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195-049
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~- ~ OL~c)' File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by: Bevedy~Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by~ianna Vincent Nathan Lowell Date: ' ' / • OF rke THE STATE kiLacke. Clac stx 333 West Sevenih Avenue IltIrtGOVERNOR SEAN PARNELI_ Anchorage, Alaska 99501-3572 Main: 907.279.1433 04tg Fox: 907 276 7542 SCANNED JUN 2 7 2014 James Ohlinger CTD Engineer 5- ©T ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-32 Sundry Number: 314-146 Dear Mr. Ohlinger: 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, Daniel T. Seamount, Jr. Commissioner DATED this 1 7 day of March, 2014. Encl. • STATE OF ALASKA RECEIVED ` 1 AL A OIL AND GAS CONSERVATION COMM, ON APPLICATION FOR SUNDRY APPROVALS MAR 1 0 2T 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill . Perforate New Pool r Repair w ell r Chang/4/(1=m !— Suspend r Rug Perforations (7 . Ferforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: (- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 195-049 - 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20218-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 2T-32 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25549 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13787 . 6057 13696' • 6004' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 121' 121' SURFACE 4715 9.625 4752' 2845' PRODUCTION 13740 7 13777' 6051' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13392-13430 • 5806-5830 3.5 L-80 13298 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER SAB-3 PERMANENT PACKER MD=13270 TVD=5730 NIPPLE-CAMCO'DS'LANDING NIPPLE MD=516 TVD=516 - 12.Attachments: Description Summary of Proposal 17,7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r— Exploratory r Stratigraphic r Development r Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/1/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265-1102 Email: James.J.Ohlinger0,conocophillips.com Printed Name J S OhlinTitle: CTD Engineer Signature iA � � Phone:265-1102 Date 3�-7��<� //•' • Commission Use Only 4 Sundry Number: c� Conditions of approval: Notify Commission so that a representative may vi{►�DMS MAY 11 201 3 vy—V -k lQ Plug Integrity r BOP Test ('°"Mechanical Integrity Test r Location CI arance r Other: Bop fc 5 to 400 0 p 5- ) Al fri-r) a- tc P !v l4ct :' app • �� c �� ,�, C 2S. 11Z (t l'' Spacing Exception Required? Yes ❑ No lif Subsequent Form Required: i( —- 7 0 -f APPROVED BY1,) , i Approved by ,ate/ ' COMMISSIONER THE COMMISSION Date: )j� • y '� / Approved a p at 0C IIS date of approval. Form 10-403(Revised 10/2012) ViNt04.cionyki,-roglittohi7 Submit Form and Attachments in DuplicateVI-F 3/l9 /14 d'A- -c c 3A\c KRU 2T-32 CTD Summary for Perfing & Plugging Sundry (10-403) Summary of Operations: Well 2T-32 is a Kuparuk A-sand injection(service)well equipped with 3'/2"tubing and 7"production casing. Two laterals from well 2T-32 will be drilled to the East(2T-32A)and to the West(2T-32AL1) side of parent well 2T-32 to improve parent well injectivity and provide support to offset CTD producers 3G-21A and 2T-40. The eastern lateral from 2T-32 will provide injection support to 3G- 21A, a CTD producer to the north of 2T-32. The western lateral will provide injection support to CTD producer 2T-40. Both of these laterals will primarily target the A2 Sand. The D-Nipple located at 13,286' MD will have the ID milled out to a 2.80"to allow the drilling assemblies access through the tubing tall. The tubing tail will also be perforated prior to cementing to allow cement between the 3-1/2"tubing tail and 7"casing. Prior to drilling,the existing A-sand perfs in 2T-32 will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A& C-sand perfs in this manner. After plugging off the existing A-sand perfs with cement,a mechanical)yhipstock will be placed in the 7"casing at the planned kickoff point. The 2T-32A and AL1 sidetracks will exit through the 7"casing at 13,393' MD and will target the A2 sands east and west of the existing well. The laterals will be completed with 2-%" slotted liner from TD with the liner top located inside the 3'/2"tubing at 13,291' MD. 46. rd Of l w / �'.*paw ,We ''vit $ elf foe ti0^ OF The- foo am Sid giy k;O :ocnq'e U/tk••*4x i Owe/. CTD Drill and Complete 2T-32 Laterals: April 2014 Pre-CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T&IC 3. MIT-IA 4. RU slickline. Tag PBTD and obtain SBHP 5. RU coil: Mill(13,286' MD)Camco D-Nipple ID to 2.80" 6. E-Line: Perforate the 3-1/2"tubing tail from 13,280' — 13,285' MD 7. RU coil: Cement Squeeze A-sand perforations, and fill 7"annulus 8. RU slickline. Tag top of cement and pressure test. 9. Prep site for Nabors CDR2-AC, including setting BPV Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) A static bottom hole pressure of 2T-32 in January 2014 indicated a reservoir pressure of 4084 psi or 13.5 ppg equivalent mud weight. The maximum down hole pressure in the 2T-32 pattern is at 2T-02 with 4326 psi. It is not expected that reservoir pressure as high as 2T-02 will be encountered while drilling the 2T-32 laterals because of offset distance and faulting. Using the 2T-32 pressure as the maximum possible, the maximum possible surface pressure assuming a gas gradient of 0.1 psi/ft,would be 3502 psi. Page 1 of 2 3/6/2014 Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2T-32A Sidetrack(A2 sand-East) 'J L5 v vi(tv a. Drill 2.80"high-side pilot hole through cement to 13,443' MD b. Drift pilot hole with whip-stock dummy c. RU Slickline—caliper pilot hole d. Set whip-stock at 13,393' MD with high-side orientation e. Mill 2.80"window at 13,393' MD f. Drill 2.74"x 3.0"bi-center lateral to TD of 15,800' MD g. Run 2%"slotted liner with an aluminum billet from TD up to 13,890' MD 3. 2T-32AL1 Lateral(A2 sand-West) a. Kick off of the aluminum billet at 13,890' MD V rip b. Drill 2.74"x 3.0"bi-center lateral to TD of 13p.OLINIQ ) c. Run 2%" slotted liner from TD up to 13,291' MD, inside the 31/2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pu11 BPV 2. Obtain static BHP. Install GLV's. Page 2 of 2 3/6/2014 . i KUP INJ 2T-32 Conocor'hillips : Well AttributesMax Angle&MD TD "' Alaska,Inc. wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • y� 501032021800 KUPARUK RIVER UNIT INJ 73.85 4,462.73 13,787.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) •'Rig Release Date I 2T-32,10/2/2013 9.05.05 AM SSSV:NIPPLE Last WO: 5/1/1995 • Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 13,377.0 9/1/2013 Rev Reason:WELL REVIEW osborl 10/2/2013 Casing Strings IIII Casing Description OD(in) ID On) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread =]I[ SURFACE 9 5/8 8.835 37.0 4,752.0 2,845.2 40.00 L80 BTC Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread HANGER:36.8 '1 PRODUCTION 7 6.276 37.0 13,777.0 6,050.6 26.00 L-80 BTC-MOD I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection • TUBING 31/2 2.992 36.8 13,297.7 5,747.5 9.30 L-80 ABMEUE Completion Details .M8 CONDUCTOR;38.0.121.0 ` "fit✓` Nominal ID fp Top(ftKB) Top(ND)(ftKB) Top Inot(°) Item Des Corn (In) 36.8 36.8 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 516.3 516.3 1.65 NIPPLE CAMCO'DS'LANDING NIPPLE w/2.856"NO GO 2.812 13,220.4 5,700.8 53.52 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO W PROFILE 3.813 (CLOSED 10/20/1995) NIPPLE;516.3 Ei - 13,268.6 5,729.8 52.70 ANCHOR K-ANCHOR RUN w/PACKER 3.250 13,269.5 5,730.4 52.69 PACKER BAKER SAB-3 PERMANENT PACKER(seal attached) 3.250 13,285.6 5,740.1 52.49 NIPPLE CAMCO'D'LANDING NIPPLE w12.795"NO GO PROFILE 2.750 13,296.8 5,747.0 52.35 SOS BAKER SHEAR OUT SUB-TTL ELMD @ 13283'on 2.992 SWS PERF 10/18/1985 Perforations&Slots Shot Dens IT Top(ND) Btm(ND) (shotsff GAS LIFT;2,215.1 L : Top(ftKB) BM)(ftKB) (ftKB) (ftKB) Zone Date t) Type Com ♦r 13.3920- 13,430.0 5,805.9 5,829.9-A-2,21-32 10/19/1995 4.0'IPERF 21/8"Enerjet;0deg. phasing;alternating BH/DP charges Mandrel Details St ati C SURFACE;37.04,752.0 a on Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model _OD(in) Sery Type Type (in) (psi) Run Date 1 2,215.1 1,971.9 CAMCO MMM 1 1/2 GAS LIFT DMY RK - 0.000 0.0 9/16/1995 Notes:General&Safety End Date Annotation __ 5/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SLEEVE-C;13,220.4 {fI'7I1f IJ _ ANCHOR;13,266.6 11:11 -t 1-rQ-r PACKER;13,269_5 a 471 r NIPPLE;13,285.6IN SOS:13,2968- IPERF,13,3920-13,4300- PRODUCTION;37.0.13,777.0 • • k 0I3 / )/\ . a \_ G a) / \ \ § o CO _ _ \ /N 03� \j�\ / § / \ / / \ _ k4H0 \ � \ > // co 0_ / # _H / \ $ \ CD ti �§ o a D, 11 k / / ) R2 § / • CO \ / \ CO \ \ \ / \ mm A m = = nn :5 i � , .. - . — ii 1 1 474.111.1 A i 1 C S ckI i g — w .. 