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185-115
ORIGINAL TRANSMITTAL DATE: 6/13/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4868 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4868 3B-11 500292136900 Production Profile (PPROF) 7-Jun-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 185-115 T38940 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.14 08:24:38 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 WELL LOG TRANSMITTAL #905480960 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 313-11 Run Date: 3/24/2019 185115 30 93 3 May 23, 2019 rft 11VC JUN 2 7 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3B-11 Digital Data in LAS format, Digital Log Image file 50-029-21369-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com ib Date: l��1l Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 0 2 2019 9"' OGCC 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: Patch ❑� 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development E Stratigraphic ❑ Exploratory ❑ Service ❑ 185-115 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21369-00 7. Property Designation (Lease Number):8. Well Name and Number: KRU 3B-1 ADL0025633 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,235 feet Plugs measured None feet true vertical 6,393 feet Junk measured None feet Effective Depth measured 9,235 feet Packer measured IRM 11.. e417. mea feet true vertical 6,393 feet true vertical 5749.570, swz. Wlt feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 16" 110' MD 110' MD SURFACE 4,188 feet 9-5/8" 4,219' MD 3,246' MD PRODUCTION 9,191 feet 7" 9,215' MD 6,376' MD Perforation depth Measured depth 8,630', 8,700', 8,744', 8,868', 8,936', 8,982' feet True Vertical depth 5,915', 5,966', 6,000', 6,096', 6,150', 6,187' feet Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 8,824' MD 6,062' TVD Packers and SSSV (type, measured and true vertical depth) SAFETY VLV - CAMCO TRDP-1A 1,823' MD 1,658' TVD UPR P21P PACKER 8,400' MD 5,748' TVD LWR P2P PACKER 8,428' MD 5,768' TVD BAKER HB RETRIEVABLE PACKER 8,477' MD 5,802' TVD OTIS WD PERMANENT PACKER 8,799' MD 6,043' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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 per20 A C 25.o70,25o71, s 25.283) 15. Well Class after work: Daily Report of Well Operations L] Exploratory ❑ Development 0 Service ❑ Stratigraphic El Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Name: Sara Carlisle / Rachel Kautz Authorized Name: Sara Carlisle Authorized Title: Well In rily Supervisor Contact Email: N2549@Conocophllllps.com — Contact Phone: 907-659-7126 Authorized Signature: `( �/ Date: - I Form 10-404 Revised 4/2017 V -L 11311'7 '* Y/?6r RBDMS-5✓APR 0 2 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 1, 2019 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch installed to remediate a tubing leak in producer KRU 313-11 (PTD 185-115). Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, sl' C&,b& Sara Carlisle Well Integrity Supervisor ConocoPhillips Alaska, Inc. 36-11 DESCRIPTION OF WORK COMPLETED Date I Event Summary 2/9/2019 TILF (FAILLED DUE TO INFLOW & PRESSURE INCREASE) 2/17/2019 2/28/2019 PERFORM LDL: LOG BASELINE TEMP TO CATCHER @ 8441' RKB. IDENTIFY LEAK @ APPROX 8413' RKB. LOG UP / DOWN PASSES ACROSS LEAK AND STATION STOPS @ 8420' & 8405' RKB. LOG MAIN PASS FROM CATCHER TO SURFACE. CORRELATED TO TBG DETAIL DEC 18 1988. PULLED OV & SET EXTENDED PACKING DV @ 8413' RKB. ATTEMPT TO TEST TBG W/ IA CONTINUING TO TRACK; PULLED EXTENDED PACKING DV @ 8413' RKB; CMIT TBG X IA TO 2500 PSI (PASS). CATCHER & PLUG REMAIN IN HOLE. 2/28/2019 RAN 24 ARM CALIPER f/ 8441'- SURFACE. DATA TO BE USED TBG PATCH. 3/24/2019 3/25/2019 3/26/2019 RAN 2 1/2 HYDROSTATIC BAILER TO K-3 PLUG @ 8413' RKB, PULLED 3 1/2 K-3 PLUG @ 8413' RKB, BRUSH n' FLUSH TBG W/ 75 BBLS DIESEL TO 8500' RKB BRUSH PATCH AREA FROM 8428' TO 8400' FOR 20 MIN'S, RAN 2.72" P2P PACKER TO SET DEPTH UNABLE TO SET PACKER DO TO TELEMETRY PROBLEMS. IN PROGRESS. SET 2.72" LOWER P213 ME @ 8428' RKB (DAL 4.01 / SN: CPP35208), SET 3 1/2 TTS TEST TOOL IN LOWER P2P @ 8428' RKB CMIT TBG x IA 2500 PASS, PULLED 3 1/2 TTS TEST TOOL @ SAME, SET 2.72"132P SPACER ANCHOR ASSEMBLY @ 8400' RKB ME (DAL 18.18.56' SN: CPP35143 / CPAL35105). IN PROGRESS. CMIT-TxIA to 2500 (PASS) Pre -Test T/I/0= 850/550/500 PRESSURE UP (2.2 BBLS) INITIAL T/I/0= 2500/2250/500 15 MIN T/I/0= 2475/2225/500 (25/25 LOSS) 30 MIN T/I/0= 2465/2220/500 (10/5 LOSS) BLEED BACK TO 1000 PSI 3 1/2 TTS TEST TOOL TO UPPER 2.72 P2P @ 8400' RKB MIT TBG 2500 PASS, PRESSURE IA & TBG TO PSI TO TEST SNAP LATCH FOR 30 MIN'S PASS. COMPLETE. MIT -T to 2500 psi (PASS) Pre -Test T/I/0= 850/575/500 Pump 0.7 bbls to pressure TBG to 2550 psi INITIAL T/1/0= 2550/675/500 15 MIN T/I/0= 2450/675/500 (-100) 30 MIN T/1/0= 2425/675/500 (-25) MIT -IA to 2500 psi (PASS) Pre-TestT/1/0= 2400/550/500 mp 2.4 bbls to pressure IA to 2500 psi ITIAL T/1/0= 2775/2500/500 MIN T/1/0= 2750/2450/500 (-25/-50) MIN T/1/0= 2750/2450/500 (0/0) 03/31/19 36-11 DESCRIPTION OF WORK COMPLETED RE-TIFL (PASSED) tial T/I/O = 140/1290/926, IA FL @ 7192' (271' above DMY ST N7,OV @ 7969' ST #8) wellhead @ WV & double block AL. 3cked WHP's to T/I/O = SI 1080/1100/682 in 1 hr, IA FL @ Same location ?d AL line Bled IA from 1100 psi to 480 psi in 1 hr T/1/0 = SI 1050/480/550 IA FL @ Same location, Monitor for 1 hour. 15 min T/I/O = SI 1050/480/545 30 min T/1/0 = SI 1050/480/540,IA FL @ same location 45 min T/I/O = SI 1050/480/535 60 min T/I/O = SI 1050/480/530 IA FL @ same location KUP PROD WELLNAME 3B-11 WELLBORE 3B-11 conocoPAlaiI . Alaska.IrSc. SB.11.a4i201.1ID.IIA. Mandrel Inserts m.imn[(x�ml St ---C HANGER'.2]6 - on N Tep lflNBl To AE) 1NNB) Meka MOtlel OO (In) Sery rise Typ raw, Type PoM1 )f Iin) TRO Run (pel) Run Dake Com 1 8,5906 5,885.6 DAMOO MMG2 i tl2 PROD DMY RK FIo 0000 0.0 10122010 _TNN Lai 1 B.I]4.0 8.0246 CA.MCO MMG-2 t tl2 PROD DMY RK 0.000 00 12162002 2 Clasetl coxovcroa',uwlpa Notes: General B Safety Entl oateAnn.' e P SNETYYLN.i8R8 ]0)2010 NOTE View Schemalle wl Alaska Sch,maric00(2 pages) 1141201] I Ni: Waiveretl for WxOA communication Gnsun:2.W2a GAS LIFT: 4,0944 SURFACE: 5521.218.5- GAS II FT; 45250 GAS UEr:6an i GAS U". 81W.5 GAB LIFT', U.I GAS UFT: 1481s GAB UFr: I...,5 UPR PNR N Ey, 8,49000 LEAR. H.411 8 $PACERPSG L. .0 GAS UFT 84128 LWR 1. WE), 8.4260 PRR a4R i Pg41(ER: a <]a5 en-UnCTION', B.a16.i PRODUCTION:8.5908 e H8W 0 RaH (PERF , Can PERF:MW.0$7078 (PERF: 8,140.88.]52, FPAC', 8]H, PRODUCTION: a.]i48 NIPPLE: BMS4 LOCATOR',.... PACER: E sea I LEAK: e.ep2D 59E. B,P425 NPPLE', sa14.1 am BaDB (PERF: 88W.P8,810.0� IPERF:9,SBBD&9980� )PERF', 8,982.04Us7X PRODUCTION: 2148215, ji S-11- PRoAcTivE DIAGNGSTIG SERVICES, INC. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) 1851 15 50483 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letterto the attention of 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVE® Attn: Diane Williams 130 West International Airport Road MAR 2 2 2019 Suite C Anchorage, AK 99518 AOGCC adsanchorage(cDmemorvlog com 28 -Feb -19 313-11 1 Report / CD 50-029-21369-00 Date : LAG W PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx (907)245-8952 E-MAIL: PDSANCHORAGE(aDMEMORYLOGCOM WEBSITE: WWW.MEMORYLOGCOM Dalch[mdALole, CenplvmPiles,5emyleres�C;xvi'wtlon7vn avifllelShc.tl^o:a.�Phillip� Tian icdo(x In 5 304$3 Memory Multi -Finger Caliper Company: ConocoPhillips Alaska, Inc. Log Date: February 28, 2019 Log No.: 15669 Run No.: 1 Pipe Description: 3.5 inch 9.3 Ib. J-55 ELIE 8RD ABMOD Log Results Summary Well: Field: State: API No. Top Log Interval: Inspection Type: Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of GLM 9 at 8,412.6 feet (Driller's Depth). 3B-11 Kuparuk Alaska 50-029-21369-00 Surface 8,435 Ft. (MD) This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage, particularly in the vicinity of a leak in GLM 9. The caliper recordings indicate a hole at the top of GLM 9 at 8,414 feet. A 3-D log plot of the caliper recordings across GLM 9 is included in this report. The caliper recordings indicate the remainder of the 3.5 inch tubing logged appears to range from good to fair condition, with a maximum recorded wall penetration of 22% at an isolated pit in joint 264 (8,197 ft). Recorded damage appears as a line of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS: Hole inside GLM 9 100 270.1 8,414 Ft. (MD) Isolated Pitting 22 264 8,085 Ft. (MD) Line of Pits 21 260 7,707 Ft. (MD) Line of Pits 20 248 8,410 Ft. (MD) Line of Pits 20 270 6,398 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. B. Suhanek C. Waldrop S. Ferguson FWC1:v_ D{aynostic ;er;cF,, Irc. / ?.0. Sox Stafford, TX '7=97 "kone. (2x5) 431-7109 or ;r,5 -9n,, i -x: (ic1` ^311-7125 E-.na3fl PDSAnalysisc:memorvlogcom Oay Plaid Oifice Pi.c;�,: (9cl) 6'°9-2307 Fax: 19071 669-7.314 Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-5.7'-8,435.0') Well: 3B-11 Field: KIIparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 28, 2019 Ji 'S PDS Report Overview Body Region Analysis Well: 313-11 Survey Date: February 28, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf I-55 EUE 8RD ABMOD Analyst Waldrop ne Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABMOD 2.992 in -6 ft 8,435 ft Damage Profile (%wall) Penetration body Metal loss body 0 50 100 GLM 1 (4:00) GLM 2 (12:00) GLM 3 (7:00) GLM 4 (5:00) GLM 5 (8:00) GLM 6 (1:00) GLM 7 (5:00) GLM 8 (10:00) GLM 9 (8:30) Bottom of Survey = 271 ii-�s PDS Report Joint Tabulation Sheet Well: 36-11 Survey Date: February 28, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf J-55 EUE BIRD ABMOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. -6 ft. 8,435 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 0.1 -6 0 0.02 6 2 192 Pup Lt. Deoosits. 1 -1 0 0.03 10 3 2.8 t. De ,sits. 1.1 32 0 0.02 6 1 2.91 No Lt. Deposits, 1.2 42 0 5 2 2.89 Pu Lt. Deraosits. 1.3 51 0 0.03 10 2 2.88 Pup Lt. Deposits. 2 57 0 0.03 10 2 2.88 Lt. Deposits. 3 90 0 10 22.960 Lt. De posits. 4 121 0 0.02 7 2 2.9 t. Deposits. 5 154 0 0.02 1 1 2 2.90 Lt. Deposits. 6 187 0 0.02 1 2 2.89 Lt. Deposits. 7 219 1 0 0.03 10 3 2.93 Lt. Deposits. 8 249 0 0.03 10 3 2.93 It. Deposits. 278 0 0.03 1n 2 2.91 Lt. De sits. 10 310 0.04 0.03 13 3 2.9 11 342 0.04 0.03 11 2 2.94 1 374 0 0.03 11 2 9 92 1 Lt. ,sits. 13 404 0 0.02 7 2 1 2.90 Lt. Dera,sits. 14 437 0 0.03 10 3 2.92 Lt. Dcpo its. 15 468 0.05 003 11 4 2.93 Lt. Dpnnsits. 16 497 0 0.03 10 2 2.91 Lt. Deposits. 17 527 0 0.03 1 10 3 2.89 Lt. Deposits. 18 558 0 0.04 1 15 3 2.91 Shallow Line of Pits. Lt. DeDO.Sitq. 19 588 0 0.02 8 3 2.92 Lt. Deposits. 617 0 0.03 11 3 2.92 Lt. De s. 21 646 0 0.03 11 4 2.94 22 678 0 0.03 10 3 2.93 Lt. De sits. 23 708 0 0.03 11 3 2.91 Lt. Deposits. 24 737 0 0.03 1.3 3 2.91 Lt. De ,sits. 25 766 0.04 16 3 2.9 Shallow in of Pi Deo . 26 797 0 0. 4 16 5 1 2.93 Shallow Line of Pits. I I. Deposits. 27 829 0 0.02 8 1 3 2.92 Lt. Der),sits. 28 1 860 0 0.03 10 1 3 Lt. Deposits. 29 890 0 0.03 11 3 --2.93 2.91 It. Dpnosits. 30 918 0 0.03 13 3 2.92 Lt. Dep,sits. 31 948 0 0.03 Vi 4 1 Lt. Deposits. 2 978 0 0.02 9 2 288 It. DenositS. 33 1009 0 0.02 9 4 2.91 Lt. Deposits. 4 1039 0 3 10 2.90 Lt. D sits. 5 1071 0 0.04 17 2.92 Shallow Line of Pits. Lt. Deposits. 36 1099 0 0.03 11 2 2.92 Lt. Deposits. 37 1131 0 .04 17 2.93 hall Pitting. Lt. Deposits. 38 1160 0 0.0 8 2. Lt. De it . 39 1189 0 0.03 10 2 2.94 40 1220 0.03 1 4 .Q 0 If sits. 41 1250 0 0.02 9 2 2.92 Lt. Deraosits. 42 1282 0 0.03 11 2 2.94 43 1313 0 0.02 1 9 2 .94 44 1345 0 0.03 I 11 2 2.91 Lt. De osits. 45 1377 0 2 9 2 2.93 46 1409 0 0.03 i 2 2.93 Penetration Body Metal Loss Body Page 1 ii-�s PDS Report Joint Tabulation Sheet Well: 3B-11 Survey Date: February 28, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf J-55 EUE 8RD ABMOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. -6 ft. 8,435 ft. Joint No. Jr. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 47 1440 0 0.03 11 2 2Deposits. 48 1469 0 0.02 9 2 2.92 Lt. Deoosits. 49 1501 0 0.03 11 3 2.90 Lt. Deposits. 50 1533 0 0.03 11 3 2.94 1 1564 0 0.04 15 4 2.94 Shallow Pitting. 52 1593 0 0.03 10 3 2.89 Lt. Deposits. 3 1622 0 0.03 11 2 2.94 54 1654 0 0.03 10 4 2.92 Lt. Del2osits. 55 1685 0 0.02 B 3 2.93 1 Lt. De ,sits. 1715 0 0.02 9 2 2.94 57 1747 0 0.02 'l 2 2.90 Lt. Deposits. 1776 0 0.02 9 2 2.92 Lt. Denosits. 58.1 1807 0 0.02 9 1 2.91 Pup Lt. De sits. 58.2 1818 0 0 0 0 2.81 CAMCO TRDP-tA SSSV 52 1828 0 0.02 1 7 2 2.93 t De ,sits. 60 1856 0 0.02 8 2 2.90 Lt. Deposits. 61 1886 0 0.02 9 2 2.93 L.t. Deiposits. 