UNIL 2.0000 VP O10.H02 YE~IFIC~TiON. LIS..IN¢';' T PAGE 101. DEsF DEGF PSIh PSIA DEGF PSIG P$IG $ S PHiX PSIG iOK LOG BOTH 15~ 0000 1.g,7000 7 ,0000 0,0000 588091 SING 1,1~'1974 59.7004 HOrN ,TOOL.STICKING* ,ALARM, .ALARM.OFF. STAT PU t41 TIJ ;,i I ~"{ N Fi M ST:A T PlJ N I TU t~ I V ALU "' ' 'S ' ¢" VP 0~0,~O~ VF]RIFIC,ASI, O~ LI,,~IN'G PA,,~; 102 ~BLE ..... YP..F., : COI~{S SON Ri ~2 ~3 ~ID'E L U L W DFW LATI STAT COUN PDAT O83 OS4 OS 6 TCS T~; 5 TM 6 T~] 7 IN IN OH~N OHMM ,5000 8,~ooooi FEE FEET F E E T SHOR 19R3 2,6 STAT PUNI TUNI VALU UN~L ~ UN U ~f A L UN'AL UMAL UN~L I,JN'AL UNAL UN~I, UNA L I~NAL UNAL UN ~L UNAL UN~L U ~,~,L VP 010.NO2 VERIFIChT!ON LISTING PAGE J03 TN9 TN 10 TN~11 TN!2 SECT TOWN NATI CONT ~CSS SLAB CL.~B CS3 ~LD P UN L U N OP~R LCC ~L I ~DF' Ef;b T D TBL ~SD1 CBD1 CW~ BSa2 CBD2 9SD3 CbD3 CBL3 STF~ DFV DFL PMFS U N ~ L UN:AL UNAL Ul'q :A L U N g. L, UNAL U N A L U N ~. L UN A L ~NAL UNAL J N .,~ b l:l N :A L: IJNAL I.INAL lin AL UNAb U N A L U N h L dN ~,L UNAL UNAL U rt ~ L UNAL t! N ,h b UNAL UNAL U N AL U N h L tfN ~L UNAL UNAL UN AL F F F F F F F L,B/F F F LB/F F F LB/F F F F DEGF OEGF LB/(; S C3 F F F F F F F F I,B/F F F' F LB/F F F F I,B/F F F F DEGF DEGF LB/G S C3 STATE C 0 U g T Y I M ~ L 0 0 440 0.0000 0.0000 O.O00O 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0,0000 0o0000 0.0000 0,0000 0,0000 0.0000 0,0000 0.0000 O.000O 0.0000 0.0000 0,0000 0.0000 0,0000 0,0000 0,0000 0.0000 0,0000 0.0000 bVP 0.10,[t02 VMPlFICATION I',ISTIMG PAGE !04 RM$ UNAL OHMM OHI~!~ 0.0000 RqCS !}MIL OH~M OHM? 0,0000 MST I.INAh DEGF DEGF 0,0000 ~FST UNAL DEGF DEGF 0,0000 ~CST UNAL DEGF DEGF 0.0000 ** FILE TRAILER ** FILE NAa~ :RFT ,017 SERVICE NAME :bOG VERSIOD ~ : 24.! DATE :83/00/35 M~XI~U~ LENGTH :1.024 FILE TYPE :PR NEXT FIL~ N~E : ********** EOF ********** ********** EOF