13 U , „. IR §_ CD 1 ! oco «/ a S § o CV \e al io \) \§ 9| \c (� \ $k f\ ',to / \ = co N.- - � § Y on §\ �� [ ƒ%\\ G±(G • Wallace,Chris D (DOA) From: Wallace, Chris D(DOA) Sent: Monday, October 07, 2013 2:30 PM To: 'NSK Problem Well Supv' Subject: RE: Report of suspected surface casing leak 2T-32(PTD 195-049) 10-07-13 Kelly, Approved for 30 day injection period. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer ENE D(„E, 0 it 201 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.gov From: NSK Problem Well Supv [mailto:n1617@)conocophillips.com] Sent: Monday, October 07, 2013 11:26 AM To: Wallace, Chris D (DOA) Subject: Report of suspected surface casing leak 2T-32 (PTD 195-049) 10-07-13 Chris, Kuparuk WAG injector 2T-32(PTD#195-049)is suspected of having a surface casing leak at 318'based upon a SLID(surface casing leak detect)which was performed yesterday. The well was being investigated for a possible CTD sidetrack. Therefore,in addition to a recent gyro survey and caliper,packoff testing was already completed on 9/24/13. As part of the 4 yr pad testing on 06-01-13,a passing waived-witnessed MITIA to 1950psi was performed. In anticipation of the probable AA requirement,CPAI recommends an MITIA to the higher maximum anticipated pressure be performed prior to submitting the AA request that we intend to pursue. CPAI requests permission to leave the well on line for 30 days in order to obtain the MITIA and write up the AA request. The well will be added to the monthly report. Attached are the 90 day TIO plot and schematic and MIT data. 1 • • - CHOKE FTP FTT IAP - OAP T/II0 Plot-2T-32 - • 2500 - 2000 1500 a. 1000 . 500 III ! ! ! -I I I + 441 f I III I 4 II 07-Jul-13 20-Jul-13 02-Aug-13 15-Aug-13 28-Aug-13 10-Sep-13 23-Sep-13 Date Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907) 659-7000 pgr 909 2 • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~~v~Q ~~U~ ~ ® Z~~1..) j~~~i ~ ~ G8s ~~ ~t]~`(1Cr11SStGt~ A~c'~~r~op igs,o~ ~-~- 3 ~' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRT~. Each of these wells was found to have a void in the conductor. These voids were filled with 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 corrosion inhibitor/sealant was pumped July l lth, 12th, 13th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, 1 Perry Klein 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 7/16/10 2T_ 3H PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2T-22 50103202240000 1950860 8" n/a 8" n/a 3.8 7/12/2010 2T 23 50103202160000 1950320 8" Na 8" n/a 2.1 7/12!2010 2T-27A 50103202170100 2090900 7" n/a 7" Na 1.7 7/12/2010 2T 82 501032021$0000 1 X0490 36" Na 36" Na 11.9 7/12rL010 2T 37 50103202270000 1951010 22" Na 22" Na 2.5 7/11/2010 2T-38A 50103202290100 1972050 8" n/a 8" Na 1.7 7/11/2010 2T-203 50103205200000 2051970 22" n/a 22" Na 5.1 7/13/2010 2T-208 50103205180000 2051870 13" Na 15" n/a 2.5 7/13/2010 2T-210 50103202730000 1982030 18" Na 18" n/a 5.1 7/12!2010 2T-217A 50103203340100 2000740 8" n/a 8" n/a 1.7 7/12!2010 3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/11/2010 MEMORANDUM To: JimRegg ~~~ 6~I6~0~( P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-32 KUPARUK RIV UNIT 2T-32 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~a~ Comm Well Name: KUPARUK RIV UNIT 2T-32 Insp Num: mitJJ090608130049 Rel Insp Num: API Well Number: 50-103-20218-00-00 Inspector Name: Jeff Jones Permit Number: 195-049-0 ~ Inspection Date: 6/1/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P.T.D 2T-32 1950490 Type Inj. i N , TVD TypeTest sPT Test psi 5736 ~ IA ~ 1500 ~ OA 600 360 1900 ~ 1830 1810 ! 360 360 360 Interval 4YRTST P~F P / TUbing 1]50 ]150 1150 1150 NOtes• 2.4 BBLS diesel pumped, 1 well inspected; no exceptions noted. +uw~ >. 'J V .i Wednesday, June 10, 2009 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ?ê~cJ b/7(Ù 7 P.l. Supervisor I) ~ r ( DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-32 KUPARUK RIV UNIT 2T-32 Src: Inspector <J~~ \0( FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: r-'§2- P.I. Suprv .:J Comm Well Name: KUPARUK RIV UNIT 2T-32 API Well Number: 50-103-20218-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603145603 Permit Number: 195-049-0 Inspection Date: 6/2/2007 .....--- Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-32 Type Inj. N TVD 5736 I IA 500 2540 2470 2470 P.T.D 1950490 TypeTest SPT Test psi 1500 lOA 80 200 150 120 Interval 4YRTST P/F P ¿/ Tubing 2575 2575 2575 2575 Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. / SCANNED JUN, 2 o 20tH Wednesday, June 06, 2007 Page 1 of 1 ( MEMORANDUM :( .~ State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner 110;> SUBJECT: Mechanical Integrity Test THRU: Jim Regg~¿'4{) )I \ 1[;\ Conoco Phillips P.I. Supervisor II 2T Pad KRU DATE: November 1 , 2003 FROM: Chuck Scheve Petroleum Inspector NON. CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 2T -32 Type Inj. N T.VD. 5736 Tubing 3600 3600 3600 3600 Interval 4 P.TD. 195-049 Type test P Test psi 1434 Casing 150 2460 2400 2400 P/F P Notes: Well 2T-21 0 Type Inj. N T.VD. 3009 Tubing 600 600 600 600 Interval 4 P.TD. 198-203 Type test P Test psi 752 Casing 0 1940 1920 1920 P/F P Notes: Well Type Inj. T.VD. Tubing Interval P.TD. Type test Test psi Casi ng P/F Notes: Well Type Inj. T.VD. Tubing Interval P.TD. Type test Test psi Casi ng P/F Notes: Well Type Inj. T.VD. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to Conoco Phillips 2T Pad in the KRU and witnessed the routine 4 year MIT on wells 2T -32 and 2T -210. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then perfonned with both wells demonstrating good mechanical integrity. M.LT.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 2 hours cc: . - ...~",.,..-~~. Ð'..E'.C.'i> (,1).111 20.01) I ' . '.. Î" I '\1J) ~,.""","~'~"'. ~.l":" ,'", "', ,.. 1 ~ .., MIT report form 5/12/00 LG. MIT KRU 2T 11-1-03 CS.xls 11/20/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuld KRU/2T 11/01/03 Sauvageau / Brake C Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well12T-32 I Typelnj I Np I T.V.D. I 5736 I Tubingl 36001 36001 35501 35501 Interval P.T.D.I'1950490 TypeTest Test psiI 1500 I Casing I 1501 24601 24001 24001 P/F Notes: Well SI for reservoir P reduction OA 350 500 475 475 P.T.D.I'1982030 Type Test TestpsiI 1500 I Casing I 01 19401 19201 19201 P/F Notes: Well SI for reservoir balance OA 300 600 600 600 P.T.D.I Notes: Type Test Test psi 1500 Casing Interval P/F Interval P.T.D.I Notes: Type Test Test psi 1500 Casing P/F Interval P/F P.T.D. I Type Test Test psi Notes: I Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 KRU MIT 2T 11-01-03.x15 11/3/2003 'i 0 -,~ 4t O 7 .& i'" e d I'" y OAII...Y WELL OF'E, ,.,,, d'¥'tch SalTIp'l~as ;~,,t a s -i: h e w e 'i 1 c.: o r" e d ? Ar"e v,,:e'J 'J 'ilest:s I'"~4:ciU'¥t''',.::~.