2 1915 0 0.03 10 3 2.95 63 1946 0 0.03 12 2 2.93 Lt. De ,sits. 64 1978 0 0.02 8 3 2.91 Lt. Deposits. 65 2007 0 0.03 to 2 2.94 66 2038 0 0.02 9 2 2.90 Lt. Deposits. 67 2068 0 0.02 8 3 2.93 Lt. Deposits. 68 2099 0 0.03 11 2 2.93 Lt. De osit . 69 2130 0 0.03 129 Q9 i t. e ,sits. 70 2160 0 0.02 8 2 2.89 Lt. Deposits. 71 2190 0 0.03 10 3 2.93 72 2222 0 0.03 11 1 3 1 2.95 73 2253 0 0.02 9 2 2.93 Lt. Derposits. 74 2282 0 0.04 14 4 2.95 74.1 2311 0 0 0 0 2.85 GLM 1 LATCH @ 4:00 75 2318 0 0.03 11 3 2.93 Lt. De osits. 76 2347 0 0.02 8 2 2.95 77 2377 0 1 0.03 10 3 2.93 8 2405 0 0.02 9 2 2.93 Lt. Deposits. 79 1 2435 0 0.03 12 2 2.93 Lt. Dei3osits. 8 Q 2464 0 0.02 9 2 2.93 1 Lt. De osits. 1 2494 0 0.02 8 4 2.91 Lt. Deposits. 82 2522 0 0.03 11 2 2.90 Lt. Deposits. 83 2552 0 0.04 14 3 2.94 4 2581 0 0.03 12 2 2.91 Lt. Deposits. 85 2611 0 0.04 14 3 2.93 Lt. Deposits. 86 2641 0 0.04 14 3 2.92 Lt. Deposits. 87 2672 0 1 0.04 17 3 2.93 Shallow Line of Pits. 88 2702 010.02 8 3 2.94 8 2 1 9 2 .92 t. e o . 90 2759 11 2 .90 Lt. its. 91 2789 9 3 2.93 Lt. sits. 9 1 10 4 2.88 Lt. Deposits, 28-50 14 1 3 1 2.93 Penetration Body Metal Loss Body Page 2 ji4s- Well: Field: Company: 3B-11 Kuparuk ConocoPhillips Alaska, Inc PDS Report Joint Tabulation Sheet Survey Date: February 28, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf Nom. ID Body Wall Top Depth J-55 EUE 8RD ABMOD Tubing 2.992 in. 0.254 in. -6 ft. Bottom Depth 8,435 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Prn. 'io Metal Loss °% Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 94 2880 0-602 8 2.90 Lt. Deposits. 5 2910 0 0.04 15 4 2 90 Sh Ilow Pitting. Lt. Deposits. 96 2941 0 0.02 9 1 2.91 Lt. De osits. 97 2971 0 0.04 16 3 2.91 Shallow Pitting. Lt. Deposits. 98 3003 0 0.03 10 0 Lt. L2212osits. 99 3034 0 0.03 12 3 2.88 Lt. Deposits. 100 3066 0 0.02 8 2 3 Lt. -sits. 10 7 0 .03 11 3 2. Lt. D o its. 102 3129 0 0.04 15 2 2.90 Shall w Line of Pits. Lt. Deposits. 103 0.03 12 3 2. Lt. osits. 104 3191 0 0.03 1n 2 2.92 Lt. De -sits. "52 0.04 16 2 2. 2 Sh II w Pittin t. De its. 106 3254 0 0.03 11 2 2.9 Lt. sits. 1073286 0 0.02 9 3 2.94 108 18 0.03 11 3 2. 2 Lt. osits. 10 335 0 0.04 17 42.9 Shallow Pittin Deposits. 110 3379 0 0.04 15 2 2.92 Shallow Pittin . Lt. D -sits. 111 411 0 0.02 9 4 2.9 Lt. D sits. 112 344 0 0.02 9 1 2 1 2.91 Lt. Qenosits. 113 34710 0.03 12 3 2.92 Lt. Deposits. 114 35 0 .03 10 3 2.92 Lt. De sits. 91 3529 1 0 1 R01 13 2 9RA Lt Qe osi s 116 35590 0.02 9 3 2.92 Lt. De osits. 13550 5 0 0. 4 14 3 2.93 Lt. De its, 118 3622 1 0 3 11 3 2.93 119 3651 0 0.03 11 4 2.93 120 3682 0 .03 11 3 2.93 Lt De sits. 121 3714 0.04 0.03 10 2 2.92 Lt. Deposits. 122 374 0 .03 11 3 2 Lt. Denoits. 123 3774 0 3 11 3 2.91 Lt. its. 124 3806 0 0.03 10 2 2.93 125 383 0 00 11 2 2.92 Lt. Dpl2Qsits. 126 3869 0 .0311 .89 De its. 127 3898 0 0.02 9 3 2.96 128 3928 0 0.03 3 2.93 t. D it . 129 3959 0.04 0. 4 2.92 Lt. De o it . 130 3989 0 0.02 9 3 2.94 131 4021 0 0.03 1 2 .92 Lt. QQt2Qots. 132 4052 0 0.0 11 3 2.90 I Lt. De o it . 132.1 4084 0 0 0 0 2:89 GLM 2 LATCH 0 12:00 133 4091 0 0.0 12 3 2.91 Lt. 134 4121 0 .0 8 3 2.93 L De its. 135 4150 0.05 0.02 9 3 2.90 Lt. D - >sits. 136 41 2 0.03 1.3 3 Lt. -sits. 137 1 4214 1 0 0.03 10 2 2.93 Lt. D---- -s138 138 4 4 0.02 L. ---- -s139 139 4277 0.02 2 2. Lt: sits. 140 4306 0 0.03 10 2 2.92 Lt. D ---- -s141 141 4 3 00.03 11 3 . D---- s142 142 4 8 0.0 1( 4 0 Lt osi Penetration Body Metal Los's Body Page 3 ji_'s Well: Field: Company: 313-11 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 28, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf Nom. ID Body Wall Top Depth J-55 EUE BIRD ABMOD Tubing 2.992 in. 0.254 in. -6 ft. Bottom Depth 8,435 ft. Joint It Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) R,n. Metal Loss % Min. I.D. (in.) Comments Damage Profile I% wall) 0 50 100 143 0.03 11 2 2.91 Lt. De its. 144 1 4430 10Q 4 15 3 2.92 Shallow Pitting, Lt. Deposits. 145 1 4462 1 0 0.02 9 2 2.92 Lt. De osits. 146 1 4494 1 0 0.04 14 3 Z94 147 1 4525 1 0 0.02 9 2 2,93 Lt. Qgposits. 148 4557 0 0.02 9 2 2.92 Lt. De osits. 149 4587 0 0.03 11 2 2.91 Li. Deposits. 150 4616 0 0.03 11 2 2.93 Lt. Deposits. 151 4647 0 0.02 9 3 2.93 Lt. Deposits, 152 4 77 0. 9 2 2.91 Lt. Deposits. 153 4706 0 0.02 8 3 2.93 Lt. Deposits. 154 4 36 0.0 13 2 2.92 Lt. Denosits. 155 4767 0 0.02 9 2 2.88 Lt. QQIaosits. 156 4798 0 0.03 12 2 2.90 Lt. Deposits. 157 4 29 (1.04 0.03 11 2 2.95 158 48 0 0.03 11 2 2.93 159 4890 0 0.02 9 2 2.93 Lt. De osits. 160 4 21 0 0.02 $ 3 2 2 Lt. D osits. 16 4951 0 0.03 13 3 2.92 Lt. De osi s. 162 1 4983 1 0 0.03 12 22.91 Lt. De osits. 163 5014 0.02 $ 2 2. Lt. D sits. 164 5046 0 002 9 1 2.87 Lt. De sits. 165 5075 0 0.03 10 2 2.92 Lt. Deposits. 166 51 7 0.03 11 3 2. 1 It osits. 167 5137 0 .0 11 1 .92 1 t. Deno its. 168 L5169 0 0.02 9 2 2.90 Lt. De osits. 169 1 12on 0.0 9 2.94 170 5229 0 0.03 2 2.93 11. De osits. 171 5 0 .03 11 3 2. Lt. sits. 172 52 0 11 jjj1 2 2.92 L . it . 172.1 5322 0 f63 (102.90 GLM 3 LATCH 7:0017 53 0 13 42.93 174 5360 0 0.04 1 3 2.91 Shallow Line of Pits. Lt. Deposits. 175 5391 0 0.02 9 3 2.93 Lt. Deposits. 176 5419 0 0.02 9 2 2.92 Lt. QQQQsits. 177 1 5451 0 0.03 10 2 2.92 Lt. Deposits. 178 5483 1 0.04 0.02 9 2 2.91 Lt. Deposits. 179 5 0.03 1 2 2.91 t. e o i s. 16 0 5545 0 0.03 10 3 1 2.90 Lt. Dej2Qit. 181 5574 0 0.03 11 2 2.91 It. De osits. 182 56 0 0.03 10 4 2. Lt. sits. 183 563 0.04 0.03 10 3 2.87 Lt. Deposits. 184 1 5668 0 0.02 9 2 2.92 it. Deposits. 185 5698 0 0.03 12 4 2. 186 5730. 0 0.03 11 2 2.92 Lt. Deposits. 1 7 61 .04 G02 9 2 2.90 sits. 188 5791 0.02 9 291 Lt. Deposits. 189 5821 0 0.03 11 3 2.9 Lt- De osits. 1 850 0.02 2.94 i i 80 0. 3 10 2 2. Lt. osits. Penetration Body Metal Loss Body Page 4 ji � Well: Field: Company: 3B-11 Kuparuk ConocoPhilips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 28, 2019 Analyst: Waldrop Pipe Description Nom. ID Body Wall Top Depth 3.5 in. 9.3 ppf J-55 EUE BIRD ABMOD Tubing 2.992 in. 0.254 in. -6 ft. Bottom Depth 8,435 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. `Yo Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 192 5911 0 0.04 14 4 2,92 Lt. Dej2osit5. 193 5940 0 0.04 14 2 2.95 194 5972 0 0.03 11 2 2.89 Lt. Deposits. 194.1 6004 0 0 0 0 2.89 G (LATCH 5-00) 195 6010 0 003 12 2 2.93 196 6042 0 0.03 10 3 2.91 Lt. De posits. 197 6072 0 0.03 11 2 2.92 Lt. Deposits. 198 6104 0 1 0.0313 2 2.91 Lt. Deposits. 199 6136 0 0.03 13 3 2.88 Lt. Deposits. 200 6167 0 .03 11 3 2.90 Lt. De s ts. 201 6199 0 0.03 11 2 2.93 Lt. Deposits. 202 6231 0 0.03 10 2 2.91 Lt. Daposits. 03 6262 9 2 2.91 Lt. Demsits. 204 6294 0 0.03 10 2 2.93 Lt. Deposits, 205 1 63260 9 2 2. 06 6357 0. 4 15 4 .93 hallow i of Pit . t. D osits. 206.1 6389 0 0 0 0 2.91 GLM 5 LATCH @78:00 207 6 96 0.0 L19 4 .88 Shallow 'ne of Pi . Lt. Q --m- i8 208 642 0 0.04 17 2 .92 hall w ine of PitsI I sits. 209 6458 0 0.05 18 3 2.91 Shallow Line of Pits. Lt. De osits. 210 489 0.0 ib 4 .92 low P' fin . Lt. De osits. 211 6 1 0 0.045 2 3 Sh Ilow Pit'n . Lt. e osits. 212 6552 0.04 0.05 18 2 2.92 Shallow Line of Pits. Lt. Deposits. 13 83 0. 4 14 2 214 661 0 0.02 B 2 i Lt. osi s. 215 6646 0 0.03 12 2 2 91 Lt. De osits. 16 6678 0 0.02 9 2 92 217 6709 1 0 0.02 9 1 2.91 LL De osits. 18 6741 1 0 0.0312 2 .91 i s. 219 Q.03 3 2 2.90 Lt. osit 220 6805 0 0.03 11 2 2.91 Lt. De osits. 21 1 6536 0 0.03 2 .94 222 1 6869 0 0.03 12 2 2 92 e osit . 223 6900 0 0.03 11 3 2.93 Lt. De osi ts. 224 6931 4 24.1 6963 0 0 0 0 .88 M 6 LAT H G?? 1:0 225 1 6969 0 0.03 1 1 2 2.91 Lt. De osits. 226 1 7000 0.0 10 s. 227 703 0 .03 12 2 2'91 Lt. e osit . 228 7061 1 0 Q.04 1 16 1 4 .91 Shallow Pitfin . Lt. De osits. 229 7 0.0 10 2 1 osi 230 712 0 0.04 1 14 1 2 .90 t. osits. 231 7154 0 0.04 16 3 2.90 Shallow Line of Pits. I n e osits. 232 718 4 15, 2.89 hallow ine of Pi t. D si s 233 7216 0 0.03 13 2 2.92 Lt. De osits. 234 7248 0 Q.05 19 3 2 Shall Line nf Pits. L. Denosits. 235 7280 0 4 17 2 2.8 Shallow Line of Pits,Lt Deposits, 236 7312 0 0.03 12 3 2.92 it. De osits. 7 7343 0 .04 1 5 3 2.9Q Shallow Pitting. Lt. . 238 7373 0 0.04 16 3 -2.90 Shallow Line of PiLs. Lt. Denosits. Penetration Body Metal Loss Body Page 5 i4S Well: Field: Company: 3B-11 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 28, 2019 Analyst: Waldrop Pipe Description Nom. ID Body Wall Top Depth 3.5 in. 9.3 ppf J-55 EUE 8RD ABMOD Tubing 2.992 in. 0.254 in. -6 ft. Bottom Depth 8,435 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 9 4 0 0. 4 15 t allow Line of Pits. Lt. D o its. 24 74 0 0.03 11 2 2.88 Lt. osits. 240.1 7460 0 0 0 0 2.90 GLM 7 LATCH kji 5:00 241 7470 0 0.03 12 3 2.90 Lt. Derposits. 242 7500 0 0.04 14 3 2.92 Lt. Deposits. 243 7531 0 0,04 15 4 2.92 Shallow Line of Pits. I.A. De osits. 2447563 0 0.03 1 2 2. Lt. si s. 45 7595 0 4 17 2.90 Shallow Pitting. t. Deposits. 246 7627 1 0 0.03 13 3 2.89 Lt. Deposits. 247 7659 4 14 2 2.91 Lt. Deposits. 248 7690 0 0.05 20 3 2.90 Line of Pits. Lt. De osits. 249 7722 0 0. 5 19 19-0 Sh II w Linf PitsQMg_!iijs 250 7754 0. 4 17 2 2.88 hall w Line of Pi. I I Deposits 251 7785 0 0.04 16 2 2.90 Shallow Pitting. Lt. Deposits. 252 781 7 0 4 17 3 2.8 Shall w Line f its. Lt. osi 253 7848 0 0.0 16 2 2.87 Shallow Pithng. Lt. Denosits, 254 7880 0 0.04 15 2 12.89 Shallow Line of Pits. Lt. Deposits. 255 1 7909 0 0.04 15 2 42.88 Shallow Line of Pits. Lt. Deposits. 6 1 7940 1 0 0.04 15 2 2.88 hallow Line of Pits. Lt. Deposits. 256.1 7971 110 0 0 0 2.89 GIM 8 LATCH @ 10:00 5779 8 0. 18 3 .92 Shallow ine of Pi . Lt D sits. 258 801 0 0.04 15 2 .90 Shall w i e of Pi t. De osits. 259 8042 0 .03 11 3 2.92 Lt. De osits. 6 0 0.0 21 .90 ine of P' . Lt. ,if, 261 8105 0.05 0.04 14 4 2. t. De osits. 262 8134 0 0.04 14 2 2.91 Lt. De osits, 63 8164 0 0.03 12 2.90 Lt, DQQQsits. 264 8196 0 0.06 22 2 2.89 Isolated Pitting. Lt. De osits, 65 8227 0.03 = 2 .90 Lt. De sits. 266 8258 0 0.04 14 .93 Lt. QeDosits. 267 8290 0 0.03 13 2 2.90 Lt. Deposits. 68 8320 0 603 10 2.92 Lt. De osits. 691 8350 0 0.04 17 3 2.93 Shallow Pittin . Lt. e osi 270 8382 0 0.05 20 5 2.93 :--of Pits. Lt. Deposits. 1-27U.1 0413 0 0.31 100 0 2.88 GLM 9 NLATCH a 8:30 HO E! 71 8426 0 0.04 16 2.92 Shallow Pitti . Lt. n---. . Penetration Body Metal Loss Body Page 6 ji: S Field: Company: Country: 313-11 Kuparuk ConocoPhillips Alaska, Inc. USA PDS Report Cross Sections Survey Date: February 28, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 270.1 at depth 8,413.520 Tool speed = 49 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 89% Tool deviation = 40° Finger = 4 Penetration = 0.308 in. Hole Inside GLM 9 0.31 in. = 100% Wall Penetration HIGH SIDE = UP PDS Report Cross Sections Well: 313-11 Survey Date: February 28, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 _ Tubing: 3.5m. 9.3 ppf J_55 EUE 8RD ABMOD Analyst: Waldron Cross Section for Joint 264 at depth 8,196.509 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area — 98% Tool deviation = 47° Finger = 7 Penetration —0.055 in. Isolated Pitting 0.06 in. = 22% Wall Penetration HIGH SIDE = UP PROD WELLNAME 38-11 r�` YiB'XB�� GX1a Aa wllps FYM Name MIBR NYI WN4en APLllpll I bIC. 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CAMCO UC 1 G4 GLV BK .t 1 10 013 S.pS.O 3, CAM UG 1 L ddV BK D. 1106 4 8.009.7 1„366.1 GMAM muu I t LPSLll-1 IQLV BK 11561 1.]SY.05232013 5 .391: 45723 CAMOO KBLIG 1 GA9 I T OW BK '1000"020 0 D GO 1 E2OC2 wre.aancAvaO- 6 6,9$.1 4,9x4,9 pp NBU(i 1GAS LFFT GLV BTM 0.108 t2 ➢11 t9 ] J. 6 ,180.2 (X1 ItR 1 LIFT NpnB 0 ,0 4(iry19 M`m.9pon.pelXflO� B ],967. ;47 S KB A LF 188 1, 5!231215 3,41. ,TS]0 FT tlr2 GAS LBT OPEN &1]2 I RGIN: pARASK/Y� 1U &51 MM 11D pYy RK 1p ,[OJ 0 dl Ru pA pneplcTwrLalswLP Conoc;,PWIITT ` Flasks enc. OIBBtTv fN .d "if ;e 114 51 tl fip(RRBI TIm�M1i Mvb MetlN 2 Bary A. 1y�. _ N P a1OWSNu T(.11 Cem - ryv,NGpp:yg &680,8 5. SS CAMC MMG3 11 PRW TN aW 00 0.0 Ip2ip010 corv0lx:Toxso-�mA 1 2 a,T/d.8 8, eA.A G9MC MMG73 1 2 ROU DMY RI( CIa6M 0. 0 .0 tLM100 �e oN6 rmomn sdFF1YxV.I6I10 nrz010 TE'1l�Mv emalcwlNeate Mica. (2 p6g6a1 tIY29P N61e: W6Nere0 tatWOw common maim vA6 un.6Ro4s Gn6urr apld avrudc6 am 110 uv1. 