~: . yes C ()?4H E i'-.J. T S ARCO Alaska, Inc. Post Office Sox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 i215 September 13, 1996 Blair Wondzell Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Sub!ect: KRU Well 2T-32 Injector, Isolation of Kuparuk Reservoir Dear Mr. Wondzell: The following historical and monitored data on KRU Well 2T-32 has been compiled in response to your query concerning this IWAG injector. Historical: KRU 2T-32 was drilled without problems aside from brief packing off that occurred while drilling at 13,238' MD above the Kuparuk. All trips before and after this point occurred without incident. The cement job went very well until the hole packed off and stuck the pipe during the pre-cementing circulation with casing on bottom. (See attached Cementing Details.) No returns were observed for the rest of the job although good pump rates were maintained and the final job pressures indicated cement had been pumped well up the annulus. Calculated cement top is at 12,503' MD. · The well was logged with a Schlumberger SLT-J cement bond log on 10/19/95. The high deviation of the well (>72°) led to pumping the slim bond log tool down the tubing after running the completion, as previous efforts to run the CBLs in cased-only high-angle wells had been unsuccessful. Good cement was seen from 13430' to the PBTD. Poorer quality cement was noted above this to the tubing tail at 13,280', with no information available beyond this depth due to the interference of the completion. The top of the C Sands is at 13,378' MD. · The 9-5/8" x 7" annulus was not Arctic packed. The annulus was left freeze-protected with diesel. Well Monitoring (ongoing since completion by Nordic Rig 1): · The daily drill site report, which reflects daily or every other day observations, shows that the 9-5/8" x 7" annulus has remained constant at 700 to 800 psig since the well was put on injection. (Please see attached data sheets and chart.) · During the same time period the 7" x 3-1/2" annulus has been relatively stable although it varies depending on whether we are injecting water or gas. These variations are due to temperature differences between the injectants. (Please see attached data sheets.) · There are no entries for the well in the Kuparuk "problem annulus" log, nor does the operator know of any communication or gas to surface problems. Based on the above data and observations, the Kuparuk appears to be isolated with cement above the depths seen with the SLT-J bond log. Cementing pressures indicated that cement was pumped up the annulus after packing off occurred. The 9-5/8" x 7" annulus has been left open to the surface with diesel on the backside, and no unusual pressures or pressure fluctuations have been noted. There also do not appear to be any other signs of leaks through the 7" x 3-1/2" annulus or around the 9-5/8" casing to surface. RECEIVED SEP 1 G 199G Alaska 0il & Gas Cons. Commission Anchorage AR3B-6003-93 2,i2 2603 This well will continue to be monitored through the Kuparuk Data Gathering System and operator observations for any unusual behavior. If there are any questions or concerns please contact me at 263-4183. Thank you, Denise Petrash Drilling Engineer 4 attachments CC: KRU Well File 2T-32 (W1) W. S. Isaacson B. O'Dell/J. Rugen ATO-370 ATO-1290 NSK 14 RECEIVED SEP 1 G 1996 Naska Oil & Gas Cons. Commission Anchorage ARCO Alaska, inc. Well#: Cementing Details Casing Size 7 ' 2T-32 Field: KUPARUK I Date: 4/30/95 HoleDiameter HoleAngle I Sh~Depth, FIo. atDept_h/, %washout 8.5" 52° ]~,~-~ /~7~.~ 19"~t~ t'~b~L9 ] State type used, intervals covered and spacing Bow spring cents, in center of first two its. and on collars of next 21 its. Centering guides through the build section, 19 total. Centralizers Mud Spacer Lead Cement Tail Cement Displacement Weight 1 0.7/1 0.7 Gels before Type PV(after cond)IYP(prior cond) 131 IPV(prior cond) 3/4Gels after Total Volume Circulated 420 BBLS. at 3-6 BPM. Volume 20/50 BBLS. No. of sacks PREFLUSH/ARCO SPACER ;Type IMix wtr temp none I Additives NONE Type IMix water temp G 165° IClP - 4/30/95 2130 hrs. Weight Calculated top of cement 12,503 No. of sacks I Weight 23OI 15.8 PPG YP(after cond) 13 Weight 8.34/12.5 Additives 0.1gps D47, 3% D53, 0.7% D65, Rate(before tail at shoe) Rate(tail around shoe) 5.1 BPM 5 BPM Reciprocation length Reciprocation speed N/A N/A FPM Theoretical Displacement Actual Displacement 523 BBLS. 535 BBLS. Bumped plug Floats held Yield Yield 1.19 0.1gps D135, 2 gps D600, 0.1% d800 Str. Wt. Up stuck Str. Wt. Down Str. Wt. in mud Remarks- Include whether full returns were obtained, recmprocation throughout operation and any other pertinent information. Had full returns with casing on bottom. Slowly increased circulation rate to 6 bpm w/full returns. After pumping 186 bbls. the hole packed off and stuck casing. Could not pull casing free or regain circulation. Well broke down at 1700 psi. Pumped an additional 234 bbls. at 4.2 bpm, 1100 psi. while Dowell mixed cement. Pumped job per plan. Pumping at 5 bpm, 1670 psi when cement left shoe, had 1940 psi at 2.7 bpm at end of job. Pumped 12 bbls. over without bumping plug. Bled back 3 barrels. Displaced with 90 bbls. diesel followed by 445 bbls. sea water. Cement Company I Rig Contractor Dowell I Parker r' ~gnature R E C E IV L. Mort'son 699 Oo~. 6omm, issio~ 2T-32 Inj Rates & Pressures Water Gas 7" x 3-1/2" 9-5/8" x 7" WHIP WHIT Vol Vol Press Press Date (psig) (°F) Fluid (Bbl) (MSCF) (psig) (psig) 10/21/95 0 0 SW 1039 0 0 0 10/22/95 2452 46 SW 717 0 0 0 10/23/95 2470 45 SW 617 0 300 850 10/24/95 2448 46 SW 564 0 300 850 10/25/95 2455 45 SW 508 0 300 850 10/26/95 2422 47 SW 447 0 300 850 10/27/95 2425 44 SW 436 0 400 800 10/28/95 2429 53 SW 431 0 400 800 10/29/95 2360 52 SW 404 0 400 800 10/30/95 2243 51 SW 407 0 400 800 10/31/95 2394 52 SW 391 0 400 800 11/01/95 2444 54 SW 802 0 400 800 11/02/95 2471 48 SW 1379 0 400 800 I 1/03/95 2468 50 SW 1294 0 425 825 I 1/04/95 2423 44 SW 1112 0 425 825 11/05/95 2428 41 SW 1127 0 425 825 11/06/95 2424 42 SW 1118 0 425 825 I 1/07/95 2402 42 SW 1037 0 250 825 11/08/95 2414 46 SW 997 0 250 825 11/09/95 2413 47 SW 1060 0 325 800 11/10/95 2417 48 SW 1051 0 325 800 11/11/95 2424 48 SW 1042 0 325 800 11/12/95 2441 45 SW 1064 0 325 800 11/13/95 2425 46 SW 1074 0 325 800 I 1/14/95 2372 43 SW 938 0 325 800 11/15/95 2434 45 SW 1009 0 325 800 11/16/95 2373 45 SW 952 0 325 800 I 1/17/95 2444 44 SW 970 0 325 800 11/18/95 2421 44 SW 1018 0 325 800 11/19/95 2420 43 SW 899 0 325 800 11/20/95 2387 42 SW 879 0 325 800 11/21/95 2162 42 SW 893 0 325 800 11/22/95 2196 41 SW 846 0 325 800 11/23/95 2239 38 SW 770 0 325 800 11/24/95 2459 45 SW 932 0 325 800 11/25/95 2205 43 SW 919 0 325 800 11/26/95 2441 44 SW 1090 0 325 800 11/27/95 2340 49 SW 497 0 325 800 11/28/95 2305 47 SW 872 0 325 800 11/29/95 2394 43 SW 892 0 325 800 11/30/95 2433 44 SW 868 0 325 800 12/01/95 3925 53 Gl 500 0 325 800 12/02/95 3919 58 Gl 500 0 325 800 12/03/95 3931 55 Gl 500 0 325 800 12/04/95 3934 54 Gl 500 1 850 800 12/05/95 3934 64 Gl 500 1 850 800 12/06/95 3924 60 Gl 500 1 850 800 12/07/95 3837 60 Gl 500 1 850 800 12/08/95 3902 68 Gl 500 1 850 800 Page 1 of 6 2T-32 Inj Rates & Pressures Water Gas 7" x 3-1/2" 9-5/8" x 7" WHIP WHIT Vol Vol Press Press Date (psig) (°F) Fluid (Bbl) (MSCF) (psig) (psig) 12/09/95 3913 68 Gl 500 1 850 800 12/10/95 3883 60 Gl 500 I 850 800 12/11/95 3915 71 Gl 500 1 850 800 12/12/95 3855 58 Gl 500 1 1000 800 12/13/95 3876 64 Gl 0 2 1000 800 12/14/95 3904 63 Gl 0 2 1000 800 12/15/95 3881 61 Gl 0 2 1000 800 12/16/95 3785 61 Gl 0 3 1000 800 12/17/95 3792 58 Gl 0 2 1000 800 12/18/95 3852 46 Gl 0 3 1000 800 12/19/95 3866 55 Gl 0 3 1000 800 12/20/95 3853 58 Gl 0 3 1000 800 12/21/95 3882 61 Gl 0 3 1000 800 12/22/95 3880 65 Gl 0 3 1000 800 12/23/95 3898 65 Gl 0 3 1050 850 12/24/95 3903 72 Gl 0 3 1050 850 12/25/95 3876 75 Gl 0 3 1050 850 12/26/95 3874 69 Gl 0 3 1050 850 12/27/95 3888 69 Gl 0 3 1050 850 12/28/95 3881 62 Gl 0 3 1050 850 12/29/95 3883 62 Gl 0 3 1050 850 12/30/95 3879 61 Gl 0 3 1050 850 12/31/95 3881 68 Gl 0 3 1050 850 01/01/96 3860 74 Gl 0 3 1050 850 01/02/96 3855 71 Gl 0 3 1050 850 01/03/96 3896 78 Gl 0 3 1050 850 01/04/96 3938 76 Gl 0 3 1150 800 01/05/96 3890 73 Gl 0 2 1150 800 01/06/96 3900 68 Gl 0 2 1150 800 01/07/96 3888 61 Gl 0 2 1150 800 01/08/96 3891 66 Gl 0 2 1150 800 01/09/96 3888 61 Gl 0 2 1150 800 01/10/96 3888 61 Gl 0 2 1150 800 01/11/96 3876 65 Gl 0 2 1150 800 01/12/96 3863 68 Gl 0 2 1150 800 01/13/96 3857 69 Gl 0 2 1150 800 01/14/96 2790 36 Gl 0 0 1150 800 01/15/96 3806 56 Gl 0 1 1150 800 01/16/96 3872 59 Gl 0 1 1150 800 01/17/96 3899 59 Gl 0 1 1150 800 01/18/96 3901 54 Gl 0 1 1150 800 01/19/96 3900 59 Gl 0 1 1150 800 01/20/96 3901 59 Gl 0 1 1150 800 01/21/96 3897 63 Gl 0 0 1150 800 01/22/96 3896 64 Gl 0 0 1150 800 01/23/96 3827 58 Gl 0 0 1050 800 01/24/96 3813 60 Gl 0 0 1050 800 01/25/96 3739 58 Gl 0 0 1050 800 01/26/96 3827 40 Gl 0 1 1050 800 Page 2 of 6 2T-32 Inj Rates & Pressures Water Gas 7" x 3-1/2" 9-5/8" x 7" WHIP WHIT Vol Vol Press Press Date (psig) (°F) Fluid (Bbl) (MSCF) (psig) (psig) 01/27/96 3867 53 Gl 0 1 1050 800 01/28/96 3872 59 Gl 0 1 1050 800 01/29/96 3859 59 Gl 0 1 1050 800 01/30/96 3862 60 Gl 0 1 1050 800 01/31/96 3860 54 Gl 0 1 1050 800 02/01/96 3856 52 Gl 0 1 1050 800 02/02/96 3850 43 Gl 0 1 1050 800 02/03/96 3935 55 Gl 0 2 1050 800 02/04/96 3958 61 Gl 0 3 1050 800 02/05/96 3929 56 Gl 0 2 1050 800 02/06/96 3933 59 Gl 0 2 1050 800 02/07/96 3917 55 Gl 0 2 1050 800 02/08/96 3897 51 Gl 0 2 1050 800 02/09/96 3887 45 Gl 0 2 1050 800 02/10/96 3901 49 Gl 0 3 1050 800 02/11/96 3900 53 Gl 0 3 900 800 02/12/96 3897 49 Gl 0 3 900 800 02/13/96 3890 44 Gl 0 3 900 800 02/14/96 3894 64 Gl 0 3 900 800 02/15/96 3893 66 Gl 0 2 1000 750 02/16/96 3899 44 Gl 0 3 1000 750 02/17/96 3877 49 Gl 0 2 1000 750 02/18/96 3889 55 Gl 0 2 1000 750 02/1 9/96 3905 51 Gl 0 3 1000 750 02/20/96 3897 51 Gl 0 2 1000 750 02/21/96 3904 58 Gl 0 3 1000 750 02/22/96 3918 50 Gl 0 3 1000 750 02/23/96 3925 53 Gl 0 3 1000 750 02/24/96 3857 47 Gl 0 2 1000 750 02/25/96 3866 75 Gl 0 2 1000 800 02/26/96 3879 73 Gl 0 2 1000 800 02/27/96 3894 65 Gl 0 2 1000 800 02/28/96 3894 66 Gl 0 2 1000 800 02/29/96 3887 72 Gl 0 2 1000 800 03/01/96 3892 62 Gl 0 3 1000 800 03/02/96 3888 56 Gl 0 3 1000 800 03/03/96 3875 79 Gl 0 2 1000 800 03/04/96 3869 80 Gl 0 2 1000 800 03/05/96 3880 72 Gl 0 2 1000 800 03/06/96 3880 73 Gl 0 3 1000 800 03/07/96 3861 66 Gl 0 2 1000 800 03/08/96 3889 63 Gl 0 3 1000 800 03/09/96 3914 62 Gl 0 3 1000 800 03/10/96 3904 67 Gl 0 3 1000 800 03/11/96 3902 67 Gl 0 3 1000 800 03/12/96 3897 67 Gl 0 3 1000 800 03/13/96 3885 67 Gl 0 3 1000 800 03/1 4/96 3880 64 Gl 0 3 1000 800 03/15/96 3900 62 Gl 0 3 1000 800 Page 3 of 6 Date 03/16/96 03/17/96 03/18/96 03/19/96 03/20/96 03/21/96 03/22/96 03/23/96 03/24/96 03/25/96 03/26/96 03/27/96 03/28/96 03/29/96 03/30/96 03/31/96 04/01/96 04/02/96 04/03/96 04/04/96 04/05/96 04/06/96 04/07/96 04/08/96 04/09/96 04/10/96 04/11/96 04/12/96 04/13/96 04/14/96 04/15/96 04/16/96 04/17/96 04/18/96 05/02/96 05/03/96 05/04/96 05/05/96 05/06/96 05/07/96 05/08/96 05/09/96 05/10/96 05/11/96 05/12/96 05/13/96 05/14/96 05/15/96 05/16/96 WHIP (psig) 386O 3849 3856 3839 3850 3889 3927 3924 3920 3914 3892 3869 3903 3913 3899 3901 3924 3928 3917 3921 3920 3919 3916 3867 3819 3822 3828 3900 3906 3918 3898 3882 3886 3900 2870 2527 2487 2546 2508 2513 2546 2493 2522 2510 2528 2556 2423 2470 2602 (°F) 55 63 71 71 74 75 78 77 82 8O 85 69 86 86 78 78 86 81 72 76 82 88 86 69 57 60 62 70 71 77 81 79 83 89 55 52 51 54 52 49 58 62 60 55 54 55 55 55 55 2T-32 Inj Rates & Pressures Fluid Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl Gl SW SW SW SW SW SW SW SW SW SW SW SW SW SW SW Water Vol (Bbl) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 3 0 3 0 3 0 3 0 3 0 4 0 4 0 4 0 3 0 2 0 3 0 3 120 0 2465 0 1752 0 1618 0 1351 0 1177 0 1155 0 1127 0 1047 0 1120 0 1077 0 908 0 860 0 1049 0 968 0 Gas (MSCF) 7" x 3-1/2" Press (psig) lOO0 lO0O 100o 1000 lOO0 1000 lO00 lOO0 lO00 1000 100o 1000 1300 1300 1300 1300 1300 1300 1300 130o 1300 1300 1300 1300 1300 1300 1300 1300 1100 1100 110o 1100 1100 1100 750 750 750 75O 75O 75O 75O 75O 750 750 75O 750 5OO 5OO 5OO Page 4 of 6 9-5/8" x 7" Press (psig) 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 8OO 750 750 750 750 750 750 75O 75O 750 750 750 750 750 75O 75O 2T-32 Inj Rates & Pressures Water Gas 7" x 3-1/2" 9-5/8" x 7" WHIP WHIT Vol Vol Press Press Date (psig) (°F) Fluid (Bbl) (MSCF) (psig) (psig) 05/17/96 2440 55 SW 814 0 500 750 05/18/96 2524 55 SW 789 0 500 750 05/1 9/96 2638 56 SW 812 0 500 750 05/20/96 2553 57 SW 600 0 500 750 05/21/96 2584 56 SW 721 0 650 750 05/22/96 2606 58 SW 771 0 650 750 05/23/96 2583 57 SW 663 0 750 750 05/24/96 2710 64 SW 905 0 750 750 06/1 9/96 3390 59 SW 760 0 250 800 06/20/96 2705 58 SW 1825 0 50 750 07/02/96 1577 58 SW 1023 0 300 700 07/03/96 2686 60 SW 1523 0 300 700 07/04/96 2671 60 SW 1230 0 300 700 07/05/96 2740 57 SW 1055 0 300 700 07/06/96 2722 56 SW 748 0 300 700 07/07/96 2748 60 SW 828 0 300 700 07/08/96 2720 62 SW 732 0 300 700 07/09/96 2735 60 SW 708 0 300 700 07/10/96 2737 59 SW 692 0 300 700 07/11/96 2740 60 SW 683 0 300 700 07/12/96 2729 60 SW 743 0 300 700 07/13/96 2725 60 SW 705 0 300 700 07/14/96 2734 61 SW 693 0 300 700 07/15/96 2682 64 SW 522 0 300 700 07/16/96 2698 66 SW 685 0 300 700 07/17/96 2754 67 SW 698 0 300 700 07/18/96 2762 65 SW 681 0 300 700 07/1 9/96 2673 65 SW 486 0 300 700 07/20/96 2760 65 SW 741 0 300 700 07/21/96 2765 66 SW 675 0 300 700 07/22/96 2786 64 SW 697 0 300 700 · __ 07/23/96 2759 67 SW 697 0 0 700 07/24/96 2714 68 SW 556 0 ,~! 0 700 07/25/96 2705 65 SW 557 0 0 700 07/26/96 2644 67 SW 475 0 p~'rl~t 700 07/27/96 2701 65 SW 617 0 ~'~-~, 700 07/28/96 2680 65 SW 1281 0 0 700 07/29/96 2658 65 SW 1573 0 0 700 07/30/96 2659 63 SW 2001 0 0 700 07/31/96 2698 63 SW 2008 0 0 700 08/01/96 2704 62 SW 1036 0 0 700 08/02/96 2630 62 SW 477 0 0 700 08/03/96 2507 61 SW 423 0 0 700 08/04/96 2624 63 SW 258 0 0 700 08/05/96 2565 63 SW 1491 0 0 700 08/06/96 2521 64 SW 587 0 0 700 08/07/96 2560 69 SW 586 0 0 700 08/08/96 2234 62 SW 501 0 0 700 08/09/96 2147 59 SW 397 0 0 700 Page 5 of 6 2T-32 Inj Rates & Pressures Water Gas 7" x 3-1/2" 9-5/8" x 7" WHIP WHIT Vol Vol Press Press Date (psig) (°F) Fluid (Bbl) (MSCF) (psig) (psig) 08/10/96 2002 59 SW 401 0 0 700 08/11/96 2500 60 SW 472 0 0 700 08/12/96 2500 61 SW 424 0 0 700 08/13/96 2500 64 SW 390 0 0 700 08/14/96 2500 62 SW 414 0 0 700 08/15/96 2500 61 SW 431 0 0 700 08/16/96 2500 61 SW 424 0 0 700 08/17/96 2500 60 SW 468 0 0 700 08/18/96 2500 61 SW 387 0 0 700 08/1 9/96 2715 58 SW 389 0 0 700 08/20/96 2693 55 SW 308 0 0 700 08/21/96 2698 52 SW 264 0 0 700 08/22/96 2694 52 SW 338 0 0 680 08/23/96 2651 53 SW 175 0 0 680 08/24/96 2625 57 SW 143 0 0 680 08/25/96 2616 56 SW 414 0 0 680 08/26/96 2670 55 SW 515 0 0 680 08/27/96 2705 55 SW 530 0 0 680 08/28/96 2675 55 SW 498 0 0 680 08/29/96 2609 56 SW 512 0 0 680 08/30/96 2685 57 SW 611 0 0 680 08/31/96 2742 55 SW 609 0 0 680 09/01/96 2737 55 SW 581 0 0 680 09/02/96 2733 56 SW 575 0 0 680 09/03/96 2747 56 SW 593 0 0 680 09/04/96 2724 55 SW 555 0 0 680 09/05/96 2593 56 SW 503 0 0 680 09/06/96 2539 56 SW 474 0 0 680 09/07/96 2677 56 SW 650 0' 0 680 09/08/96 2666 56 SW 628 0 0 680 09/09/96 1231 55 SW 124 0 0 680 09/10/96 2721 54 SW 0 0 0 680 09/11/96 2712 53 SW 13 .0 . 