6.am.o 36 11A.6➢Y) 4A:iIFt'.6AN6 GAS IYT:9,µ21 MSIIR: T,6B16 Gd6 VI: iSNA L6VL 0}1]6 o6nuFr.61+6s— w' Mev wiA nm,e.. Flud 0.taY0 PBP. 6,161.1 PPCY.61. &1Ie,! MOIXM:igN iFM.i v�o�cruw 4i6a IFCRF: Mawz7G FRK 4WU➢ FRRG.67[ ®QM, B.aca.p6,iP1A ' poo mcw:aMC i«usnxn vw�ousrw s,na6 i66P1$4r6w LO['.tTIXt 4T945 6Ew:4dm6 seea,6mA mvxc,eeui S 1'0.6116 Nkl6.4m4DN8140- PEPc: 46t46a.6uA� NG(K 69310.0.06]0 PR06YCTIM N1 "M 185115 WELL LOG TRANSMITTAL #905480960 30371 To: Alaska Oil and Gas Conservation Comm. February 13, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 313-11 Run Date: 02/01/2019 and 02/09/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 3B-11 Digital Data in LAS format, Digital Log file RECEIVE® 1 CD Rom 50-029-21369-00 FEB 19 2019 AGGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: WlqlX�q Signed: • • PTV I 5--115 Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday,January 04, 2017 10:08 AM To: Loepp, Victoria T (DOA) Cc: NSK Problem Well Supv Subject: 3B-11 (PTD# 185-115) OA sustained casing pressure Attachments: 3B-11 Schematic.pdf; 3B-11 90-day 110 plot.docx Follow Up Flag: Follow up Flag Status: Flagged SCANNED APR 2 8 2017, Victoria, KRU gas lifted producer 3B-11 (PTD#185-115) is experiencing sustained casing pressure of the outer annulus (OA) and operations is having difficulty maintaining the pressure below the 1000 psi DNE. The well passed a MITOA on 9/2/2016 and a TIFL on 12/23/2016, indicating the IAxOA communication is to gas only. CPAI plans to waiver the well to allow the lAxOA communication and let the well's OA pressure operate up to 1400 psi. The surface casing is 9 5/8" 26#J-55 casing that has a burst pressure rating of 3520 psi, so allowing the OA to operate up to 1400 psi does not exceed 45%of the casing burst rating. Please let us know if you have any questions or disagree with this plan. Attached is a schematic and 90 day TIO plot. Regards, Rachel Kautz Well Integrity Engineer,ConocoPhillips Alaska, Inc. Temp.Slope Phone:907-659-7126 (Filling in for Dusty Freeborn/Jan Byrne) 1 • • rn p Psi row= W MUD.BLPD [n n. is 'r_; >�+ a .-. co w 4 m Er; ' WIp III P as9 jos* o v -u G Cri N • Q p � a f o [1 C) l O NN 0 m f LOi o --k------__<11 N i T fS n 1 ...i r r-."-- •' a11, I I -' A 6 o o 8s degF o IMIIMIIIIIIIMIMIIMIMINIIMMMIIMIIMIIIIIIIMMIIIMIMIIIIIMIS C,) aCOa 0)CO Ca .a T T COT T W w T n T T T T T mt P Ir a iit 2 §2 2§2 k7; A C)C)CO 0)0)Cr)Cr)0)CO C)CO W co 1 S �ppp{ppp��pp�tpp ttyp N p t�pp '.�9 N C 7 C i b Q 0 0 0 P G O O y m m Z m O a 23 M 0 r w WN W���,a aNy N�ptp Ap NNA NNA��App�cApp A N w 6 b 0 O S b 6 b G o N O O O O O O O O O O O O r c ccccccccccp, 737073737373707373XI7373z 60 000000000000 y RI KUP PROD4111 3B-11 COnOCOPhilli�1C a Well Attributes Max Angle&MD TD Alaska Inc.InWellbore API/Ad Field Name Wellbore Status ncl(°) MD(MKS) Act Btm(RKB) co.....,,,_4.“hips 500292136900 KUPARUK RIVER UNIT PROD a 57.52 7,600.00 9,235.0 ... ,."•.• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3e-11,7/10/2015 9.27:43 AM SSSV:Locked Out 160 12/19/2012 Last WO: 12/18/1988 35.80 6/27/1985 Verocal sd,emabc(actual Annotation Depth(ftK8) End Date Annotation Last Mod By End Date Last Tag:SLM 8,860.0 7/8/2015 Rev Reason:TAG hipshkf 7/10/2015 "� _ HANGER;23.6 Casing Strings Casing Description Oil(in) ID(in) Top(ftK8) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread (■ CONDUCTOR 16 15.062 33.0 110.0 110.0 62.50 H-40 WELDED �I r2. Casing Description OD(in) Ib(in) Tap:f6:3)0) 6K6) SM Depth(ftK8) Set Depth(NDI...Wtt en(I...Grade TOP Thread 1 SURFACE 95/8 8.921 302 4,218.5 3,246.2 36.00 J-55 BTC 1111 � f' Casing DescriptIon OD lin) ID(in) Top(ftK8' Set Depth(ftK8) Sri Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 24.0 9,215.0 6,376.6 26.00 J-55 BTC CONDUCTOR;33.0-110.0 Tubing Strings Tubing Description 'String Ma...I ID(in) "Top(ftKB) 'Set Depth(ft..i Set Depth(TVD)(...IWI('blit)- (Grade 'Top Connection TUBING WO 3 12 9 2.992 23.6 8,824.2 6,062.4 301 J-55 EUE8rdABMOD SAFETY VLV;1,8226 le Completion Details Nominal ID GAS LIFT;23023 - Top MKS) Top(TVD)(1tKB) Top Incl(') Item Des Com (in) g 23.6 23.6 0.02 HANGER FMC GEN III HANGER 3.500 1,822.6 1,657.5 47.75 SAFETY VLV CAMCO TRDP-1A(Locked Out on 8/29/97) 2.813 GAS LIFT;40944 Ir 8,462.7 5,792.5 44.50 PBR BAKER PBR 3.000 8,476.5 8802.4 44.18 PACKER -BAKER HB RETRIEVABLE PACKER 2.890 8.632.9 5,917.1 41.67 BLAST RINGS BLAST RINGS(2) - 2.992 SURFACE;30,2.4,218.5-.• I I 8,705.8 8971.9 40.99 BLAST RINGS BLAST RING(1) 2.992 GAS LIFT;5,38.0 • 8,752.8 6,007.5 40.33 BLAST JT BLAST JOINT(1) 2.992 GAS UFT;6,019.7 - 8,785.4 6,032.4 39.87 NIPPLE OTISX NIPPLE 2.813 8,796.5 6,041.0 39.72 LOCATOR OTIS LOCATOR w/SPACE OUT 3.000 GMS LIFT;6,384.5 8,799.1 6,043.0 39.68 PACKER OTIS WD PERMANENT PACKER 4.000 GAS LIFT;8,9821 8,802.5 6,045.6 39.63 SBE SEAL BORE EXTENSION 4.000 8,814.1 6,054.6 39.44 NIPPLE CAMCO D NIPPLE 2.750 GAS LIFT;7,463.68,823.6 6,061.9 39.29 SOS OTIS 2.992 GAS UFT;7,967.8 • Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f GAS LIFT;8,412.6 -. Top(ftKB) atm(ftKB) IRKS) (ftKB) Zone Date tI Type Corn 8,630.0 8,670.0 5,915.0 5,944.9 C-4,C-3,C-2, 7/11/1985 12.0 IPERF 5 1/2"Csg Gun,120 3B-11 deg.phasing 8,700.0 8,707.0 5,967.5 5,972.8 C-1,3B-11 7/11/1985 12.0 IPERF 5 1/2"Csg Gun,120 deg.phasing PDR;8.462.7 , 8,744.0 8,752.0 6,000.8 6,006.9 UNIT B,3B- 7/11/1985 12.0 IPERF 5 1/2"Csg Gun,120 PACKER;8.476.5 11 deg.phasing 8,868.0 8,918.0 6,096.4 6,135.7 A-4,A-3,36- 7/11/1985 4.0 IPERF 4"Csg Gun,90 deg. 11 phasing PRODUCTION;8,516.7 • • 8,936.0 8,946.0 6,150.0 6,157.9 A-2,3B-11 7/11/1985 4.0 IPERF 4"Csg Gun,90 deg. phasing 8,982.0 8,987.0 6,186.7 6,190.7 A-2,36-11 7/11/1985 - 4.0 IPERF 4"Csg Gun,90 deg. phasing PRODUCTION;8,590_6 Stimulations&Treatments Min Top Max Atm Depth Depth Top(TVD) Btm(TVD) (ftK8) (1tK8) (ftK8) (RKB) Type Date Corn IPERF;9,630.08,670.0C- SAND 8,752.0 5,915.0 5,944.9 FRAC 12/13/200 FRAC-119M#16/20 FRAC;8,830.01-.�- 2 8,630.0 8,752.0 5,967.5 5,972.8 FRAC 12/13/200 C-SAND FRAC-119M#16/20 FRAC;8,700.0 2 IPERF;8,700.08,707.0_ • 8,630.0 8,752.0 6,000.8 6,006.9 FRAC 12/13/200 C-SAND FRAC-119M#16/20 2 Mandrel Inserts (PERF;8.744.08,7520 St FRAC,8,7M.0� I of n Tap(TVD) Valve Latch Port Size TRO Run N Top 119(6) (91(13) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn at ? 2,302.3 1,959.7 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,262.0 5/23/2013 2 4,094.4 3,157.7 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,261.0 5/23/2013 PRODUCTION;8,774.0/ 3 5,325.0 3,935.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/22/2008 ■ 4 6,009.7 4,348.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,261.0 5/23/2013 NIPPLE;8,785.4 5 6,394.5 4,572.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/6/2002 III 6 6,962.1 4,902.0 CAMCO KBUG 1 GAS LIFT GLV BTM 0.188 1,288.0 5/23/2013 LOCATOR;8,79115 Ii" 7 7,463.6 5,190.2 CAMCO KBUG 1 GAS LIFT DMY None 0.000 0.0 4/10/1995 8 7,967.8 5,470.5 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,279.0 5/23/2013 PACKER;8,799.1 9 8,412.6 5,757.0 WFT MMG-2 11/2 GAS LIFT OV RK 0.250 0.0 10/9/2013 SSE;8,802.5 M. 1 8,516.7 5,831.4 CAMCO MMG-2 11/2 PROD DMY RK Flo 0.000 0.0 9/22/2010 Latch 1 8,590.6 5,885.6 CAMCO MMG2 1 12 PROD DMY RK Flo 0.000 0.0 10/2/2010 NIPPLE;8,814.1 _ 1 -Thor 111 Latch 1 8,774.6 6,024.4 CAMCO MMG2 11/2 PROD DMY RK 0.000 0.0 12/6/2002 soS;8,823.6 ti 2 Closed Notes:General&Safety End Date Annotation 7/7/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 pages) IPERF;8,868.08,918.0 I I IPERF;8,936.08,946.0- I I I I IPERF;8982.08,9870- I I PRODUCTION;24.0-9,215.0 1 i 2_C k' WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 & DATA LOGGED " ` 1424 iS Anchorage, Alaska 99501 ` ' ��•K BEND R Sha 01 ZL 0 0CC, RE: Production Profile: 3B-11 Run Date: 7/25/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3B-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21369-00 Production Profile Log 1 Color Log 50-029-21369-00 some PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. - _ Well History File Identifier Organization (do.el RESCAN [] Color items: O Grayscale items: [] Poor Quail [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ~ I NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [3 Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other ISl Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ Scanned (do.e) IIIIIIIIIIIII1[1111 PAGES: ~ l (at the time of scanning) SCANNED BY: BEVERLY ~ VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: Quality Checked (done) Rev 1 NOTScanned.wl3d WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Vii' f w. 1~ .. r .n RE: Production Profile: 3B-11 Run Date: 8/20/2010 August 27, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3B-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21369-00 Production Profile Log 1 Color Log 50-029-21369-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3535 ~ _ klinton. _~` k1 , S a~ `~~ l~ ~~~ Date: l ,;~~~~:~ Si ned: g . Conoc~hillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED ¡~UG 1 3 200í Alaska Oil & Gas Cons c........m· . . . ."" ISSlon Anchorage August 7,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 9950 I \<66~\\S SCANNED AUG 1 42007 Dear Mr. Maunder: 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 by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of20". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, 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 top-fill operation was completed on July 27,2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner August 5, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ;;;µ~ M~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/7/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na !:Ial 38-02 185-057 32" .4 bbls 20" 7/27/2007 4.2 8/5/2007 38-03 185-060 29' 5.2 bbls 20" 7/27/2007 4.2 8/5/2007 38-04 185-061 14' 2.5 bbls 20" 7/27/2007 4.2 8/5/2007 38-05 185-075 SF N/A SF 7/27/2007 1.7 8/5/2007 38-07 185-077 45' 6.1 bbls 20" 7/27/2007 6.8 8/5/2007 38-08 185-087 14' .5 bbls 20" 7/27/2007 2.5 8/5/2007 38-09 185-113 SF N/A SF 7/27/2007 1.7 8/5/2007 38-11 185-115 20' 2.9 bbls 20" 7/27/2007 5.1 8/5/2007 38-12 185-116 43' 7 bbls 20" 7/27/2007 3.4 8/5/2007 38-13 185-023 43' 5.9 bbls 20" 7/27/2007 11.9 8/5/2007 38-14 185-024 11 ' 8.9 bbls 20" 7/27/2007 5.1 8/5/2007 38-15 185-025 57' 9 bbls 20" 7/27/2007 7.6 8/5/2007 38-16 185-026 43' 6.8 bbls 20" 7/27/2007 7.6 8/5/2007 Conoco hillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 14, 2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3B-11 (185-115) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 3B-11. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Mooney Wells Team Leader CPAI Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _XX Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development_ X RKB 85 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 5134' FNL, 431' FEL, Sec. 16, T12N, R9E, UM (asp's 518601, 5991264) 3B-11 At top of productive interval 9. Permit number / approval number 1390' FSL, 1472' FEL, Sec. 22, T12N, R9E, UM "' J 185-115/ At effective depth 10. APl number ,~ 50-029-21369 - At total depth 11. Field / Pool 4190' FNL, 1262' FEL, Sec. 22, T12N, R9E, UM (asp's 523070, 5986941) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9235 feet Plugs (measured) sand plug @ 8838' true vertical 6393 feet Effective depth: measured 9033 feet Junk (measured) true vertical 6228 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 227 sx AS 1 110' 110' SUR. CASING 4195' 9-5/8" 1300 sx AS III & 370 sx Class G 4219' 3246' PROD. CASING 9191' 7" 700 sx Class G & 250 sx AS I 9215' 6374' Perforation depth: measured 8630' - 8670', 8700' - 8707', 8744' - 8752', 8868' - 8918', 8936' - 8946', 8982' - 8987' true vertical 5913' - 5943', 5965' - 5970', 5998' - 6004', 6094' - 6133', 6147' - 6155', 6184' - 6188' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 8824' MD. REC~ Packers & SSSV (type & measured depth) OTIS 'WO' @ 8799' MD; BAKER 'HB'@ 8477' MD; ,]/~N___ ~-~0 2003 CAMCO 'TRDP-1A' (LOCKED OUT ON 8/29/97) @ 1823' MD. 13. Stimulation or cement squeeze summary A~a$~(a DJ[ & intervals treated (measured) 8630' - 8670', 8700'- 8707', 8744' - 8752' Treatment description including volumes used and final pressure 119M# of 16/20 carbolite 14. Representative Daiiv Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 218 856 769 109 Subsequent to operation 483 960 1117 126 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~t ~ Title: Wells Team Leader Date M~chae/ Mooney ~ Jl"~ Prepared b~/ Sharon A//sup-Drake 263-4612 I-'t FI. SCANNED FEB 0 2003 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 3B-11 Event History 12/O6/O2 12/07/02 12/O8102 1 2/O81O2 12/09/02 12/11/02 TAG FILL @ 8889' RKB.REPLACE 1.5" CV @ 8775' RKB W/DV. PULL 1" VALVES @ 6395', 6010', & 5325' RKB. IN PROGRESS. [TAG, OPEN-CLOSE C SAND, GLV] PULLED GLV'S @ 2302' & 4094' RKB.SET DV'S @ 2302',4094',5325', 6010' & 6395' RKB.SET 2.75" A-2 PLUG @ 8814' RKB.PT TBG