0 680 09/12/96 2716 54 SW 33 0 0 680 Page 6 of 6 4OOO 3500 3000 25O0 2000 1500 1000 2T-32 Rates & Pressure --0--7 Pressure ~ 10' Pressure --~×~ WH Temp 90 80 !70 60 50 40 30 20 5OO 10 TP10 THEORETICAL PRODUCTION EVENT LOGGING SUMMARY 09/13/96 11:48:30 DATE 09-09-96 09-09-96 08-01-96 08-01-96 07-19-96 07-19-96 07-02-96 06-21-96 06-19-96 05-25-96 05-02-96 04-19-96 02-18-96 02-18-96 01-05-96 01-05-96 12-31-95 12-31-95 12-01-95 12-01-95 11-01-95 11-01-95 10-21-95 10-01-95 TIME 1815 0400 1000 0800 1530 0730 1045 0800 1630 1730 1400 1320 1415 1145 1545 1345 0815 0800 1245 0930 1545 1445 0000 0000 60 61 6O 61 6O 61 6O 61 6O 61 60 42 41 42 41 42 41 42 41 61 6O 61 6O 61 DRILL SITE: 2T WELL : 32 MANUAL ALLOC/ EVENT TYPE /AUTO NONALL SAND OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OPEN TO GAS INJECTION A A A WELL SHUT IN A A A OPEN TO GAS INJECTION M A A WELL SHUT IN M A A OPEN TO GAS INJECTION M A A WELL SHUT IN M A A OPEN TO GAS INJECTION M A A WELL SHUT IN M A A OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OPEN TO H20 INJECTION M A A WELL SHUT IN M A A OIL WATER GAS WATER GOR LFT GS INJ GS SRC WT INJ WT RATE RATE RATE PCT RATIO RATE RATE RATE RATE h0 0 0 0 0 0 0 0 1 I'~ o o o o o o o o I o~ o o o o o o o 1 I o ~o o o o o o o o I o o.,..o o o o o o 1 I o o~ o o o o o o o I 0 0 ~ 0 0 0 0 0 1 0 0 0~ 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 1 0 0 0 ~ 0 0 0 0 0 0 0 0 0~ 0 0 0 0 1 0 0 0 0 ~0 0 0 0 0 0 0 0 0 ~ 0 1 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 ~0 1 0 0 0 0 0 0 0 0x~ 0 0 0 0 0 0 0 0 0 ~ 1 0 0 0 0 0 0 0 0 ~x~ 0 0 o o o o o o 1~ o oo 0 0 0 0 0 0 0 0 ARCO Alaska, Inc. Date' December 26, 1995 Transmittal #: 9311 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. q)::. ~'"? All items below include BOTH Blueline and Sepia. ~ ~, 2A-i 8 CBL 10/15/95 ,~'-~'~ 2T-32 CBL 10/19/95 ,~;-- t~,~.. 2T-36 CBL 10/20/95 q~-- ~ 2. 1 Q-26 CBL 10/24/95 ct~"-- ~ 1 Q-23 CBL 10/24/95 5800-6655 13130-13636 14990-15325 5900-6885 87OO-9866 · Date' Acknowledge: ~ DISTRIBUTION' Sharon AIIsup-Drake DS Development ATO-12O5 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501' h_~ : .~.' ..... - ~-~;, "~:.'22::. Erickson/Zuspan NSK Central Files NSK-box 69 OQ '.'vi AR ?_? ~aska 011 & Gas Cons. Commission ,.. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 28, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-32 (Permit No. 95-49) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2T- 32. If there are any questions, please call 265-6206. Sincerely, M .~77~a.n g~. ' Supervisor Kuparuk Drill Site Development MZ/skad ORIGINAL STATE OF ALASKA ALA,_,,,A OIL AND GAS CONSERVATION COMI¥ ..... :~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~ GAS r-] SUSPENDED r-I ABANDONED F-] SERVICE r~ /~/~/sJfi~t~lhal~g~o ~ater injector 2 Name of Operator ~-- ~it N~rt~ ARCO Alaska, Inc 95-49 / ~ 3 Address 8 APl Numar P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20218 4 Location of well at surface . - ?.. , . . 9 Unit or Lease Name 567'FSL, 556'~L, Sec. 1,T11N, R8E, UM ':" .... '::'~;:' ~ ~ ...... r At Top Producing Interval ~~~/ ] ~TAT~,~:~,1[ 10 WellKuparuk River UnitNumber Al ~otal Depth.:: 11 Field and Pool 1137' FNL, 1503' FEL, Sec 34, T12N, R8E, UM . , , B ............. KUPARUK RIVER 5 Elevalion in feet (indicate KB, DF, etc.) ~ 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 41', Pad 81'~ ADL 25549 ALK 2663 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ 15 Water Depth, if o~shore ~16 No. of Completions April 18, 1995 April 29, 1995 20-Oct-95 perf'd~ NA feet MSLI 1 17 Total Depih (MD+TVD) 18 Plug Back ~pth (MD+TVD) 19 Directional Su~ey ~20 Depth where SSSV set 21 Thickness of permafrost 13787' M D & 6062' TVD 13696' M D & 6004' TVD YES ~ NO ~~ NA feet MD =1380' ss APPROX 22 Ty~ Electric or Other Logs Run GR/CDR/CDN, GR/CCL/SLT-J 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE C~E~ ~ 16" 62.5~ H-40 Surf. 121' 24" 210 sx AS I 9.625" 40.0~ L-80 Surf. 4752' 12.25" 820 sx AS III Lead, 830 sx Class G Tail 7" 26.0~ L-80 Surf. 13777' 8.5" 230 sx Class G ~. . 24 Perforations open to Production (MD+TVD of Top and Bo~om and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 13298' 13270' 13392'-13430' MD 4 SPF 5811'-5835' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Dale Firsl Injection ~Method of Operation (Flowing, gas lift, etc.) 10/21/95~ Injecling Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO I TEST PERIOD E Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE E NA 28 CORE DATA Brief description of lithology, ~rosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . Form 10-407 Submil in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 13376' 5801' Bottom Kuparuk C 13390' 5809' Top Kuparuk A 13390' 5809' Bottom Kuparuk A 13510' 5885' . A~asks Oil .!~ (".s ~:,;'. Q',:""'.~ '... '. :,'.,:' 31. LIST OF A'I-I-ACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. / / Signed .._ ~" ~ Title 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". Form 10-407 Date: 11/07/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-32 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8141 AFE: AK8141 TYPE:DEV AFE EST:$ 1585M/ 2050M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20218 FIELD: KUPARUK RIVER SPUD:04/18/95 START COMP: FINAL: 04/19/95 ( 1) TD: 2868'(2868) SUPV:RLM 04/20/95 (2) TD: 4762'(1894) SUPV:JT 04/21/95 (3) TD: 5064'(302) SUPV:JT 04/22/95 ( 4) TD: 5930'(866) SUPV:JT 04/23/95 (5) TD: 4836'( 0) SUPV:JT 04/24/95 (6) TD: 5980' (1144) SUPV:JT 04/25/95 ( 7) TD: 6970'(990) SUPV:JT 04/26/95 (8) TD: 9546'(2576) SUPV:RLM 04/27/95 (9) TD:12193' (2647) SUPV:RLM MW: 10.0 PV/YP: 13/29 APIWL: 17.8 DRILLING Accept rig at 0900 hfs 4/18/95. Spud at 1330 hrs. 4/18/95. Directional drill from 121' to 2868' DAILY:S115,304 CUM:$115,304 ETD:SO EFC:$1,700,204 MW: 10.0 PV/YP: 21/ 9 APIWL: 8.8 CIRC. TO CMT Directional drill from 2868' to 4762'. Run 123 joints of 9-5/8" casing. DAILY:S143,291 CUM:$258,595 ETD:SO EFC:$1,843,495 MW: 9.5 PV/YP: 12/14 APIWL: 8.6 DRLG Cement 9-5/8" casing. Test BOPE. Pressure test casing. Drill f/4772' to 5064' DAILY: $170,680 CUM: $429,275 ETD:SO EFC: $2,014,175 MW: 9.5 POOH TO SET PLUG Drilled from 5512 to 5930' sidetrack. DAILY:S75,571 CUM:$504,846 PV/YP: 17/13 APIWL: 6.6 POOH to set cement plug to ETD:SO EFC:$2,089,746 MW: 9.5 PV/YP: 18/13 APIWL: 9.6 WOC POOH survey. Spot dirty pill. Spot 31 bbl cement. WOC. DAILY:S85,673 CUM:$590,519 ETD:SO EFC:$2,175,419 MW: 9.5 PV/YP: 15/11 APIWL: 6.8 TRIPPING FOR BHA #5 WOC. Plan to kick off plug at 4850'. Control drilled from 4850' to 5980'. Trip for BHA #5. DAILY:S81,253 CUM:$671,772 ETD:SO EFC:$2,256,672 MW: 9.6 PV/YP: 17/13 APIW-L: 6.8 SHORT TRIP RIH w/ BHA #5. Sidetrack new hole f/5480 t/5802. Drilled from 5802 to 6970. % DAILY:S93,917 CUM:$765,689 ETD:SO EFC:$2,350,589 MW: 9.6 PV/YP: 17/13 APIWL: 7.0 DRILLING Directional drill 8.5" hole from 6970' to 9546' DAILY:S80,225 CUM:$845,914 ETD:SO EFC:$2,430,814 MW: 9.7 PV/YP: 11/11 APIWL: 7.5 DRILLING Directional drill $.5" hole from 9546' to 12193'. DAILY:S80,059 CUM:$925,973 ETD:SO EFC:$2,510,873 Date:il/07/95 Page: 2 04/28/95 (10) TD :13238' (1045) SUPV: RLM 04/29/95 (11) TD:13420' (182) SUPV: RLM 04/30/95 (12) TD'13787' ( 367) SUPV'RLM 05/01/95 (13) TD'13787' ( 0) SUPV:RLM 05/02/95 (14) TD:13787'( 0) SUPV:RLM ARCO Alaska Inc. DAILY DRILLING REPORT MW' 10.7 PV/YP: 18/18 APIWL' 5.2 POOH Directional drill 8.5" hole from 12193' to 13238' DAILY'S103,062 CUM:$1,029,035 ETD'SO EFC:$2,613,935 MW: 10.7 PV/YP: 18/11 APIWL: 5.0 DRILLING Test BOPE. Directional drill 8.5" hole from 13238' to 13420' DAILY'~73,267 CUM:$1,102,302 ETD'SO EFC'$2,687,202 MW: 10.7 PV/YP: 20/13 APIWL: 4.8 RUNNING CASING Directional drill 8.5" hole from 13420' to 13787' Running 7" casing. DAILY:S205,543 CUM:$1,307,845 ETD:SO EFC:$2,892,745 MW: 10.7 PV/YP: 13/13 APIWL: 5.2 LAY DOWN DP Ran 7" casing to 13777' Cement casing. CIP at 2130 hfs 4/30/95. Freeze protect 9.625" x 7" annulus. DAILY: $118,519 CUM:$1,426,364 ETD:S0 EFC:$3,011,264 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish laying down s-135 drill pipe, injecting mud and cleaning pits. Rig released at 1000 hfs 5/1/95. DAILY:S18,534 CUM:$1,444,898 ETD:SO EFC:$3,029,798 Date: 11/07/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8141 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8141 TYPE:DEV AFE EST:$ 1585M/ 2050M STATE: API NUMBER: START COMP: FINAL: 09/04/95 (15) TD:13787' PB:13696' SUPV:MDD 09/05/95 (16) TD:13787' PB:13696' SUPV:MDD 09/06/95 (17) TD:13787' PB:13696' SUPV:DCL 09/07/95 (18) TD:13787' PB:13696' SUPV:DCL 09/08/95 (19) TD:13787' PB:13696' SUPV:DCL 09/09/95 (20) TD:13787' PB:13696' SUPV:DCL 09/10/95 (21) TD:13787' PB:13696' SUPV:DCL 09/11/95 (22) TD:13787' PB:13696' RIH W/ 3-1/2" COMPLETION MW: 8.6 SEAWATER Move rig from 2T-31 to 2T-32. Function test BOPE. Run in hole with packer and 3-1/2" completion tubing. DAILY: $34,363 CUM:$1,479,261 ETD:S0 EFC: $3,064,161 POOH W/3-1/2" TUBING MW: 8.6 SEAWATER Continue RIH with 3-1/2" completion string. Packer hit tight spot, set prematurely. Attempt to move pipe. RIH with chemical cutter. Worked tool, could not get below 3020' POOH with 3-1/2" production tubing. DAILY:S47,520 CUM:$1,526,781 ETD:SO EFC:$3,111,681 CIRC OUT HI VIS SWEEP MW: 8.6 SEAWATER Run in hole with 3-1/2" DP to top of fish. Tag fish at 4954' POH with 3-1/2" DP and fish. RIH w/milling assembly on 3-1/2" DP to packer at 4984'. Mill on packer from 4984' to 4988' DAILY:S35,700 CUM:$1,562,481 ETD:SO EFC:$3,147,381 RIH W/SPEAR/PU 3-1/2" DP MW: 0.0 Run in hole with 3-1/4" spear to 4890'. Latch fish. No recovery. Test BOPE. Run in hole with spear to 5270'. Run in hole 3-1/2" DP. DAILY:S34,868 CUM:$1,597,349 ETD:SO EFC:$3,182,249 POH WITH 3-1/2" DP MW: 0.0 POH with fish. Run in hole with casing scraper. Scraper dragging on junk. PU 3-1/2" DP to PBTD. Displace well with clean seawater. DAILY:S37,400 CUM:$1,634,749 ETD:SO EFC:$3,219,649 RIH W/3-1/2" COMPLETION E RIH with 3-1/2" completion equipment. MW: 0.0 DAILY:$3t,979 CUM:$1,666,728 ETD:SO EFC: $3,251,628 RIH W/MILL AND 3-1/2" DP MW: 8.6 SEAWATER Continue RIH w/3-1/2" completion assembly. Make up 6-1/8" mill, tandem casing scrapers, DC's and 3-1/2" DP. Started pushing junk at 2771' DAILY'S31,200 CUM'$1,697,928 ETD'SO EFC'$3,282,828 POH W/STAND BACK DP MW: 0.0 Continue pick up and run in hole with 3-1/2" DP. Reverse circulate 2 annular volumes at PBTD. Date' 11/07/95 Page' 4 ARCO Alaska Inc. DAILY DRILLING REPORT SUPV'DCL DAILY' $31,200 CUM:$1,729,128 ETD:S0 EFC: $3,314,028 09/12/95 (23) TD'13787' PB'13696' SUPV:DCL RIH W/GLOBE BASKET ON 3-1 MW: 8.6 VIS/SEAWATER Run in hole with 6" guage ring, bumper sub and 3-1/2" tbg 3715'. GR hanging up. Worked through tight spots. MU 6" globe basket, bumper sub, jars and 12-4 3/4" DCs. Run in hole slowly. No tight spots. Worked through areas where GR was dragging. No obstructions. Reverse circ w/viscosified seawater. No metal or junk in returns. DAILY:S37,147 CUM:$1,766,275 ETD:SO EFC:$3,351,175 09/13/95 (24) TD'13787' PB'13696' SUPV'MDD POOH, LD DP MW: 8.6 VIS/SEAWATER Continue running in hole with globe basket. Worked thru tight spots. RIH to 13600' DAILY' $37,925 CUM:$1,804,200 ETD'S0 EFC:$3,389,100 09/14/95 (25) TD:13787' PB:13696' SUPV'MDD RIH WITH 3-1/2" COMPLETIO MW: 0.0 Continue to pull out of hole with globe basket while LDDP. Found 3 pieces of packer. Run in hole on 3-1/2" tubing. DAILY' $36,757 CUM:$1,840,957 ETD'S0 EFC'$3,425,857 09/15/95 (26) TD:13787' PB:13696' SUPV:HDD RIG RELEASED MW: 0.0 Continue run in hole with packer assembly and 3-1/2" tubing. Set packer. Freeze protect well. Test packoff and tree. Secure well. Rig release at 2130 hfs 9/14/95. DAILY:S132,522 CUM:$1,973,479 ETD:SO EFC:$3,558,379 10/20/95 PERF 'A' SAND INTERVAL Perf 13392'-13430' using 2-1/8" EJ w/alternating BH/DP charges, 4 spf, 0° ph. Bond log indicated cmt bond is good below 13430' with poorer quality cmt above this. End of WellSummary for Well'AK8141 HEAD LOC~TI~: L~T(hV-S) AZIMUTH FRO~ ROTARy TABLE TO TAR%'ET IS 3~,2.~ ?IE IN POINT(TIP) : E£&gJRI~) ~ 121.00 T:,UE VER? I)k'PTN 121.00 I~LI~TI~ 0.~ ~IM~ ~TIT~E(N/-S) 0.00 ft ft 121 ,,:4.: 374.72 253,7 _..:= . ,~,..:.,8 ..... 73..-', ! :: 7,.'-.: (,~:' '?i ,'.-." .... ' i,;.,'-,l ?3,0 134-.%37 9'2,6 15!0.05 1658.!2 1752.67 1844.85 !937.15 92.2 !73!,40 52.3 1777,~6 94,1 +0i,05 a.02 320,83 461,96 42.77 321.41 526,4Q 45.81 321,92 407.42 5~.79 49.26 ~2,03 ¢152.1! 7~1B.73 2405,40 2498,26 9'3,8 'y:,7 1975/.;.2 52,6 ,.,-: .....-.,. 6E4,10 5!,70 ~I,76 Ja~.Oa 742.99 54,50 C~!,07 ~7.57.' 819,54 57/,C4 320,96 637.09 980,92 ,.:,o/ 32!,02 762.91 2780,19 2965,00 94,2 2165.C2 92.6 189.2 25.:62,2~ I065.~ 64,91 ~0.43 ~:,z. 67,['Q 319,62 894.89 1238.44 69,65 3!8.70 i4!2,36 70.77 318.3i !0%.40 15'?0,80 70,59 317.76 ~'""q ~'' 3524.I4 3711.04 40qi,17 165,4 2~25.91 184,5 2~8t.7I 189,2 2601,~ 190,9 265~.85 1764,74 69,25 317,2i 1351.55 193~,67 72,25 317.~ 1479,7~ 2116,0S 7i,4.~ 317,44 !613.6i, <~oj~ ~17.~ 1743,54 2478,80 73,01 ~i6.4~ 4278,I~ 4671.87 4850.68 4~7.67 187,0 Z?I2.44 184,5 27.~,3~ ~9.1 2825.49 t78,8 2578,61 87,0 2656,8~ 72.28 316,35 2833,12 73,85 317,69 2!35.43 3033,I5 72.75 316.77 2282.48 3'203,84 73,36 316,48 2406.8] 32~.51 71,36 315.~ 2~6.~ .. .~.., -~ ..,... f-. de~ !OOft r, r..-: O.nO ,'~ ,',", 0,00 {.,.54 '~ ~''' ,;. e~:- ?.1,0o 0.15 0,42 0.6:? 142,1(' '.: 0 -C':94 1 · "": 3i4.3i , ,o ~ ~..', -,~ ~ '~ .= · .. -.::,:,. !2f.,o .... 2,03 -:v.,eu ~o~.~ 317,93 2,64 :v0.~,.. o,9. ,6 3,05 -i29,21 ~^ ~i ~,,o ...... 243 ~'~ ~ n~ 2,cA .~ ',' ~:e o.: .... 77 4,10 -2!g,24 342,70 S20,41 4,37 -~5,14 ~i,06 ~0,47 4,04 -2qJ,38 461,98 320.58 3,02 '~ ~: 52~,42 320,7I 3,32 -376,12 595,82 320,86 3,&~ -ZD,76 .~3,~ ~0,97 ~,61 -4~, .~A ,.~,~_, ~. .... 3.05 -565,83 877,73 J~l,03 2,94 -6!6,72 98!,01 321,05 2.82 lO&.,: ~1,02 2.76 -670.16 = '~ -72~+05 t'=~ .... 5" -/o:.39 !.38..~ 320.82 -8~..66 !412.37 320.57 0.54 -i0!7.07 !590,80 320,26 -!1E~,74 1764.77. 31%% 0,76 -1252.66 I72J.76 3!9.75 1.64 -1372.&6 2!16.~ ~'~ :' . ~i~,..,o 0,43 -!494,77 2296.58 317039 -161%65 2477,~ 317.21 -1742,77 2657,52 319,02 0,39 'l&~,ll 2833,~ - 318.~0 -19c/9.12 30a4.18 318.79 0.67 -2116,57 2205,11 318,67 0,37 -2174,2B a28/.92 318.60 JAN 0 9 ,l?9,,S 665~,44 I~5,5 ,~841.90 ~ s 7i23.12 281,2 7406,09 2~2.0 7&9~,9~ 278,9 79.~.66 27%7 8245.77 282,1 ~10.59 '~.07 9370.39 2~,3 9o53.~ 283.1 ~'36.30 282,8 :~1~3.06 186,6 !0309,~ lc%,9 11148.02 274,i 11413.40 26%4 I1666,63 273,2 11959,96 273,3 12143,96 I84,0 lgr?,8.~' 184.4 12420.07 91.7 !~11.60 91.7 _ . 21' - 2. ft fr f~c dec :: ~23!,1? 4113.19 ~.C~ 317.36 '~2fi7,.':7 4287.29 6'?,61 321.33 3207.20 ~o~.,77 4374.68 70.24 .... . ~ OZ, 7 -,'.,~ ,~ ~ -,-,~ n 34~,.9J Z;51,z~ 5075.37 72,I~ 3637,65 5342,80 72,09 321,68 4047,3: 3724,50 5610,6I 72,05 325,!8 42~2.78 ~5iI,7~ 5874,68 71.48 ~3,17 4477.52 ?;00,% 6139.72 71,52 5~3,52 29~7,51 6407,73 72,56 322.83 49(6.11 4<:72.16 6676.!9 72.48 323.24 51!9,~ 4J..',O,O?6944,86 71,~ 323,20 4342,]~ 7474,07 71,I5 321,93 ..k'75~.!7 44.34,82. 7741,50 70,62 ~1,5~ 59~0,17 4528,7~ 8008.19 70.59 321.00 6168,41 ~7590.73 8184.~ 70.64 320,35 67, C4,~ 4652.7? 6360.61 70,~ 319,66 6437.92 47~5,;1 862.7.74 71,00 ~0.16 45~7,03 ~893,61 71,17 320,36 6847.02 4927,40 9152.42 70,34 319.~ 7047,6~ 5011,~2 9404,'~ 72,75 320,94 724~.49 5C91,)V 9665,17 73,05 T~,D' 7~5,I6 5173,02 9926,09 72,96 320.97 7649.7z b'293,26 lO0~,B6 69,42 317,17 77~1,0~ 53X),02 !0271,64 68,14 319,18 790q.16 b'~4.~ 10356,56 67,57 319,94 7973o81 5370,05 10441,15 ~,91 320.55 803B.8~ ., -2735,12 4!!5.53 -c<'n~.A~..... 4377.08 -3(KO.?? 4_553.07 -3!i6.!8 ~ .... ,/;r,~.. 3!8.79 -3~i.61 4903.:~ 3!8.~ -0~;,.,,~/ 5076,5! 319'07 -34.8%12 o~o,.,. 319,24 '3648,93 5611,22 3t?,44 '~62.30 613%~ 319,81 -4i23,1~ A4t,? ~ .19,95 -4284.75 6676.24 320.07 -4606,87 720%09 320.26 -477.4,65 7474,07 ~0,33 -4940,25 7741,50 320,35 -5i07,05 8008,20 ~0,~ -5218.6~ 8184,37 30,38 -5~1,75 6360.62 320.38 -~03,43 8627.,'"5 320,37 -5673.40 ~93.62 -5640,02 9152.43 320.35 -6001.0S ~.404.13 ~0,~ -6163,26 9665.21 320,38 -6,~.28 ~126,!2 ~.41 -6439.11 100~.68 320.39 -6553.75 10271.65 ~,~ -~.~ 1~.~ ~.35 -~,94 1~1.15 ~0.~ :i .:82 4 0 :$,2 0,.73 2,09 0 Io08 0,53 0.71 0,12 0,41 0,45 0,22' 0.I9 0.33 0,25 0.16 0,09 0,43 1,05 0,46 0,52 2,12 0.90 &,:7-T. 7;, -7024,67 '"~' ........... ~-- .?