TO 2000 PSI, GOOD TEST. PULLED 1.5" DV @ 8413' RKB. [GLV, OPEN- CLOSE A SAND, PT TBG-CSG] PUMP 1200# OF 20/40 SAND IN 40# HEC GEL. FLUSHED WITH SW AND FREEZE PROTECTED TUBING WITH 20 BBLS OF DIESEL. [OTHER STIM] LOAD IA W/171 BBL SW W/53 BBL DSL CAP. SET DV @ 8413' RKB. TEST IA 3500 PSI & TBG 3000 PSI, GOOD. PULLED 2.75" A-2 PLUG @ 8814' RKB. TAGGED SAND PLUG @ 8838' RKB. PULL C SAND DVS @ 8591' & 8517' RKB. MEASURE BHP @ 8835' RKB: 2758 PSI. SET TRDP-1A FRAC SLEEVE @ 1823' RKB. [TAG, OPEN-CLOSE C SAND, PRESSURE DATA] DUMPED SLUGGITS TO 8837' RKB, PULLED & RERAN FRAC SLEEVE @ 1823' RKB [OTHER STIM, SSSV WORK] 12/13/O2 12/14/02 12/16/02 12/17/02 PUMPED C SAND FRAC. PLACED 119M# 16/20 CARBOLITE BEHIND PIPE, 10 PPA ON PERFS. SAW TSO -36 MINUTES INTO JOB, CUT SAND DUE TO RAPIDLY INCREASING PRESSURE AND LIMITED MAX ALLOWABLE TREATING PRESSURE. FLUSHED TO COMPLETION, LEFT 31 BBLS DIESEL IN WELLBORE FOR FREEZE PROTECTION PERFORMED A FCO TO 9099' CTMD. RETURNS 1-1+ ALL DAY. RIH WITH A 1 3/4" STANDARD FCO TOOL STRING AND A SWIRL JET NOZZLE. WASHED ALL MANDRELS ON THE WAY TO SURFACE. WELL FREEZE PROTECTED TO 4000' CTMD. TURN WELL OVER TO WIRELINE FOR GLVD. [FCO] PULLED FRAC SLEEVE @ 1823' RKB, TAGGED FILL @ 9033' RKB, SET CATCHER @ 8814' RKB, SET 1.5" HFCV'S @ 8517' & 8591' RKB, IN PROGRESS [SSSV WORK, TAG, OPEN-CLOSE C SAND] NEW GAS LIFT DESIGN @ 2302', 4094' & OV @ 5325' RKB, PULLED CATCHER @ 8814' RKB [GLV] SCANNED FEB 0 4 2003 Page I of I 1/13/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission. TO: Julie Heusser, Commissioner DATE: January 7, 2001 THRU: FROM: Tom Maunder, ~j~)q/)~~'/ P. I. Supervisor ~ J o~.," o \ Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3A & 3B Pads Sunday, January 7, 2001: I traveled to the Kuparuk River Field and witnessed the semi-annual safety valve system testing on 3A & 3B Pads. As the attached AOGCC Safety Valve System Test Reports indicate I Witnessed the testing of 8 wells and 16 components on 3A Pad and 6 wells and 12 components on 3B Pad with 1 failure observed. The surface safety valve on well 3A-08 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. John Arend conducted the testing today he demonstrated good test procedure and was a pleasure to work with The wellhouses on these two pads were very clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 3A & 3B Pads in the Kuparuk River Field. KRU 3A Pad, 8 wells, 16 components, KRU 3B Pad, 6 wells, 12 components, 19 wellhouse inspections 1 failure 0 failures Attachment: SVS KRU 3A Pad 1-7-01 CS SVS KRU 3B Pad 1-7-01 CS X Unclassified Confidential (Unclassified if doc. Removed) Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 3A Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3A-01 1851860 64 70 50 P P OIL 3A-03 1852060 3A-05 1852210 64 70 50 P P OIL 3A-08 1852240 64 70 60 P 4 OIL 3A-09 1811940 64 70 60 P P OIL 3A-12 1852390 64 70 60 P P OIL 3A-13 1852810 64 70 40 .P P OIL 3A-16 1852840 64 70 70 P P OIL 3A-17 1961320 3A-18 1961330 64 70 50 P P OIL Wells: 8 Remarks: Components: 16 Failures: 1 Failure Rate: 6.3% [] 90 Day Surface Safety Valve on well 3A-08 had a slow leak when tested, vzlve to be service retested by operator. 1/9/01 Page 1 of 1 SVS KRU 3A Pad 1-7-01 CS.xls ! , , Alaska Oil and Gas Conservation CommiSSion Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 3B Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date oil, WAa, GIN& Number Number PSI PSI Trip Code Code Code Passed GASorC¥CLt ! 3B-03 1850600 64 70 60 P P OIL 3B-04 1850610 64 70 50 P P OIL! 3B'06 1850760 64 70 50 P P OIL 3B-08 1850870' 3B-09 1851130 64 70' 70 P P OIL 3B-1i 1851150 64 70~ 50 P P OIL 3B-13 1850230 3B-14 1850240 Wells: 6 Components: 12 Failures: 0 Failure Rate: [39o Day Remarks: Good Test 1/9/01 Page 1 of 1 svS KRU 3B Pad 1-7-01 CS.xls STATE OF ALASKA AL, ...,cC& OIL AND GAS CONSERVATION COMMIb~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 142' FSL, 433' FEb Sec. 16, T12N, R9E, UM At top of productive interval 1390' FSL, 1472' FEL, Sec. 22, T12N, At effective depth 1137' FSL, 1284' FEL, Sec. 22, T12N, At total depth 1088' FSL, 1253' FEL, Sec. 22, T12N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 9235 feet true vertical 6391 feet 6. Datum elevation (DF or KB) RKB 86 7. Unit or Property name Kuparuk River Unit 8. Well number 3B-11 9. Permit number/approval number 85-115 10. APl number 5o-029-21369-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 91 3 0 feet Junk (measured) None true vertical 6305 feet ORIGIN AL feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 227 SX PFC 1 1 0' 1 1 0' Surface 41 89' 9-5/8" 1300 Sx AS III & 421 9' 3246' Intermediate 370 SX Class G Production 9191' 7" 700 Sx Class G & 921 5' 6374' Liner 250 SX AS I Perforation depth: measured 8630'-8670',8700'-8707',8744'-8752',8868'-891 8',8936'-8946',8982'-8987' true vertical 591 3'-5943',5965'-5970',5998'-6004',6094'-61 33',61 47'-6155',61 84'-61 88' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 8824' Packers and SSSV (type and measured depth) Pkr's: Otis RRH @ 8472' & Otis WD @ 8806'; SSSV: Camco TRDP-1A @ 1823' (Locked out) 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 9/19/97. Intervals treated (measured) 8868'-8918',8936'-8946',8982'-8987' Treatment description including volumes used and final pressure Pumped 177.9 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 5366 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 216 64 543 1188 157 Subsequent to operation 331 283 1150 1209 163 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I here/~rtify that the foregoing is true and correct to the best of my knowledge. / / Signed Title Wells Superintendent F o r ~_-4 ~ ~(~f,'6¢~5/88 ' ..~ --, Date //~/~- ~',,~ SUBIViCf' IN DUPL~C~'"~E ARCO Alaska, Inc. ' KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3B-11(W4-6)) WELL JOB SCOPE JOB NUMBER 3B-11 FRAC, FRAC SUPPORT 0828971734.8 DATE DAILY WORK UNIT NUMBER 09/1 9/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 (~) Yes O No (~) Yes O No DS-YOKUM JOHNS ESTIMATE KD1489 230DS36BL $1 26,044 $142,081 Initial TbCl Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer'~Cr~ I Final ~er Ann 1 292 PSI 2300 PSI 535 PSI 1 000 PSII 1400 PSI 400 PSI DALLY SUMMARY PUMPED 177,911 # OF UP TO 12 PPA 10/14 TO PERFS. LEFT 1200# IN PIPE. PUMPED 14,000# 20/40 , 153,000# 12/18 AND 12,111# 10/14. TIME 07:00 07:45 08:30 08:31 09:47 11:10 11 '56 12:02 12:45 12:54 13:01 LOG ENTRY MIRU DOWELL FRAC EQUIP. , LI'I-I'LE RED PUMP AND APC VAC. TRUCK. HELD SAFETY MEETING AND JOB PROCEDURE REVIEW. PRESSURE TEST TREATING LINE TO 9990 PSI. INITIAL WHP 1290 PSI. PUMP BREAKDOWN WITH 50# GEL, 25 BPM AT 7350 PSI TO 25 BPM AT 4920 PSI. PUMP 20/40 SCOUR STAGES 1 PPA AND 2 PPA WITH STRIGHT SEAWATER FLUSH AT 15 BPM AND SHUTDOWN FOR ISIP 1923 PSI. PUMP DATA FRAC AND FLUSH. 5 TO 15 BPM 4450 PSI. SHUTDOWN FOR CLOSURE CALCULATIONS. PUMP 540 BBLS PAD , 5 TO 15 BPM AND 4450 PSI. PUMP FLAT 2 PPA , 15 BPM 20/40 PROPPANT AND 4430 PSI. PUMP RAMP UP FROM 2 PPATO 10 PPAOF 12/18 PROPPANT, 15 BPM AND 5350 PSI. PUMP 10 PPA FLAT STAGE OF 12/18 AT 15 BPM AND 5375 PSI PUMP 10/14 FROM 10 TO 12 PPA, 15163# AT 15 BPM AND 5366 PSI. GO TO FLUSH WITH 76 BBLS OF FLUSH , LAST 20 BBLS WAS DIESEL. SHUTDOWN & RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $882.00 APC $7,200.00 $9,250.00 ARCO $340.00 $540.00 DOWELL $116,704.00 $119,704.00 HALL IB U RTO N $0.00 $7,445.00 LITTLE RED $1,800.00 $4,260.00 , TOTAL' FIELD ESTIMATE _ $126,044.00 $142,081.00 ADDENDUM ~ELL: 10/28/88 10/31/88 12/20/88 12/22/88 12/24/88 3B-11 RU S/L, tst lubr to 3000 psi; OK. RIH, pull dummy. Load tbg w/44 bbls diesel. Latch & pull dummy @ 8485' WLM. Bullhead 75 bbls, 10.7#/gal brine & 5 bbls diesel. RIH, set 1-1/2" dummy @ 8485'. POOH. RD S/L. RU Schl 5/8" fsh'g unit. Snub Schl unit off w/cat. Tst lubr. RIH, catch fsh @ 8730' WLM, pull and jar. Jar on fsh, wrk dn to shear GS tl, POOH, RD. Secure well. RU WL, RIH w/2.75" IB; tagged @ 8705' WLM. POOH; IB showed sand @ 8705' WLM. RIH w/2.25" OD bailer, tag up @ 8705' WLM, wrk bailer to 8774' WLM, POOH; rec'd sand. RIH w/latch tl, wrk to 8788' WLM, POH; no rec'y. RIH w/latch tl, push circl vlv to 8792' WLM, POH; rec'd circ vlv. Made 5 rns w/2.25" OD bailer; rec'd sand on all 5 rns. Never got below 8792' WLM. RIH w/2.25" blind box, tag @ 8792' I~M & att to shear out ball w/o success. POH w/blind box, RD WL. RU CTU & GIH to 8800', wsh to SOS @ 8824'. Att to pressure to 4000 psi; ball would not seat, POOH to 8500'. Allow ball to fall out of GLMs. Pressure to 4000 psi; OK. RIH, set on shear out sub w/CTU. Pressure to 4300 psi; would not shear. Wsh shear out sub while recip'g pipe. Stop circ, set on shear out sub w/CTU. Att to re-pressure; able to pmp in 1200 psi @ 1BPM. POOH to 8777'; pipe stuck. Wrk free, POOH 1000' & pressure tbg to 4000 psi; ball re-seated. RIH to shear out sub, set dn w/6000# tbg wt. Pressure tbg to 4200 psi; ball would not shear. Bleed pressure. Switch to cln diesel, POOH displ'g well w/cln diesel. RU Otis, tst lubr to 1300 psi. RIH, tag shear out sub @ 8823', POOH; clear impression of ball. GIH, beat dn on shear out sub w/2-1/8" stem w/spangs & 2" blind box, shear SOS. GIH, tag fill @ 8963' (" sand perfs @ 8868'-8987'), POOH. Secure well. Lower 24 "A" sand perfs covered w/fill. Drilling Supervisor Date STATE OF ALASKA . /'~, ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well GAS [] SUSPENDED ~ ABANDONED .:~ SERVICE [] Classification of Service Well 2 Name of Operator ARCO Alaska, Inc. 3. Address p_cl_ Rn× 1NN%F~N~ Anchnrag~ AK qq510-0360 4. Location of well at surface 142' FSL, 433' FEL, Sec.16, T12N, RgE, UH At Top Producing Interval 1390' FSL, 1472' FEL, Sec.22, T12N, RgE, UM At Total Depth 1088' FSL, 1253' FEL, Sec.22, T12N, RgE, UM 7. Permit Number 85-115 8. APl Number 50- 029-21369 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3B-11 11. Field and Pool Kuparuk River Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 86' RKB I ADL 25633 ALK 2566 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 06/18/85 I 06/24/85 06/27/85* 17. Total Depth (MD+TVD)/18.PlugBackDepth(MD+TVD) 19. Directional Survey t 20. Depth whereSSSV set 9235'MD/6391'TV[~ 9130'MD/6305'TVD YES ~ NO [] I 1823' feet MD Kuparuk River Oil Pool 15. Water Depth, if offshore 116' No. of Completions N/A feet MSLI 1 I21. Thickness of Permafrost 1600' (approx) . 22. Type Electric or Other Logs Run D IL/SFL/SP/GR~ FDC/CNL/Ca], CET/CR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 6" 9-5/8" 62,5# 36.0# 26.0# H-40 J -55 J -55 Surf Surf .~lrf 24. Perforations open to Production (MD+TVD of Top and interval, size and number) Perforated w/4 spf 8982' - 8987' MD/6184'-6188'TVD 8936 ' -8946 ' MD/6147 ' -6155 'TVD 8868 ' -8918 'MD/6094 ' -6133 'TVD Perforated w/1 2 spf 8744'-8752'MD/5998'-6004'TVD 8700 ' -8707 'MD/5965 ' -5970 'TVD 8630 ' -8670 'MD/5913 ' -5943 'TVD 110' b, 719' 9715' 1 ?-1/a" 8-1/2" 227 sx PFC !300 sx AS !!! & 370 s× ! lottom and 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8824' 8477' & 8799 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD)~AMOUNT& KIND OF MATERIAL USED See attached F~acture Stimulation Summary, dated 7/28/85,/for fracture data. 27. N/A PRODUCTION TEST Date First Production Date of Test Flow Tubing Press. Hours Tested Casing Pressure IMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FOR IoI L-BBL TESTPERIOD eI CALCULATED i~ I OIL-BBL 24-HOUR RATE "~ I GAS-MCF GAS-MCF WATER-BBL WATER-BBL CHOKE SIZE IGAS'OILRATIO OIL GRAVITY-AP (corr) 28. CORE DATA None * NOTE: Form 10-407 Fractured well 7/28/85. JAN 1 8 ~'.' ~asl~ l]il & Gas C0~s. ~mmiffion ,-,.. ~ch0rage Wor~over performed ~2/~9/88, ~'ut:):f_~; ~ & ~e]_Z perforated 7/12/85 Submit in duplicate ~/' CONTINUED ON REVERSE SIDE ~ ~ Rev. 7-1-80 WC5/071 GEOLOGIC MARKERS FORMATION TESTS , _ i _ 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 8G2G' 5910' N/A Base Upper Sand 8708' 5971' Top Lower Sand 8851 ' 6081 ' Base Lower Sand 9012' 5209' i 31. LIST OF ATTACHMENTS I Fracture Stimulation Summary (dated 7/28/85) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 " .... , ,% , (NO~E: ~omd co }mcov~r r~term Co ~1u~4-Volume Job co=ple~e a~ //3~ ., 7-2~-~ · '( T ~me ) STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate × Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 142' FSL, 433' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1390' FSL, 1472' FEL, Sec. 22, T12N, R9E, UM At effective depth 1137' FSL, 1284' FEL, Sec. 22, T12N, R9E, UM At total depth 1088' FSL, 1253' FEL~ Sec. 22~ T12N, R9E, UM 12. Present well condition summary Total Depth: measured 9 2 3 5' feet true vertical 6391 ' feet Plugs (measured) 6. Datum elevation (DF or KB) 85 RKB 7. Unit or Property name Kuparuk River Unit 8. Well number ,3B-11 9. Permit number/approval number 85-115/ 8-875 10. APl number 5~02~-21:~69 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 9 1 3 0' feet true vertical 6305' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8630'-8670', 5913'-5943', Length Size 100' 16" 41 95' 9 5/8" 9191' 7" measured 8700'-8707', 8744'-8752', true vertical 5965'-5970', 5998'-6004', Cemented Measured depth True vertical depth 227 Sx AS I 100' I 00' 1300 Sx AS III & 421 9' 3246' 370 Sx Class G 700 Sx Class G & 9 21 5' 6 3 7 4' 250 Sx AS I 8868'-8918', 8936'-8946', 8982'-8987" 6094'-6133', 6147'-6155', 6184'-6188" Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J-55 set @ 8808' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA @ 1807', Packers: Baker RH @ 8461' & Otis WD @ 8783" 13. Stimulation or cement squeeze summary Refracture A Sands RECEIVED Intervals treated (measured) 8868'-8918', 8936'-8946', 8982'-8987' Treatment description including volumes used and final pressure JAN Pumped 57MIb of 16/20 proppant. Final Pressure: 6400# ~?,., . ,, ., 14 Representative Daily Average Production or Injection D~t;::la~'~t 0~ (x ~a~ bUll~i. Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure"ul~U~Tal~hg Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1300 700 0 - 1200 115 1800 2000 0 - 1200 115 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Date /"'"1 ~ -.'~'~ / SUBMIT IN DUPLICATE APCO Alaska, Inc. Subsidiar/of Atlantic Richfield Company lARKS IFIELD- DISTRLC.T - STATE IOPERA~jN AT REPORT T/fME WELL SERVICE REPORT IDAYS iDATE I / / ~ OIL AND GAS CONSERVATION COI~ 'SION .... ~'~ '~i ~ ~ APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 142' FSL, 433' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1390' FSL, 1472' FEL, Sec. 22, T12N, R9E, UM At effective depth 1137' FSL, 1284' FEL, Sec.22, T12N, R9E, UM At total depth 1088' FSL, 1253' FEL, Sec. 22, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 85 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3B-11 9. Permit number 85-1 1 5/8-87,5 10. APl number 5o-029-21369 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth' measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 1 1 0' Surface 41 8 9' Intermediate Production 91 91 ' Liner Perforation depth: measured 9235' 6391' 9130' 6305 Size 16" 9 5/8" 7" feet feet feet feet Cement' 9130'-9235' Junk (measured) Fill @ 8969' Cemented Measured depth True 227 Sx AS I I 10' 1 1 0' 1300 Sx AS III & 421 9' 3246' 370 Sx Class G 700 Sx Class G 9215' 6374' 250 Sx AS I 8630'-8670', 8700'-8707', 8744'-8752', 8868'-8918', true vertical 5913'-5943', 5965'-5970', 5998'-6004', 6094'-6133' Tubing (size, grade, and measured depth 3-1/2" J-55 set at 8807' Packers and SSSV (type and measured depth) Baker RH @ 8461' and Otis WD @ 8783', Camco TRDP-1A-SSA @ 1807' 8936'-8946', 8982'-8987' , 6147'-6155', 6184'-6188' 13. Attachments Description summary of proposal _ Refracture stimulate the A sands. (Wellbore schematic 14. Estimated date for commencing operation August, 1990 16. If proposal was verbally approved Name of approver Date approved Detailed operation program X attached). BOP sketch 15. Status of well classification as: Oil X Gas __ Suspended Service oil production 17. I herfrl~y certify that t~ng is true and correct to the best of my knowledge. Signed . Title FOR COMMISSION USE ONLY Date ? '"/~ "?~) Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test Subs. equent joj~n__.require 10- -- Approvea Approved by the order of the Commission Form 10-403 Rev 05/03/89 JApproval N o.¢~) .,,~-,~( I Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT IN TRIPLICATE Kuparuk Well 3B-11 A Sand Refrac Procedure Cost Tracking AFE: # K81280 Pre-Frac 1. Obtain two 12 hour A sand only well tests. 2. Pull GLV's from 2286', 5309', 7448', 7952', and 8397' MD-RKB and run DV's @ same depths (leave the bottom mandrel open while displacing the 7" annulus with diesel). If a Petredat gauge is available, pull a DV from 8501' MD-RKB (top C sand GLM) and replace it with the pressure gauge for the C sand pressure measurement during the stimulation treatment. Estimate the time of the refrac as accurately as possible and Set the data sampling frequency to collect the pressure data in an one minute interval during the stimulation period (a 24 hour period bracketing the estimated stimulation time and in a five minute interval outside of the period). 3. Displace annulus with diesel. 4. Pressure test tubing. Fracture Treatment (using Quality Control: non-delayed gelled water) 1. Check all tanks for cleanliness and check proppant for fines. Insure water is uncontaminated. 2. Insure adequate amounts of proppant and water are on location for the frac. 3. Perform pre-frac quality control tests on gelled water using water which has been delivered to the drill site for the frac. Frac Job: 1. MIRU fracturing equipment. Install tree saver and pressure test all surface lines. , Pressure up 3-1/2" x 7" annulus to 3000 psi. Do not allow this pressure to exceed 3500 psi during fracture treatment. Maximum allowable wellhead treating pressures are shown below as a function of annulus pressure. annulus pressure (DSi~ *maximum WHTP (DSi~ 2500 5500 3000 6000 3500 6500 * Well 3B-11 has 3-1/2", 9.3 #/ft., L-55 tubing. Maximum WHTP's above are based 100% of the MYS of 3-1/2" L-55 tubing. . Pump 180 barrel gelled water breakdown stage, shut-down for ISIP, and check for excess friction. Cut the crosslink chemical towards the end of the breakdown stage (with the tubing volume remaining). Check tank straps against flow meter and correct flush volume as necessary. . Pump fracture treatment per attached schedule starting with a 500 barrel gelled water pad. The following three gelled water systems are acceptable for the refracture treatment: Halliburton' BoraGel Dowell: YF240D B.J. Titan: RXL , The expected treating pressure is 4000 psi based on the following: Fracture gradient = 0.71 psi/ft (6165' TVD) Tubing friction = 0.263 psi/ft (8807' MD) Fluid gradient = 0.435 psi/ft (6165' TVD) Estimated perf friction = 0 psi based on initial frac 6. If necessary, cut rate in I BPM increments down to 16 BPM during job to reduce WHTP. 7. Obtain representative fluid samples from the pad, slurry, and flush stages during the fracture treatment. 8. Bleed down annulus to 500 psi. Rig down fracturing equipment, Post-Frac Flowback , Establish baselines for comparisons by visually inspecting choke and performing NDT of erosion prone areas, immediately downstream of choke, the drain line, all elbows, and all tees that will be exposed to flowback fluids. Document these inspections on a Flowback Log. . Based on the NDT results on the choke and piping, replace as necessary after reviewing with Corrosion Engineering. At the foreman's discretion, Steps 3 through 5 may be skipped. . Inspect S-Riser and modify as recommended in Cowan/Jackson letter "Modified S-Riser Design Criteria for Post-Frac Flowbacks" dated February 6, 1990 if expected flowrate as determined by KOE, KFE, and Corrosion warrant, or if existing riser has eroded based on UT tests. 4. Install one thread-o-let on the riser (KFE to design proper location and size) to allow hook up of an erosion probe connected to the wellhead safety system. , Install an erosion probe that is tied into the wellhead safety system, If Well 3B-11 has a 3" x 3" choke, it should be replaced with a 4" x 3" choke if possible in order to avoid the increased frequency of monitoring flowback required on a well with a 3" x 3" choke. . Operations Engineer: Place samples taken during the fracture treatment in hot water bath at 150F to observe break time. After the design break time and after verifying that the gel has broken in the water bath, the Operations Engineer will contact the Production Foreman to initiate flowback. . Open well to tanks at a Iow flow rate, not to exceed 300 BLPD. On bottoms up, verify that the gel has broken. If excessive proppant or unbroken gel is present, SI well and contact A. Ramirez/G. Limb (x7525). Do not exceed 300 BLPD for the first 12 hours. After several bottoms up and as soon as clean returns are present with no noticeable gel or significant amounts of proppant, turn well into test separator. Set Iow flowrate alarm for 50 BLPD. Set high flowrate alarm on test separator for 600 BLPD for a 3" choke or 1100 BLPD for a 4" choke. , After the first 24 hours of flowback, decrease wellhead pressure in 50 psi increments at regular time intervals (minimum two hours) until the well is producing at header pressure. Limit the flowrate increase to no more than 750 BLPD every 24 hours. , Reset the high flowrate alarm to stay below erosional velocity as predicted by the table provided by Corrosion Engineering shown in step 10. Alarm settings should be based on the maximum flowrate for the average GLR from the first 24 hours of flow. If the GLR changes by more than 250 SCF/BBL, change the high flowrate as appropriate. Record rates, choke setting, and WHP's during the flowback period on the flowback log. 10. Inspect the choke internals visually and the erosion prone areas, downstream of the choke and the S-riser, twice during the first week and weekly thereafter until it is confirmed that an erosive condition does not exist. Maximum flowrates should be limited to those specified in the following table: Gas 4" Choke 3" Choke Liquid Maximum Maximum Ratio Flowrate Flowrate 300 3500 2000 500 2800 1600 1000 2000 1100 1500 1500 800 2000 1300 700 3000 1000 500 5000 700 400 11. Increase the flowrates outlined in the previous table only after a non-erosive condition is verified through inspection and confirmed by Corrosion Engineering. If erosion in the piping or choke body is identified, the well will be choked back to the previous non- erosive rate until some indication is obtained that the solids production has decreased and an assessment of the damage has been made. 1 2. Once the FTP has returned to normal line pressure, send all flowback logs and other pedinent information to A. Ramirez/G. Limb. Post-Frac Wireline 1. If a Petredat gauge was instlled, pull it and replace with a DV. Tag fill. 2. Install gas lift design. Check with the drill site engineer if a new design is necessary. 3. Obtain A sand only tests (the C sand will remain isolated as it has been). WELL 3B-11 GW FRAC DATA TABLE (BPM) I (BBL) I (POUNDS) PROPPANT (LBS)I (BBL) BREAKDOWN 20 180 0 0 180 SD FOR ISIP, PROVE FLOWMETER ICUMULATIVE I STAGE HITS DIRTY VOL (BBL)I PERFS~ (BBL) 180 78 PAD 20 500 0 0 500 680 258 SLURRY 2 PPG 20 18 1544 1544 20 4 PPG 20 34 5713 7257 40 6 PPG 20 47 11957 19214 60 8 PPG 20 59 19872 39086 80 10 PPG 20 42 17490 56576 60 12 PPG 20 26 13185 69761 40 FLUSH 20 76 0 69761 76 TOTAL 983 69761 1056 7OO 758 740 778 800 818 880 878 940 958 980 1018 1056 VOLUME TO PERFS (BBL) = 78.0 PROPPANT: 16/20M CARBOLITE or LWP THROUGH 10 PPG STAGE 12118M CARBOLITE in 12 PPG STAGE PUMP RATE = 20 BPM (Drop to 16 BPM if necessary in I BPM increment) Estimated Surface Treating Pressure = 4000 psi for non-delayed (suHace crosslinked) GW, including zero perf friction based on initial frac BREAKDOWN = GW + 40 LB/1000 GAL Silica Flour + 8 Hour Breaker Cut XL during last part (flush) of BD stage PAD = GW + 40 PPT Silica Flour + 8 Hour Breaker SLURRY = GW + 8 Hour Breaker (NO Silica Flour) CYC 7/6/90 KUPARUK WELL 3B-11 APl #: 500292136900 SPUD DATE: 06/18/85 ADL LEASE: 25633 COMPLETION DATE: 07/11/85 PERMIT #: WORKOVER DATE: 85-115 12/1 6/88 ORIGINAL RKB: SURFACE LOCATION: 142'FSL,433'FEL,SEC16,T12N,RgE TOP OF KUPARUK: 1390'FSL,1472'FEL, SEC22,T12N,RgE TD LOCATION: 1088'FSL, 1253'FEI~SEC22,T12N,RgE NI del:~hs are MD-RKB to top of equipment unless otherwise noted CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5# H~40 100 9.625' 36# J-55 4219 7" 26# J-55 9215 3.5' 9.3~ J-55 8808 SIZE LINER DETAILS WEIGHT GRADE TOP BTM TUBING JEWELRY TYPE ID DEPTH CAM CO TRDP-1A 2.81 ' 1807 BAKER 8447 BAKER HB 8461 OTIS WD 8783 CAMCO 'D 2.75' 8798 OTIS 8807 MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 57 HOLE ANGLE THRU KUP: 42 LAST TAG DATE: 04/29/90 RATHOLE: -18 FISH/OBSTRUCTION: deg deg DEPTH 8OO 7600 8969 ITEM sssv SBR PKR PKR NOGO SHROUT TUBING SPOOL: 24 WELLTYPE: PRODUCER PBTD: PBTDSS: 9130 6219 L ~:i:~:~:~:i:i:i:{:~:i:i:~:i:i:i:~:!:i:~:~:!:i:~:~:i:i:i:~:i:!:i:i: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .-.....,.....-.....,..,................-.........-..........,.,... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:+:~:.:.:.:-:.:.:.:-:.:.:.:.:.:.:.:. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .................~................................................. .......... i'l'l .................. "'' ~'rN 1 2 3 4 5 6 7 8 9 10 11 12 PAD ELEVATION: 55 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2286 CAMCO KBUG 1' 4078 CAMCO KBUG 1' 5309 CAMCO KBUG 1" 5994 CAMCO KBUG 1' 6379 CAMCO KBUG 1' 6946 CAMCO KBUG 1' 7448 CAMCO KBUG 1' 7952 CAMCO KBUG 1' 8397 CAMCO MMG-2 1.5' 8501 CAMCO MMG-2 1.5' 8575 CAMCO MMG-2 1.5' 8759 CAMCO MMG-2 1.5' PERFORATION DATA INTERVAL ZONE FT SPF PHASE 8630-8670 C3 40 12 120 8700-8707 C 1 7 12 120 8744-8752 B 8 12 120 8868-8918 A3,4 50 ' 4 90 8936-8946 A2 10 4 90 8982-8987 A2 5 4 90 REVISION DATE: 07/05/90 REASON: 4/90 Tag Fill PORT SIZE 0.188 .DV 0.188 .DV .DV .DV 0.188 0.25 0.25 .DV .DV .DV COMMENTS SWS 5.5" HJ II SWS 5.5" HJ II SWS 5.5" HJ II SWS 4' HJ II SWS 4" HJ II SWS 4" HJ II 1. 5000 PSI ?" WELLHr. AD CONNECTOR FLANGE 2. S000 PSI WIR£LINE RAMS (VAI~IABL[ SIZE) 3. 5000 PS1 4 1/6" L UBR~C, ATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-Orr BOP EGU!.PMENT ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk AT©-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F~08 3N-01 3N-14 3F-15 3F-15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Ku ~aurk Ku3aurk Ku2aurk Ku3aurk Ku2aurk Ku2aurk Ku )aruk Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Well Level Report I 2 Level Report I 2 Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level ,Report Level Report Level Report Level Report Level Report I 2 Level Report Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report -03-87 -18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 -04-87 2-O2-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-2O-89 2-21-89 2-21-89 2-2O-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' '~ /C/~oro~; c'u~,?,)iS$/o~ Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin~ Casin{ Casin~ 3 H-01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-1 7-89 Casing 1 E- 2 9 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M- 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron -.. '4/~ska Oil 4 ~;,,_~.,, ,, -' ~ STATE OF ALASKA AL/-,~XA OIL AND GAS CONSERVATION CO M M IS~,, ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate m Plugging __ Perforate Pull tubing I Alter casing m Repair well I Pull tubing ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Serv=.ce 4. Location of well at surface 142' FSL, 433' FEL, Sec.16, T12N, R9E, UM At top of productive interval 1390' FSL, 1472' FEL, Sec.22, T12N, R9E, UM At effective depth 1137' FSL, 1284' FEL, Sec.22, T12N, R9E, UM At total depth 1088' FSL, 1253' FEL, Sec.22, T12N, R9E, UM 12. Present well condition summary Total depth: measured true vedical 9235 'MD 6391 'TVD Effective depth: measured 9130 'MD true vertical 6305 'TVD feet feet feet feet Plugs (measured) None Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 110' 16" 41 89 ' 9-5/8" 9191 ' 7" measured 8630 ' -8670 ', 8936 ' -8946 ' , 5913'-5943' , true vertical 6147'-6155', Other_~_.~ Workover 6. Datum elevation (DF or KB) RKB 86 ' 7. Unitor Property name Kuparuk River Unit Tubing (size, grade, and measured depth) 3-1/2", J-55, tbg w/tail ~ 8824' Packers and SSSV (type and measured depth) Baker 'HB' (a 8477' & 'WD' pkr ~ 8799'~ & CAMCO 8. Well number 3B-11 9. Permit numbedapproval number 85-115/8-875 10. APl number 50-- 029-21:369 11. Field/Pool Kuparuk River Oil Pool Cemented Measured depth True vertical depth 227 sx PF "C" 1lO'MD 110'TVD 1300 sx AS III & 4219'MD 3246'TVD 370 sx Class G 700 sx C1 G & 9215'MD 6374'TVD 250 sx AS I 8700'-8707', 8744'-8752', 8868'-8918' 8982'-8987' 5965'-5970', 5998'-6004', 6094'-6133' 6184'-6188' 'TRDP-1A' SSSV ~ 1823' 13. Stimulation or cement squeeze summary I nt~t/~als treated (measured) Treatment description including volumes used and final pressure N/A RECEIVED Oil & Gas Cons, Com~_.~[o~ '": ~chomge Prior to well operation Subsequent to operation 14. 15. Attachments Copies of Logs and Surveys run · Daily Report of Well Operabons Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 16. Status of well classification as: Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Area Drillino Enoineer Tubing Pressure I Service I Date /,,,///,/~'~ feet Form 10-404 Rev 06/15/88 * Workover Well History (Dani) $W03/085 ! SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History- Initial Report - Daily Instructiona: Prepare and submit the "lnllilll Report" on the first Wednesday after a well is spudded or workover operations are star, ed. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County. parish or borough _n_~ ~T.~nW~ T~ NORTH ST.nP~, Field ILease or Unit I K[]PA Auth. or W.O. no. -~3 9 0 ! i _we P~OVER State 3R-ll Well no. Operator ~PT · 50-ngq-?l R~;q Spudded or W.O. begun Date ~nr,~p~ 1 I/2R/R~ Date and depth as el 8:00 a.m. 11/29/88 ( TD: 9235 PB: 9130 SUPV:TA 11/30/88 ( TD: 9235 PB: 9130 SUPV:TA 12/01/88 ( TD: 9235 PB: 9130 SUPV:CD 12/02/88 ( TD: 9235 PB: 9130 SUPV:CD 12/03/88 ( TD: 9235 PB: 9130 SUPV:CD 12/04/88 ( TD: 9235 PB: 9130 SUPV:CD 12/05/88 ( TD: 9235 PB: 9130 SUPV:CD Completerecordforeachdayrepo~ed ~nT~ I Hour ARCO w.I. DISPLACE WELL W 10.6 PPG MW:10.6 NACL/NA~R MIRU, ACCEPT RIG AT 2300 11/28/88, DISPLACE WELL W/ 10.7 PPG BRINE, OBSERVE WELL DAILY:S17,900 CUM:$17,900 ETD:S17,900 EFC:$740,000 RU SLICKLINE TO LOCKOUT S MW:10.6 NACL/NABR CIRC. & INCREASE BRINE WT F/ 10.3 TO 10.6, OBSERVE WELL, ND TREE, NU BOPE & TEST, PULL LANDING JT, LEFT FMC XO IN HGR, ATTEMPT TO PULL HGR, UNABLE TO STING OFF SBR, BAKERLOCK LANDING JT, SCREW INTO XO, PULL XO, PULL BPV DAILY:S27,910 CUM:$45,810 ETD:$45,810 EFC:$740,000 POH W/ TBG C/O COUPLINGS MW:10.6 NACL/NABR ATTEMPT TO LOCK OUT SSSV, NO SUCCESS, ND STACK, CONNECT CL TO TBG HGR, OPEN SSSV, RU E-LINE, RIH W/ CHEMICAL CUTTER, CUT TBG AT 8595' & 8431', POH, STUCK TOOL STRING AT 8418', PULL OUT OF ROPE SOCI<ET, RD E-LINE, POH W/ TBG AND CHANGEOUT COUPLINGS TO AB MOD DAILY:S64,756 CUM:$110,566 ETD:S110,566 EFC:$740,000 RIH W/ 3-1/2" TBG MW:10.6 NACL/NABR CONT. POH W/ TBG C/O COUPLINGS TO AB MOD, RU SLICKLINE, RIH W/ LIB, POH, RIH W/ OVERSHOT W/O GRAPPLE ON TBG DAILY:S31,378 CUM:$141,944 ETD:S141,944 EFC:$740,000 SLIP & CUT DRLG LINE MW:10.6 NACL/NABR CONT. RIH W/ TBG, TAG STUB @ 8434', CIRC. ONE VOLUME, RU SLICKLINE, FISH CHEM CUT, POH, RD SLICKLINE, POH W/ TBG, INSTALL WEAR BUSHING, RIH W/ OVERSHOT ON DP DAILY:S33,947 CUM:$175,891 ETD:$175,891 EFC:$740,000 RIH W/ OS ON DP MW:10.6 NACL/NABR CONT. RIH W/ OS ON DP, LATCH PKR @ 8428', JAR FREE, CIRC. GAS OUT, POH W/ PKR & SBR, RIH W/ OVERSHOT ON 3-1/2" TUBING DAILY:S27,923 CUM:$203,814 ETD:$203,814 EFC:$740,000 RIH W/ WASHPIPE ON DP MW:ll.0 NACL/NABR CONT. RIH W/ OS ON TBG, LATCH FISH, COULD NOT PULL, RU E-LINE, RIH W/ 2-5/8" CHEMICAL CUTTER, CUT TBG @8736', COULD NOT PULL, RIH CUT TBG @8600', POH W/ TBG, PU 180' WASHPIPE, RIM W/ WASHPIPE ON DP DAILY:S40,701 CUM:$244,515 ETD:$244,515 EFC:$740,000 The above i~,e~3rrect For form preparation ~ distribution~"~ see Procedures ~nu~l~Sec~mn 10, Drilling, Pages 86 and~7. AR3B-459-1-D Number ali daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company ~, Daily Well History--Interim Inslructions: This form is used during drilling or workover operations.. If testing, coring, Or perforating, show' formation name in describing work performed. Number aH drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final complehon Report oltJcial or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less lrequently than every 30 days, or (2) on Wednesday of the week Jn which oil string is set. Submit weekly for workovers and following setting of oil string until completion. ICounty or Parish IStateAK District ARCO ALASKA INC. I NORTH SLOPE I I ILease or Unit Field KUPARUK RIVER I 3B-11 I Well no. Date and depth as of 8:00 a.m. 12/06/88 ( TD: 9235 PB: 9130 SUPV:CD 12/07/88 ( TD: 9235 PB: 9130 SUPV:CD 12/08/88 ( TD: 9235 PB: 9130 SUPV:CD 12/09/88 ( TD: 9235 PB: 9130 SUPV:DS/TA 12/10/88 ( TD: 9235 PB: 9130 SUPV:DS/TA 12/11/88 ( TD: 9235 ?B: 9130 SUPV:DS/TA 12/12/88 ( TD: 9235 PB: 9130 SUPV:DS/TA Complet ...... d ~b~:~)h~y fhile drilling ..... k ..... in prog .... RIH W/ OS ON TBG MW:10.8 NACL/NABR CONT. RIH W/ WASH PIPE ON DP, WASH 8546' TO 8742', (TAGGED SAND @8661'), POH LD WASH PIPE, RIH W/ OS ON 3-1/2" TBG DAILY:S30,805 CUM:$275,320 ETD:S275,320 EFC:$740,000 CIRCULATE MW:10.8 NACL/NABR SERVICE RIG. CON TIH W/ OVERSHOT ON TBG. TAG & LATCH FISH AT 8606'. PULL FREE AT 4K OVER STG WT. CIRC. POOH W/ FISH. LD FISH. RECOVERED BLAST RINGS. MU BHA. TIH W/ WASH PIPE ON DP. TAG FISH AT 8741'. WASH TO GLM AT 8774'. CIRC BTMS UP. DAILY:S27,904 CUM:$303,224 ETD:S303,224 EFC:$740,000 POOH M'W:10.8 NACL/NABR CIRC HOLE CLEAN. POOH. LD WASHPIPE. WASHOVER SHOE HAD 2-1/2" X 7" PIECE MISSING F/ BTM. MU OS W/ 3.78" EXTENSION AND JARS AND RIH. TAG TOP OF 3-1/2" TBG AT 8733'. JAR ON FISH. FISH CAME FREE. POOH W/ FISH. DAILY:S27,912 CUM:$331,136 ETD:S331,136 EFC:$740,000 POH W/OS ON DP MW:10.7 NACL/NABR POH, LD TUBING STUB, RIH W/ OS DRESSED FOR WIRELINE TOOLS, WASH AND REAM TWO JOINTS TOF @ 8760'DPM, WORK OVER FISH, CBU, POH DAILY:S28,415 CUM:$359,551 ETD:S359,551 EFC:$740,000 CIRC. GAS OOH MW:10.8 NACL/NABR POH. RECOVERED 25' OF WIRELINE TOOLS, MU 6" MILL SHOE, RIH, TAG SAND @ 8773', WASH TO PKR @ 8793', MILL OVER PKR F/8793'-8796', PKR MOVED DOWN HOLE, WELL FLOWING, CBU, GAS WILL NOT BREAK OUT OF BRINE, CONT. CIRC. DAILY:S27,915 CUM:$387,466 ETD:S387,466 EFC:$740,000 CIRC. 11.4 BRINE @ 4800' MW:10.8 NACL/NABR CONT. CIRC. 10.8 PPG BRINE, SIDPP 200 PSI, CIRC. 11.1 PPG, SIDPP 110 PSI, CIRC 11.5 PPG BRINE, SIDPP 0 PSI, CIRC. 11.3+ BRINE, WELL FLOWING, CIRC. 11.4 PPG BRINE, WELL STABLE, POH, 105 STANDS OUT, WELL FLOWING, RIH TO 4800', CIRC. 11.4 PPG BRINE DAILY:S140,058 CUM:$527,524 ETD:S527,524 EFC:$740,000 POH W/ MILL ON DP MW:ll.6 NACL/NABR CIRC. 11.4 PPG BRINE, GET CRUDE RETURNS, CIRC. 11.5 PPG BRINE, RIH TO 8746', CIRC. 11.5 PPG BRINE, POH 24 STANDS, FILL 2.5 BBLS SHORT, CBU, POH 12 STANDS, FILL 2 BBLS SHORT, RIH TO 8746', CIRC. 11.6 PPG BRINE, POH DAILY:S84,279 CUM:$611,803 ETD:S611,803 EFC:$740,000 Drilling, gas 8 d~)- ' AR3B-459-2-B i Number all prepa~d for each ARCO Oil and Gas Company Daily Well History--Interim Instruclions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number alt drill stem tests sequentially. Altach description o! all cores. Work performed by Producing Section will be reported on "Interim11" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weakly for workovers and following setting of oil string until completion. District County or Parish State ARCO ALASKA INC. NORTH SLOPE Field ILease or Unit KUPARUK RIVER I 3B-11 ! Complete record for each day while drilling or workover in progress NORDIC 1 Date and deptl'l as of 8:00 a.m. 12/13/88 ( TD: 9235 PB: 9130 SUPV:DS/TA 12/14/88 ( TD: 9235 ?B: 9130 SUPV:DS/TA 12/15/88 ( TD: 9235 PB: 9130 SUPV:JH/IC 12/16/88 ( TD: 9235 PB: 9130 SUPV:JH/IC 12/17/88 ( TD: 9235 PB: 9130 SUPV:CD/IC 12/18/88 ( TD: 9235 PB: 9130 SUPV:CD/IC 12/19/88 ( TD: 9235 PB: 9130 SUPV:CD/IC JWeil no. RIH W/SPEAR ON DP MW:ll.6 NACL/NABR FIN POOH W/ BURN SHOE. RIH W/ OS. CBU. ATTEMPT TO LATCH FISH AT 8799'. WORK DOWN TO 8802'. UNABLE TO LATCH. POOH. LD OS. PU 4" SPEAR. RIH. DAILY:S89,137 CUM:$700,940 ETD:S700,940 EFC:$740,000 JARRING ON PERM PKR MW:ll.6 NACL/NABR CONT. RIH W/4" SPEAR, TAG PKR AT 8802', PUSH PKR TO 8811', WORK SPEAR INTO PKR, POH, NO RECOVERY, TEST BOPE, RIH W/ 4" SPEAR, TAG PKR AT 8811', PUSH TO 8900', WORK INTO PKR, JAR ON PKR, CBU, SPOT 25 BBL VISC PILL ON BTM, JAR ON PKR DAILY:$29r422 CUM:$730,362 ETD:S730,362 EFC:$740,000 POH LD DP MW:ll.6 NACL/NABR JARRED PKR FREE, POH W/ PKR, RIH W/ BURNING SHOE, WASHED F/ 8917'-9116', CBU, SPOT HI VIS PILL, RU TO POH LD DP DAILY:S63,056 CUM:$793,418 ETD:S793,418 EFC:$740,000 RU BELL NIPPLE MW:ll.6 NACL/NABR POH LD DP, RU E-LINE, RIM W/ GR/JB, RECOVERED DEBRIS AT 8863', PU AND RIH W/ PERM. PKR ASSEMBLY, SET PKR AT 8783' WLM, RD E-LINE, NU BELL NIPPLE DAILY:S91,001 CUM:$884,419 ETD:S884,419 EFC:$740,000 POH W/ OTIS RET. PKR MW:ll.6 NACL/NABR CONT. RIH W/ COMPLETION ASSEMBLY, ATTEMPT TO STAB INTO PERM PKR, RET PKR SET TO EARLY, POH W/ COMPLETION ASSEMBLY DAILY:S27,777 CUM:$912,196 ETD:S912,196 EFC:$740,000 RIH W/ SLICKLINE TO PULL MW:ll.6 NACL/NABR CONT. POH W/ COMPLETION ASSEMBLY, RIH W/ COMPLETION ASSEMBLY WITH BAKER PKR, STAB INTO PKR, ATTEMPT TO VERIFY POSITION, LEAKED OFF, RU SLICKLINE, RIH TO PULL ORIFICE VALVE. (CAMCO 'TRDP-1A' SSSV @ 1823', BAKER 'HB' PKR @ 8477', OTIS 'WD' PKR @ 8799', & TT @ 8824'.) DAILY:S121,554 CUM:$1,033,750 ETD:S1,033,750 EFC:$740,000 RIH W/ SLICKLINE MW:ll.6 NACL/NABR CONT. SLICKLINE, DROPPED 1-1/2" OV IN HOLE, DROPPED CUTTER BAR IN HOLE, SPACE OUT TBG, SET PKR & TEST TBG TO 2500 PSI, SHEAR PBR, TEST ANNULUS TO 2500 PSI, TEST SSSV TO 1000 PSI, ATTEMPT TO SHEAR OUT BALL, FAILED, ND BOPE, NU TREE, TEST TREE AND PACKOFF TO 5000 PSI, FISH W/ SLICKLINE DAILY:S32,709 CUM:$1,066,459 ETD:S1,066,459 EFC:$740,000 The a~g~is correct Sig n~_,~ ~ For form prep~"'~"~i~n '~nd distributio[~"~.