-'~ -¢ -7r, v: .... AD~ X9 220,25 a5,r',7.~'':: ""-' =: -,' ~.i .~.~ 11154 ':-'~"'~ ~-- -,; oo.'?~ 11225,24 -7[<>C,% 11q37,1~ -7344,33 11502.79 320.~ 1,10 0.96 0,79 2 ~ ..¢ 2.45 0 ARCO Alaska, inc. Date' December 26, 1995 Transmittal #' 9310 RETURN TO' ARCO Alaska, inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~f,O)(, 2T-27 CDR 04/17/95 REF #50-103-20217 r 2T-32 CDN 04/30/95 REF #50-103-20218-00 ¢¢'-- H,'f '-2T-32 CDR 04/30/95 REF #50-103-20218-00 ,/F-F? 2T-30 CDR 05/12/95 REF #50-103-20219-00 5~ ~--(~'7..-~ 2V-06 TDTP 06/11/95 REF #95219 ¢¢'-~'[ 2T-31 CDR 0713/95 REF #50-103-20226-00 f2T-36 CDR 07/25/95 REF #50-103-20228-00 ~/-~¢,~ z.~-2T-36 CDN 07/25/95 REF #50-103-20228-00 /:-2T-38 CDR 08/03/95 REF #50-103-20229-00 %~ft % )..2.T-38 CDN 08/03/95 REF #50-103-20229-00 ~-.. ~o ~ 2T-37 CDR 08/10/95 REF #50-103-20227-00 qr_~.~ 1Q-24 ARC5 Array Resistivity Comp. 08/30/95 4206-7270 ~- ~3x. 1 Q-26 ARC5 Array Resistivity Comp. 09/22/95 3820-7010 ~1~-~ I~ 1 Q-23 ARC5 Array Resistivity Comp. 09/30/95 5156-9982 Acknowledged' Date' DISTRIBUTION' Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsupoDrake DS Development ATO- 1205 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501~ .,J-~o~.a' ~-' 0il. & Gss Cons. ~,,.~,"'~ ..... AnCt~Or~ge Clifton Posey Geology ATO - 1251 11/9/95 NO. 9870 GeoQuest 500 w. International Airport Road Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99518-1199 /~~.~ /( Attn: Larry Grant ATTN: Sherrie /V /1 / ~ ( ...~ 3001 Porcupine Drive f/~'' ~,~-" (J /J'~ ~,~~v~\ Anchorage, AK 99501 ,I~,; ~ ~~v~~v ' en Hole) ~,. LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1Q-24 ~' 95324 ARC5 950830 I I 1 2T-32 95172 CDR/CDN . ~ ~ 950430 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. AlaSKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 7, 1995 Michael Zanghi, Drill Site Develop Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2T-32 ARCO Alaska Inc 95-49 567'FSL, 556'FWL, Sec 1, T11N, R8E, UM 1131'FNL, 3753'FWL, Sec 34, T12N, R8E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. Yours very truly, Russell A Douglass Commissioner BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory ['l Stratigraphic Test [] Development Oil X Re-Entry D Deepen D Service r-] Development Gas 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25549, ALK 2663 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 567' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1333' FNL, 3921' FWL, Sec. 34, T12N, R8E, UM 2T-32 #U-630610 At total depth 9. Approximate spud date Amount 1131' FNL, 3753' FWL, Sec. 34 T12N, R8E, UM 4/1 4/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-27 13819' MD 1131 ~ TD feet 75' ~ 500' MD feet 2560 6083' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum holeangle 71.4° Maximurnsurf~ce 1691 pslg At total depth (TVD) 3250 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Lencjth MD TVD MD TVD {include stacje data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 4558' 41' 41' 4599' 2857' 820 Sx Arcticset III & HF-ERW 830 Sx Class G 8.5" 7" 26,0# L-80 BTCMOC 13778 41' 41' 13819' 6083' 210SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth R E ¢ E IV E D Surface Intermediate Production APR -7 1995 Liner Perforation depth: measured Alaska 0il & Gas Cons. C0mmlssl0n true vertical Anchorage 20. Attachments Filing fee X Property plat ~ BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis [~ Seabed report [--~ 20 AAC 25.050 requirements X 21 .Xhereby certify that the, foregoing is true and correct to the best of my knowledge Sig L~ Title Drill Site Develop. Supv. Date ~ f //"-~ ' ~ '-- ~'t' v ' i~) ~ - Commission Use Only Permit Number I numberAI{~ '~ I Approval date I See cover letter for " 4:~"- ~7~'? S0~-//O,,=~- ~ O '7_/~ /'"/ - 7' c~l 6- other re({uirements Conditions of ~pproval Samples required [~] Yes J~] No Mud log required D Yes [~ No Hydrogen sulfide measures r~ Yes r-] No Directional survey required ~] Yes ~ No Required working pressure for BOPS D 2M ~ 3M r'~ 5M D 1OM D 15M Other: ORIGINAL SIGNED BY RUSSELL A. DOUGLASS by order of ~.~ Approved by Commissioner the commission Date ' '~ ~(77 ~"-~.~ Form 10-401 Rev. 7-24-89 Submit in triolicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2T-32 . . , . , , , , , 10. 11. 12. 13 14 15 16 17 18 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,599')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (13,819') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Will attempt to run cased hole cement evaluation in the form of Schlumberger's through-tubing SLT-J CBL. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVE. D APR -? 1995 OiJ & Gas Cons. Cornm~ Anchorage DRILLING FLUID PROGRAM Well 2T-32 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,691 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2T-32 is 2T-27. As designed, the minimum distance between the two wells would be 75' @ 500' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-32 surface/production casing annulus will be filled with diesel after setting 7" and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. Risks in the 2T-32 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. R E E E IV E D APR -7 1995 ktaska ~ & Gas Cons. Commt,~ton Anchorage ,r iARCO ALASKA, Inc. J Structure : Pad 2T Well : 32 J I i Field : Kuparuk River Unit Location : North Slope, Alaska < - - W e s} o.oo 7500 7000 6500 6000 5500 5000 4500 4000 3500 5000 2500 2000 1500 lO00 500 0 500 II II II II 1I II II II II II II II II II II I I I 9500 __ TD LOCATION: . _9000 1131' FNL, 3753' FWL I SEC. 34, T,2N, BBE I ~ 8S00 ~ N 39.72 DEG W nAr~gle Drop 11259' (TO TARGET) _8000 ~ I TARGET LOCATION: J - ~ TARGET 6500 ~ ~M)=5862 - ~ TMD=1547§ ~ ~ ~, DEP=11259 - ?reared by : jones For: D PETRASHJ N~ ~°~sS~ 7a¢¢5° _00o0 iDote plotted : 24-Feb-95 _ jPIo'¢ Reference is 32 Version #3. i ~ 5500 ]Coordinates are in feet reference slot #32.1 ~ - ]True Vertical Depths are reference RKB. ~ -~ooo --- Baker Hughes INTEQ --- ~ _ K-lO 2500 o 600_ ~ - o~ _ "~ 5/8 Co~r~ P~ _ 2 o_ [ ........ ~. __ .,~ _~o00 - }~ 15.00 mILD 30~C / 100' t'~ - 't.L '-~'"'~ T/ UGNU SNDS ~ 1 ~ 51.00 ~. _ ~ 13/ W SA}( SNDS TVD=2872 TMD=4017 DEP=237g _ ~_ ~ 9 5/8" cso PT T~3=2857 TMD=4599 DEP=2930 ~ 3boo_ K- 10TVD=5007 TMD=5070 DEP=3377~'~~..~ _500 Q~ ESTIIJ^TED : ,8._- AN IZ F -- ~_ ~ 71 44 DEG isu~^c~ - 5400- BEGIN ANGLE DROP WD=5341 · = = "'"~,~70.~.~ 00 DROP 2 ~: / TARGET ANGLR ~,~.~ - t/zor~ c (roD) W~:586~ ~D=~3476 ~P=~59 6000_ -- .... ~ T/ ZONE A 1'VD=5867 TMD=15484 DEP=11265 bO PEG T/ A2 SNDS 3VD=5881 TMD-13505 OEP-II282 B/ KUP SNDS TM3=5954 TMD=15619 DEP=11369 6C::,Oa TI) / ?" CSG ?? 'rvD=6083 T~ID=13819 i i i i i i i i i i i i i i i i i i i i i i i I i i i i i i i i i i i i i i I i i i 6043 0 6C0 1200 1800 2400 3000 5600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200108001140012000 Scale 1: 500.00 Vertical Section on 320.28 azimufh with reference 0.00 N, 0.00 E from slof #$2 RECEIVED APR - 7 1995 Alaska Oil & Gas Cons. Corngilss!on Anchorage ARCO ALASKA, ][1-1(2. Sfrucfure : Pod 2T Well : 32/25/29/26/22/31 41aska Field : Kuporuk River Unif Location : North Slope, Al(~sko ~co,~,: ,o.oo E a s f - - )> 220 240 260 280 500 320 340 360 ,.~0 400 420 440 460 480 500 520 540 560 580 600 620 640 7..1'- 17C(I1600 % 1500 ~760 ~740 ~720 700 /,, I I _620 _600 - _5~o 4O0 _420 ,. 