~ see Procedurqs ~anual Section 10, ~ Drilling, Page~J~ and 8.7 AR3B-459-2-B JNumber all daily well history forms consecutively as they are prepared for each well. Page no. 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. "Finel 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 compJetion, report completion and representative ~est data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is aveilable. Accounting cost center code District ~:~,CO ~LASY,~, INC._ C°unty°r[%~(~[J~s'~H SLOPE Field KUPARUK RIVER Lease or ~E~r_..: 25633 3B-11 Iwe,,no. I Auth. or W.O..a/{3901 ITM WORKOVER I API: 50-029-21369 Stat~ Operator ARCO A.R.Co. V~5,6000 Spudded or W~J~[3~ Date 11/28/88 Date and depth Complete rec[i~r{~,t~e~,Chlday reported as of 8:00 a.m. 12/20/88 ( 2 TD: 9235 PB: 9130 SUPV:CD/IC Iotal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our 2300 ['{RS IPrior status if a w.o. I RIG RELEASED MW: 7.0 DIESEL CONT. FISH W/ SLICKLINE F/OV, PULL DV, SET NEW OV, ATTEMPT TO TEST TBG, NO SUCCESS, FISH OV #2, SET OV AT 8412', PRESSURE TEST TBG, DISPLACE WELL TO DIESEL, CHECK DY, SET BPV, RIG RELEASED AT 2400 ON 12-19-88 DAILY:S35,370 CUM:$1,101,829 ETD:S1,101,829 EFC:$740,000 Old TO Released rig Classifications (oil, gas, etc.) Producing method Potential test data New TD Date PB Depth Kind of rig Type completion (single, dual, etc.) Official reservo r name(s) Well no. Date Reservoir Producing Interval Oil or gasTest 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 AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Division ol AflantlcfllchfleldCompa~y ADDENDUM WELL: lo/28/88 10/31/88 3B-11 RU S/L, tst lubr to 3000 psi; OK. RIH, pull dummy. Load tbg w/44 bbls diesel. Latch & pull dummy @ 8485' WLM. Bullhead 75 bbls, lO.7#/gal brine & 5 bbls diesel. RIH, set 1-1/2" dummy @ 8485'. POOH. RD S/L. RU Schl 5/8" fsh'g unit. Snub Schl unit off w/cat. Tst lubr. RIH, catch fsh @ 8730' WLM, pull and jar. Jar on fsh, wrk dn to shear GS tl, POOH, RD. Secure well. DEC 1 9 i9,38 Drilling Supervisor T~L N0:907659~i~3 , , ~ . ~ ', ~ ! ,, I ' . . -, ~ ~~ ~' . . , _ . -'~. ~ ~ ~ . ~_. ~ - , ~~ ~ ~Cp , - d-~''.. ~ '" .~. ,. rag~,, , ~lon , . STATE OF ALASKA AL, .~KA OIL AND GAS CONSERVATION COMMIssiON APPLI TION FOR SUNDRY APPROVALS 3. Address P. O. Box 100360a Anchorac~.eI AK 4. Location of well at surface 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well Alter casing __ Repair well ~' Plugging __ Time extension Change approved program __ -- Pull tubing ~ Variance __ Perforate 2. Name of Operator J 5, Type of Well: 6. Datum elevation (DF or KB) Development Exploratory __ R 14 B Stratigraphic ~ 99510 0360 Service~ 142' FSL, 433' FEL, 5ec.16, T12N, RgE, UH At top of producbve interval 1390' FSL, 1472' FEL, 5ec.22, T12N, RgE, UN At effective depth 1137' FSL, 1284' FEL~ Sec.22, T12N, RgE, UN At total depth 1088' FSL, 1253' FEL, 5ec.22, T12N, R9E, UN 7. Unit or Property name Kuparuk River Unit 8. Well number 3B-11 9. Permit number feet R~-11% 10. APl number 50-- 029-21369 11. Field/Pool Kuparuk River 0il Pool 12. Present well condition summary Total depth: measured true vertical 9235 ' M D feet Plugs (measured) 6391 ' TVD feet Effective depth: measured 9130 ' H D feet Junk (measured) true vertical 6305 ' T V D feet Casing Length Size Cemented Measured depth Structural Conductor 11 0 ' 1 6" 227 S x P F "C" 110 ' M D Surface 4219' 9-5/8" 1300 sx AS II I & 4219'MD Intermediate 37 0 s x C 1 a s s G Production 9215' 7" 700 sx CS G & 9215'MD .., ' r.. 250 sx AS I [ JnVej Dmeasured 8630'-8670', 8700'-8707', 8744'-8752', 8868'-8918' 8936'-8946', 8982'-8987' NOV 2 I ¢.,~,,;;i: true vertical 5913'-5943', 5965'-5970', 5998'-6004', 6094'-6133' Oil & Gas Cons, Commissior~ 614 7, - 615 5,, 618 4, - 618 8, ....~'~-'--'-"-- -luL~t~j1~.J~i~(]~rade, and measured depth) ~ . . . 3-1/2", J-55, EUE 8rd, 9.3¢ tbg with tail e 8821'MD . /~.~/¢L/ Packers and SSSV (type and measured depth) Packers: OTIS RRH ~ 8472', OTIS WD ~ 8806' SSSV: Camco TRDP SSSV ~ 1920' True vertical depth llO'TVD 3246'TVD 6374'TVD 13. Attachments Description summary of proposal ¢' Detailed operations program __ BOP sketch v" 14. Estimated date for commencing operation ),,l.-/~ -,¢--~' 16. If proposal was verbally approved Name of approver Date approved 15, Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '¥'~,,~ ~,'~"~-t/ Title A r~,a r)~-il ling E.~ine, er Date t I,,/"~[/ / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness (JWB) SA3/0059JApproval No..(~, ~ ~ I Plug integrity ~ Mechanical Integrity Test BOP Test ~ Location clearance ~ Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Retu~ed Commissioner Date //%.~-¢~,~ '-'c"~")(~' SUBMIT IN TRIPLICATE Pre-Rig Operations 1. Kuparuk River Unit Well 3B-11 Preliminary Workover Procedure Load tubing and annulus with diesel. 2. Shut in well for seven days. 3. Obtain BHP. 4. Make chemical cuts above and below carbide blast rings. 5. Set BPV. Rig Operations 1. MIRU Nordic #1. 2. Kill well. Pump pills as necessary. 3. Nipple down tree. Nipple up BOPE and test. 4. Shear out of SBR. POH changing couplings to AB Mod. 5. Pickup drill pipe and packer releasing tool. Latch packer. o . o . 10. 11. 12. 13. POH. RIH and fish carbide blast rings and tubing stub/seal assembly. Attempt to fish wireline tools. Assuming wireline tools cannot be fished, mill over permanent packer. packer below bottom perforation. POH RIH with casing scraper and circulate bottoms up. RU E-Line. RIH with GR/JB to PBTD. RIH with permanent packer and set between "A" and "C" Sands. Run 3-1/2" selective single completion assembly. Secure well and release rig. Completion Fluid = Expected BHP = Anticipated Start = Push ANNULAR PREVENTER § PIPE RAI'IS 4 BLIND RAI'IS '5 TUBING HEAD 2 i ' I 1. 16' CONDUCTOR SWAGED TO 10-3/4' 2. 11'-3000 PSI STARTING HEAD 3. I 1'-3000 PSi X 7-1/16'-5000 PSI TUBING HEAD 4. 7-1/16' - $000 PS1 PIPE. RAHS 5. 7-1 / 16" - S000 PSi BLIND I~AI'IS 6. 7-1 / 16' - S000 PSi ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK ANO FILL ACCUHULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHt,K. ATOR plI:;I. ES,~LI~ IS 3000 PSI WITH 1500 PSI DOWNSTI:~EAH OF THE I~JLATOR. 3. 08SERVE TIHE, THEN CLOSE ALL UNITS SII'IULTAI~OUSLY ANO RECORD THE TII'IE AND PRESSURE REr'IAINII~ AFTER ALL UNITS ARE CLOSED WITH CHARGINI~ PUffll3 OFF. 4. I~CORD ON THE IADC REPORT.. TIE ACCEPTABLE L(:N/ER LII'IlT IS 45 SEC01~S CLOSII~3 TII"IE ~ 1200 PSI REI'IAINING PRESSUP. E. BOP STACK TEST 1. FILL BOP STACK Al,tO t'IANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCI3EWS ARE FULLY RETRACTED. PREDETERHINE DEPTH THAT TEST t3LUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-.DOWN $CREIw~ IN HEAD. CLOSE ANNULAR PI~EVENTER AND CHOKES AND BYPASS VALVES ON THE I'IANIFOLD. 4. TEST ALL C01"IPONENTS TO 250 PSi AND HOLD FOR 10 I"IlNUTES. S. INCREASE PRESSURE TO 1800 PSi AND HOLD FOP, 10 r'IINUTES, BLEED TO ZERO PSi. 6. OPEN ANNULAR PREVENTEI~ AND CLOSE PIPE RAHS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 HINUTES. 8. CLOSE VALVES 01RECTLY UPSTREAI'I OF CHOKES. BLEED D0WNSTREAH PRESSURE TO ZERO PSI TO TEST VALVES. TEST REHAINING UNTESTED I"IANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAH OF VALVE AND WITH ZERO PSI D(N/NSTREAI"I. BLEED SYSTEH TO ZERO PSI. 9. OPEN PIPE RAHS. 8ACKOFF I~UNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAr'IS AND TEST TO 3000 PSI FOR I0 I"IlNUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAI"IS AND RECOVER TEST PLUG. HAKE SURE HANIFOLO AN0 LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN TIlE 0RILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSi. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KCX)tIEY PUI"lP. 13. P, EC0f~ TEST INF013,HATION ON BLOWOUT PREVENTER TEST FORH. SIGN AND SEND TO DRILLING SUPERVISOI~. 14. I::)EPJ:013~ COI'lPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY 0PEI;b~,TE BOPE gAILY. de ,JULY 28, 1986 ARCO Alaska, Inc. Date: June 6, 1988 Transmittal #: 7178 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3B-1 1 Kuparuk Well Pressure Report 4 - 2 5 - 8 8 Static 'C' Sand If you have any questions, concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged' ~-~:-~--~~-~ DISTRIBUTION: ~ '~~~. {~, C .~.~ D & M State of Alaska Chevron Mobil SAPC Unocal ARCO Alaska, Inc, Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-17-85 TRANSMITTAL NO: 5354 RETURN TO: ARCO ALASKA, INC. KUPARUK OPEKATION~ ENGINLEfcING RECORDS CLERK ATO-1115B P.O. bOX 100360 ANCHORAGE, AK 99510 TR3kNSMITTED HERL~WITH ARE THE FOLLOWING ITEMS. RLCEIPT AND RETURN ONE SIGNED OPEN HOLE FINALS/ SCHL (ONE * OF EACH) 3B-12 ~""-5" DIL/5FL-GR ,------ 07-03-~5 RUN #1 ',.32" DIL/bFL-GR~--~' 07-03-85 RUN # 1 -. 5" DEN/NEU --- PORO 07-03-85 RUN · "~2" DEN/N;':U~-'-- PORO 07-03-85 RUN # 1 ~"5" DE N/N EU ~-'"~~~}~ 07-03-85 RUN #1 ~--'"---2" DEN/NEU -- RA~ 07-03-85 RUN ....... "~-- CYBEKLOOK -/ 07-03-85 RUN 3B-11 -'~ 5"-'- DIL/SFL-GR ~"--2" "- DIL/SFL-GR ..~ ~5" _ DEN/NEU · -"~'2"% DEN/N]~U ~ CYbE~OK 2Z-13 ~2,,z_ DZL/SFL-GR ~5" ~' DEN/NEU-GR ~5''/ DEN/NEU-GR ~2 '~ ~CYBE~OOK PORO PORO RAW PORO PORO RAW RAW PLLASE ACKNOWLEDGE COPY OF THIS TRANSMITTAL. 06-26-85 ttUN 06-26-85 RUN 06-26-~5 RUN 06-26-85 kgN 06-26-85 RUN #1 06-26-~ 5 RUN #1 06-26-85 RUN 07-0 5-~ 5 RUN #1 07-05-85 RUN #1 07-05-85 RUN #1 07-05-85 RUN #1 07-05-85 RUN ~1 07-05-85 RUN #1 07-05-85 RUN ~1 4030-8232 4030-8232 5600-8206 5600-8206 5600-8206 5600-8206 7500-8183 4213-9198 4213-9198 5800-9167 5800-9167 5800-9167 5800-9167 ~4U0-9143 4204-8502 4204-8502 4700-8476 4700-8476 4700-8476 4700-8476 7600-8453 3C-8 ~5"~'" DIL/SFL-GR "~2"'" DIL/SFL-GR ~5"'- DEN/NEU-GR '~2" DE N/N EU- GR x~5"-' DEN/NEU-GR 2" / DEN/NEU-GR ~CYt3ERLOOK PORO RAW RAW 07-23-85 RUN #2 07-23-85 RUN #2 07-22-85 RUN #2 07-22-85 RUN #2 07-22-85 RUN #2 07-22-~5 RUN ~2 07-23-85 RUN #2 RECEIPT ACKNO~LEDGED: BPAE ~. CUR~ILR CHEVRON D & M*BL DRILLING*BL L. JOHNSTON £~OBIL NSK CLEItK*DL DISTItl~UTION: ~. PAbH~:R ~XXON PHILLIPS OIL J. RATMMELL*SL DAT~: 5207-10024 5207-10024 5206-10031 5206-10031 5206-10031[~.' STAT~ OF ALASKA*BL SOHIO /S~ UNION K.TULIN/VAULT*FILM ARCO Alaska. Inc. Js a Subsidiary of At an cRJchfieldComr3any ARCO Alaska, Inc. Post Office Bux' 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-11 Dear Mr. Chatterton: Enclosed are copies of the 3B-11 Well Histories to include with the Well Completion Report, dated 8/12/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L69 Enclosures cc: 3B-11 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AtlanticRichfieldCompany Daily Well History-Initial Report Instructions: Prepare and submit the "Initial Rel~rl" 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. DistrictAlaska County or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. IT t e I AYE 604411 North Slope Borough ADL 25633 Drill State Alaska IWell no. 3B-11 Parker 141 API 50-029-21369 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate I Spudded Complete record for each day reported Date and depth as of 8:00 a.m. 6/19/85 6/20/85 6/21/85 6/22/85 thru 6/24/85 A.R.Co's W.I. Hour lPr or status if a W.O. I 6/18/85 1515 hrs. 56.24% 16" @ 100' 1700', (1600') Drlg Accept Rig @ 1200 hrs. 6/18/85. NU diverter sys. Spud well @ 1515 hrs, 6/18/85. Drl, Dyna Drill, & survey to 1700'. 