220 240 260 280 .500 520 540 560 380 400 4-20 440 460 480 500 520 540 560 580 600 620 640 Scale1:10.00 Easf --> -y ?.:r- 5~, 3' ~7..q,M,L&, L~ t',l, ARCO ALASKA, Inc. Structure : Pod 2T Well : 52/25/29/26/22/51 Field : Kuporuk River Unit Locofion : North Slope, Alosko ~oo'~: ~o-oo Eas} --> RECEIVED ~ska Oil & ~as Cons. Anch0ta~e 520 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 520 560 400 440 480 520 1720. __ 1680__ A 440_ - ~400_ 260~ _1760 _1720 _ 1680 1600 A _1520 J I - _1480 Z - _14400 - --I- _1400 ~ _1360 1900 _1160 _ _1120 320 280 2:40 2O0 160 120 E,O 40 0 40 80 12:0 16O 200 240 2E, O .520 .560 400 440 48(3 520 Scale 1 : 20.00 E a st - - > 1080 kdPARUK RIVER UNI'I 20" DIVERTER SCHEMATIC 4 5 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE ~, OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. REEEIVED DKP 11/9/94 APR - 7 1995 Alaska OiJ & Gas Con~. CommOn Anchom¢ < < 7 , 6 5 13 5/8" 5000 PSI STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC 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 THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO3-FOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 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 POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16"-2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 1:~5/8" - 5000 PSI SPACER SPOOL 4. 13~J/8"-5000 PSI PIPE RAMS 5. 13-5/8"-5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR RECEIVED APR -7 1995 Alaska 0ii & Gas Cons. Commlr,~on Anchorage WELL PERMIT CHECKLIST FIELD & POOL COMPANY WELL NAME GEOL AREA UNITS PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF SHORE ~) ADMINISTRATION 1. 2. 3. 4. 5. 6. ~ 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or resets pit ............. 21. If a re-drill, has a 10-403 for abnd~t been approved. 22. Adequate wellbore separation propose~ ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid pro,ram schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~ psig~ 27. Choke manifold complies w/~I ~-53 (May 84) ...... 28. Work will o~cur without operation shutdo~ ....... 29. Is presence of ~2s gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ,,~..ty N 34. Contact name/phone for weekly progress reports . . . ... Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: Comments/Instructions: HOW/~o - A:LFORMS~cheklist rev 03/94 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 effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER * ....... SCHLUMBERGER · COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-32 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20218-00 REFERENCE NO : 95172 o~$ Tape Verification Lis~ing Schlumberger Alaska Computing Center 2-NOV-1995 i5:50 **** REEL HEADER SERVZCE NAME : EDIT DATE : 95/11/ 2 ORIGIN : FLIC REEL NAME : 95172 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-32, API #50-103-20215-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/11/ 2 ORIGIN : FLIC TAPE NAME : 95172 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA, INC., KUPARUK 2T-32, API #50-103-20215-e0 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2T-32 501032021800 ARCO ALASKA, INC. .SCHLUMBERGER WELL SERVICES 2-NOV-95 BIT RUN 1 BIT RUN 2 JOB NUMBER: 95172 95172 LOGGING ENGINEER: RUMINER RUMINER OPERATOR WITNESS: TRANTHAM MORRISON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: 8E FNL: FSL: 567 FEL: FWL: 556 ELEVATION(FT FROM MSL KELLY BUSHING: 122.0e DERRICK FLOOR: 122.0~ GROUND LEVEL: 80.7~ WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4752.0 2ND STRING PAGE: .~$ Tape Verification LisSing Schlumberger Alaska Computing Center 2-NOV-J995 i5:50 SRD STRING PRODUCTION STRING REMARKS: Well drilled 24-APR through 3~-APR-95 with CDR & CDN. All data was collected in two bit runs and includes two short MAD passes. $ $ PAGE: **** FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 9s/ii/ 2 MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 5250.0 13787.e CDN 5180.0 13670.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE MAD MWD MWD $ REMARKS: 5177.0 5460.0 5460.0 13238.0 13238.0 13787.0 No depth adjustments performed as per Dave Sharer of ARCO. This file also contains the Very Enhanced QRO resisitivit¥ with 2' average that was reprocessed at GeoQuest. Density and Neutron data unavailable from 11402' down to 13033' $ o~$ Tape Veri~ica%i~n Lis%-ing Schlumberger Alaska Compu%ing Cen%er LIS FORMAT DATA 2-NOV-1995 15:50 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ,, TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 56 4 66 ~ 66 6 73 7 65 8 68 0.5 9 65 FT ~1 66 18 12 68 13 66 0 14 65 FT ~5 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619190 00 000 00 ~ 1 1 1 4 68 0000000000 RA MWD OHMM 619190 00 000 00 0 1 1 1 4 68 ~000000000 RP MWD OHMM 619190 00 000 00 0 1 1 I 4 68 0000~0000~ VRA MWD OHMM 619190 0~ 0~0 00 0 1 1 I 4 68 0000000000 VRP MWD OHMM 619~90 00 000 00 ~ 1 1 1 4 68 0000000000 DER MWD OHMM 619190 00 000 00 0 1 1 1 4 68 0000000000 ROP MW]) FPHR 61919~ 00 0~0 ~0 ~ 1 1 1 4 68 00000000~0 FET MWD HR 619190 ~0 000 00 ~ 1 1 1 4 68 ~000~0~000 GR MWD GAPI 619196 00 00~ ~0 0 1 1 1 4 68 600B0~0000 RHOB MWD G/C3 61919~ ~ 00~ ~ ~ 1 1 1 4 68 ~~ DRHO MWD G/C3 619190 ~0 000 00 0 I 1 1 4 68 0000000000 PEF MWD BN/E 61919~ 00 000 00 0 1 1 I 4 68 0000000000 CALN MWD IN 619190 00 000 00 0 1 1 1 4 68 00000000~0 NPHI MWD PU-S 61919~ 00 000 00 0 I 1 1 4 68 0000000000 ** DATA Tape Verificatien Lis~ing Schlumberger Alaska Computing Center 2-NOV-1995 15:50 DEPT. 13787.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MW1) VRP.MWD -999.250 DER.MWD -999.25~ ROP.MWD 62.283 FET.MWD GR.MWD -999.250 RHOB.MW1] -999.25~ DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 DEPT, 5177.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999,250 DER.MWD -999.250 ROP.MWD -999,250 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD 40.600 PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .~l SERVICE : FLIC VERSION : ~01C0! DATE : 95/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes, DEPTH INCREMENT: 0.5~00 FILE SUMMARY LDWQ TOOL CODE START DEPTH STOP DEPTH CDR CDN $ MERGED DATA SOURCE LDWQ TOOL CODE 5250.0 13248.8 5180.0 13248.~ MAD RUN NO. MAD PASS NO, MERGE TOP MERGE BASE MAD 1 1 MAD 2 1 5180.0 5460.~ 13150.0 13238.0 .~S Tape Verificaticn Lis~ing Schlumberger Alaska Computing Center 2-NOV-1995 15:50 REMARKS: No depth adjustments performed as per Dave Sharer of ARCO, This file also contains the Very Enhanced QRO resisitivity with 2~ average that was reprocessed at GeoQuest. # LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 l 5 66 6 73 7 65 8 68 0.5 9 65 FT Il 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 l 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619196 00 006 00 6 2 1 1 4. 68 RA MAD OHMM 619190 00 000 0~ ~ 2 1 1 4 68 0~0e00~000 RP MAD OHMM 619190 00 000 00 0 2 1 1 4 68 00000~00~0 VRA MAD OHMM 619190 00 000 00 0 2 1 1 4 68 000~000000 VRP MAD OHMM 619190 00 00~ 00 0 2 1 1 4 68 00000000~0 DER MAD OHMM 6~9~9~ 00 000 00 0 2 1 ~ 4 68 e00000~000 ROP MAD FPHR 619~90 00 000 00 0 2 ~ 1 4 68 00000~000~ FET MAD HR 61919~ 00 000 00 0 2 1 1 4 68 00000~0000 GR MAD GAPI 619190 00 00~ 00 0 2 [ [ 4 68 00000000~0 RHOB MAD G/C3 619190 00 000 00 0 2 [ 1 4 68 0000000000 DRHO MAD G/C3 619190 00 000 00 0 2 1 1 4 68 0000000000 PEF MAD BN/E 619190 ~0 000 00 0 2 1 1 4 68 000000000~ CALN MAD IN 619190 00 000 ~0 0 2 1 1 4 68 00000~0000 .$ Tape Veri~ica~i¢~ L[s~ing Schlumberger Alaska Computing Cen~er 2-NOV-1995 15:50 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NPHI MAD PU-S 619190 00 000 00 0 2 1 1 4 68 0000000000 DATA ** DEPT. 13238.000 RA.MAD 2.567 RP.MAD VRP.MAD 2.984 DER.MAD 2.785 ROP.MAD GR.MAD 99.383 RHOB.MAD 2.222 DRHO.MAD CALN.MAD 8.500 NPHI.MAD ** END OF DATA ** 2.944 VRA.MAD 365.798 FET.MAD 9.995 PEF.MAD 2.617 1.436 9.999 **** FILE TRAILER **** FILE NAME : EDIT .092 SERVICE : FLIC VERSION : ~91C91 DATE : 95/11/ 2 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/11/ 2 ORIGIN : FLIC TAPE NAME : 95172 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 27-32, API #50-[93-29218-99 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/il/ 2 ORIGIN : FLIC REEL NAME : 95172 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 27-32, API #50-i95-29218-90