439', .6°, N54E, 438.99 TVD, .44 VS, N1.35~, E1.86 800', 12.1°, S46.9E, 797.40 TVD, 35.05 VS, 16.63S, E32.44 1469', 36.2°, S45E, 1397.11TVD, 320.87 VS, 215.64S, E237.65 16" @ 100' 4238, (2538') Washing & Reaming Drl & survey f/1700'-1933'. TOH & PU new BHA, TIH & Drl & survey 1933'-4238'. C&C well, short trip to HWDP, TIH, wash & remg. 1657', 42.4°, ~43.5E, 1542.52 TVD, 439.74 VS, 301.07S, E32/.51 2139', 51.6°0, ~46.9E, 1862.88 TVD, 799.07 VS, 550.67S , E579.08 2651', 50.4? , ~49.0E, 2184.66 TVD, 1197.20 VS, 816.26S, E875.79 3656', 46.10, ~48.5E, 2857.29 TVD, 1943.47 VS, 1316.87S,E1429.38W 418~', 44.5~/~ I~1~.47.5E, 3232.63 TVD, 2320.45 VS, 1571.47S, 16" @ 100' 4238', (0') Drl'g Wt 8.6, PV 10, YP 10, PH 11.5, WL 11,8 Sol 2 C&C well, TOH, LD BHA, RU & rn 97 jts 9-5/8" 36# J-55 BTC csg. Shoe @ 4219', collar @ 4129' C&C well & cmt w/1300 sx AS III & 370 sx CL G. Displ & bump plug to 2000 psi; OK. ~ Floats held OK. Circ cmt. ND diverter. NU & tst BOPE. TIH, tst csg to 1500 psi. Start to DO. 9-5/8" @ 4219'L ~lq~/ 8032', ~"TBIH f/Wash Out Wt 9.4, PV 14, YP 15, PH 9.0, WL 6.8, Sol 8 Drl out of 9-5/8" csg to 4248'. Tst formation to 12.5 EMW; OK. Drl & srvy f/4238'-7235'. Drl & srvy f/7235'-8032', lost pmp pressure, TOH, found wash out, TIH. s,. 4E, us, -- 4722', 52.5°, S48E, 3579.33 TVD, 2725.66 VS, 1848.16S, 5903', 53.0°, S47.2E, 4296.11 TVD, 3663.89 VS, 2475.46S, 2701.35 6399', 54.7°, S47.SE, 4588.69 TVD, 4064.37 VS, 2746.80S, f~994-~9-2~¢ici~3.~i2 7018', 54.1°, S46.6E, 4950.53 TVD, 4566.58 VS,~'%O90.96S,M'2-26i~.66M'5d-I~oM 7523', 56.3°, S44.7E, 5240.08 TVD, 4979.90 VS, 3385.41S, 8031', 53.1°, S43.1E, 5526.78 TVD, 5398.69 VS, 3684.69S, E3945.75 Signature For torm preparalion a~d distribution, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. AR3B-459-1-B Drilling Superintendent Number all daily well history forms consecutively as they are prepared for each well. Pag no. e l ARCO Oil and Gas Company ~ Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drdl stem tests sequentially. Attach description of all cores. Work ~erformed by Producing Section will be reported on "Interim" sheets until final complehon. Report official ar representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough Lease or Unit Kuparuk River ADL 25633 Compiete record for each day while drilling or workover in progress 6/25/85 6/26/85 6/27/85 JState Alaska Well no. 3B-11 9-5/8" @ 4219' 9235', (0'), TOH Wt. 10.3, PV 14, YP 18, PH 8.0, WL 7.2, Sol 13 Drl f/8032'-9235', CBU. Made 20 std, short trip, C&C f/logs, TOH 8459', 44.3°, S38.6E, 5809.26 TVD, 5718.40 VS, S3927.91, E4156.06 8926', 37.8°, S36.2E, 6161.44 TVD, 6020.82 VS, S4171.55, E4342.33 9190', 31.9°, S30.8E, 6378.09 TVD, 6167.53 VS, S4297.35, E4425.59 \ 9-5/~" @ 42~9' 9235', (0') TOH to Rn Logs Wt 10.3, PV 11, YP 8, PH 8.5, WL 6.8, Sol 13 RU SCHL, TIH to log; would not pass 7640'. 9-5/8" @ 4219' 9235', (0') RN'G 7" CSG Wt 10.4~-PV 18, YP 11, PH 8.5, WL 6.8, Sol 14 POOH f/logs, RU Schl, log f/9235'-4219' w/DIL/SFL/SP/GR, & f/9235'-4250' w/FDC/CNL/CAL, RD Schl. Wsh & rem to btm, C&C hole. Spot pill, POOH. LD DP, TIH, RU, rn 7" J-55, 26# csg, 40 its. The above is correct Signature ~or ~o~m ~re~araH~ a~str~budo~ Drilling, Pages 86 and 87 AR3B-459-2-B Drilling Superintendent .':-~ ! ~-~' :,.~ .i~:;i:-i ~¢~b((:~ll .daily well history forms a'~ th~y'~f¢~t~ared for each well. consecutively JPg,~, no. .a Daily Well History-Final Report ARCO oil and Gas Company Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wail is Plugged, Abandoned. or Sold. "Final Reporl" should be submitted also when operations are Suspended for an indefinite or appreciable length of time. On workoYers when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" fort~ may be used for reporting the entire operation rf space rs avarlab}e. I Accounting cost center code District County or Parish State Al,-.q ,~k,..~ Alaska North Slope Borough Field Lease or Unit Well no. Kuparuk River ADL 25633 3B-11 Auth. or W.O. no. ~Tit e AFE 604411 I Drill Parker 141 AP1 50-029-21369 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m, 6/28/85 A.R.Co. W.I. 56.24% Date 6/18/85 Complete record for each day reposed Iotal number of wells (active or inactive} on this pst center prior to plugging and bandonment of this well our Prior status if a W.O, 1515 hrs. 7" @ 9215' 9215', (0') Final Report Fin rn 23 jts 7" 26# J-55 Butt csg, FS @ 9215', FC @ 9130'. C&C well & cmt w/60 bbl of Spacer 3000 & 700 sx CL "G" @ 15.8. Displ w/brine & bump plug w/3000 psi; flts OK. ND BOPE, set slips & cut csg. NU wellhead &tst pckoff to 3000 psi. RR @ 1800 hrs, 6-27-85. Old TD New TD PB Depth Released r~g Date Kind of rig 1800 hrs. 6/27/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual. etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potenhal test data Well no. Cate Reservoir Producing Interval Oil or gasTest 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 Signature~ ~ Date~/~~'~'' Title ,ir For form preparation a/nd distribution. see Procedures Manual. Section 10, Drilling. Pages 86 and 87. Drilling Superintendent AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for eacl~ well. Pag.~ no. Division of AllantJcRIchfieldCompany 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 ,f space is avadable. District Alaska ICounty or Parish Lease or Unit Title Accounting cost center code state Alaska Field North Slope Borough Kuparuk River ADL 25633 IWell no. 3B-11 Auth. or W.O. no. AFE 604411 Nordic 1 Completion AP1 50-029-21369 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete (W.t~,~ Dale and depth Complete record for each day reported as of 8:00 a,m. A.R.Co. W.I. 56.24% Date 7/11/85 7/11185 7/12/85 7/13/85 thru 7/15/85 Iotal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our j Prior status if a W.O. 0015 hrs. I Old TD Released rig 1200 hrs. Classifications (oil. gas. etc.) O±l Producing method Flowing Potential test data 7" @ 9215' 9215' PBTD, Perf'g Brine Accept rig @ 0015 hrs, 7/11/85. ND tree, 'NU & tst BOPE. RU WL, RIH w/4" csg guns, 4 SPF, 90° phasing. Perf f/8987'-8982' 8946'-8936' & 8918'-8868' 7" @ 9215' 9215' PBTD, Tst tree Brine RIH w/5½" csg gun, 12 SPF, 120° phasing. Perf 8752'-8744', 8707'-8700' & 8670'-8630'. RIH w/perm pkr & tailpipe assy. Set pkr @ 8784'~v~J'~IH w/3½" compl-string. Set top pkr @ 8466'. Shear SBR, lnd tbg. Tst pkr &tbg. Set BPV. ND BOPE, NU & tst tree. 7" @ 9215' 9215' PBTD, RR Brine NU & tst tree. Displ well to crude. Tst SSSV. Set BPV. RR @ 1200 hrs, 7/12/85. (NOTE: Rn total of 278 jts, 3~", 9.3#, J-55, EUE 8RD IPC tbg w/SSSV @ 1920', Retrv Pkr @ 8471', Perm Pkr @ 8806', "D" Nipple @ 8814', Tailpipe @ 8821'. (~5~t~inq Fr,~-a.~t~,'~nq~rvj-~) ~-. ¢5 New TD PB Depth 9215 ' PBTD Date Kind of rig 7 / 12/85 Rotary Type comdetion (single. dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oii on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and d stribution, ~,~, W. ,~.~o see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C 7/29/85 Title Drilling Superintendent C_~ ~ la,s they ~r~' pre~)ared for each ,well. consecutively no. j-",~'i/` ';F~F ''" Division of AtlanticRIchfleldCompany ARCO Alaska, Inc. Post Office B,-...-,00360 Anchorage, Alask~ 99510-0360 Telephone 907 276 1215 DATE: 09-10-85 TRANSMI?TAL NO: 5341 RETURN TO: ARCO ALASKA, INC. KUPARUK OPEKATIONb ENGINEERING irE' CO P, DS CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HER/~WITH ARE THE FOLLOWING ITLL~IS. PLEASE ACKNOWLEDGE RECEIPT AND RETUR/q ONE SIGNED COPY OF THIS TR3LNSMITTAL. CASED HOLE LOGS (FINALS): "~lQ-15 --~ 'CBL 6/12/85 8000-8745 "~ 1Q-I-- CCL & PERFORATING RECORD 4/16/85 ,J 2V-9 ~- COMPLETION KECOkD 4/25/85 7525- ~2H-15~ COHPLETION RECORD 4/13/85 6998- -"~2H-2--- CCL & PE~{FORATING t{ECORD 4/24/85 ~-~ 2H-14~ CCL & PERFORATING RECORD 4/23/85 ~'~2R-16--~ CCL & PERFORATING RECORD 4/19/85 PERFORATING RECORD 8/3/85 7800-8 PACKER SETTING RECORD 6/5/85 72 PACKER SETTING RECORD ~/15/85 6 COHPLETION RECORD 4/17/85 7434- PERFOkATING I<E CO RD S/5/85 8300- COMPLETION RECORD 4/27/85 8920- CET 7/5/85 6500-9100 7800 7438 000 90-7820 700-6950 7650 8550 9030 RECEIPT ACKNO%~LEDGED: DISTRIBUTION: BPAE DRILLING* ~. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON HOBIL PHILLIPS OIL D &.M NSK CLERK* J. RATHMELL UNION K. TULIN/VAULT ARCO Alaska, Inc Post Office',..ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLEJ~K ATO-1115B P.O. BOX 100360 ANCHOkAGE, AK 99510 ENGINEERING TRANSMITTED HEREWITH ARE RECEIPT AND RETU~q ONE SIGNED SEQUENCE OF EVENTS FROM WELL PRESSURE DATA ~1C-4'-' 07-23-85 '-~1C-5' 07-29-85 '~1C-5,-' 07-30-85 ~'~iC- 6 ~ 07-25-85 ~"~iC- 6 07-24-85 ~lD-8-' 07-30-85 --~lH-3- 07-30-85 ----1R-5 07-05-85 -"-'1~-6' 07-06-85 ---'lR-8 07-U~-85 ~ 1Y-10- 07-27-85 '~iY-11- 07-28-85 ~ 2A-2 .' 07-04-85 ~ 2B-13' 07-30-85 ~-2U-14' 06-30-85 ~ 2U-14-' 07-01-85 ~ 2U-15 07-08-85 ~ 2V-2 07-27-85 ~ 2V-2. 07-28-85 ~ 2W-7° 07-26-85 ~2W-7- 07-27-85 2X-15' 07-09-85 - 2X-15" 07-04-85 - 2Z-l- 07-05-85 ~2Z-6' 04-08-85 ~3B-7~ 06-27-85 - 3B-8~ 06-28-85 ~ 3B-8-~ 06-27-85 '~3B-9/' 07-18-85 3B-11 07-20-85 ' 3B-12' 07-21-85 3C-11-' 07-29-85 RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE COPY OF THIS TRANSMITTAL. SERVICE REPORTS STATIC BHP CAMCO PBU DRESSER ATLAS PBU DRESSER ATLAS STATIC BHP CAMCO STATIC BHP CAMCO STATIC BHP CAMCO STATIC BHP CAMCO ~HP & MISC. CAMCO BHP & MISC. CAMCO STATIC BHP & t,~ISC. CAMCO STATIC BHP CAMCO END OF PBU DRESSER ATLAS 'C' SAND STATIC BHP OTIS PRESSURE DATA OTIS 'A' SAND PBU OTIS 'A' SAND PBU OTIS PRESSURE TEST & MISC. OTIS 'A' SAND PBU OTIS 'A' SAND PBU OTIS 'A' SAND ONLY PBU OTIS 'A' SAND PBU OTIS FLO%~ING BHP & FLUID I.D. OTIS FLOWING BHP & TEMPERATURE OTIS BRP SURVEY & MISC. OTIS STATIC BHP CAMCO STATIC BHP & MISC. CAMCO STATIC BHP & MISC. OTIS BHP & MISC. CAMCO STATIC BHP & MISC. CAMCO BHP SURVEY & MISC. CAMCO STATIC BHP & MISC. CAMCO STATIC BHP & MISC ~~'~ DAT~s~ DISTRIBUTION: DRILLING W. PASHER STATE OF~'A~';~SKA* L. JOHNSTON EXXON SOHIO* MOBIL* PHILLIPS OIL* UNION* NSK CLERK J. RAT}iMELL* · K.TULIN/VAULT ARCO AIsska. Inc. is a Sdbsidiary of AtlanticRichfieldCompany ARCO Alaska. inc Post Office ~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5292 RETURiq TO: ARCO aLASKA, INC. KUPARU K OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING TRANSMITTED RECEIPT AND KUPARUK WELL lB-1. 05-3 lB-2- 05-3 ~lB-4. 05-1 HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. PRESSURE REPORT--ENVELQPE FACE DATA 0-~5 CAMCO ~3B-15 05-28-85 OTIS 0-85 CAMCO 3B-16- " 05-28-85 OTIS 6-85 CAMCO -'~ 3C-11o" 07-29-85 CAMCO - 1C-4 07-24-85 1C-6-" 07-25-85 ~ 1D-8-~ 07-30-85 --1H-3 07-30-85 ~' lQ-13'~' 06-24-85 "lQ-14-~ 06-23-85 "lQ- 15- 06-21-85 "lQ-16~" 06-21-85 1R- 5"- 07-05-85 1R-6 '-~ 07-06-85 · · ~'lR-7? 07-06-85 -1R-8' 07-08-85 ~'2A-2-' ' 07-04-85 ~-2W-7-- 07-26-85 ~p_v-3 07-11-85 -~2W- 15' 08-04-85 3B-1 06-14-85 3B-2~--' 06-14-85 -3B-3'r 06-28-~5 ~-3B-3' 06-15-85 --3B-4-- 06-15-85 -3B-5--" 06-26-85 - 3B-6- 06-26-85 ~-3B- 7- 06-28-85 3B-7 ~ 06-27-85 3B-8~ 06-28-85 --3B-9~ 07-18-85 ~3B- 10-' 07-20-85 -3B-11 -- 07-20-85 3B-12-.- 07-21-85 3B-13. 05-29-85 ~3B-14 05-29-85 RECEIPT ACKNOWLEDGED: CAMCO CAMCO CAMCO CA/~CO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS DRESSE~{ OTIS OTIS CAMCO OTIS CAMCO CAMCO CAMCO CAin]CO CAMCO CAMCO OTIS CAMCO C ~] C O CAMCO CAMCO OTIS OTIS BPAE* B. CURRIER CHEVRON* D & M* DISTRIBUTION: DRILLING W. PAShER L. JOHNSTON EXXON ~.XJB I L* PHILLIPS OIL* NSK CLERK J. RATHMELL* STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska Inc. ~s a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO~MISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State A/asia OiI and Gas C(mrervaL:on '" ' ' ~.O~SSIOE 300j Porcu~r,c Drive Receipt of the following material / which was transmitted via is hereby ackmowledged: ~UANTITY /f'~,/~ ~ z~2~_ DESCRIPTION t 1~. - ~ z-/~ ~:~631 - RECEIVED: DATED: Copy sent to sender YES ,,, NO _~ STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO~AISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 State of klaska . ~onscrvaacn Comm~ssio~ SO0] Poreuph~e Drive Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION -~- o a~=7 3 - ~- ~ £e ~ - o~ 6 ?~- o~z//o-- Copy sent YES to sender NO ~_ ARCO Alaska, Inc. August 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-11 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 3B-11. I have not yet received copies of the Well Histories. When I do, I will forward them to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRUIO/Lll5 Enclosures A',!CO AMsku, Inc, is u Subsiclialy nf AtlanticRichfieldCompany STATE Of ALASKA ALASKA ~,~-'AND GAS CONSERVATION CO¥~.MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, 1. Status of Well Classification of Service Well OIL [~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-115 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 0-29-21369 , , . 4. Location of well at surface 9. Unit or Lease Name 142' FSL, 433' FEL, 5ec.16, T12N, R9E, UM 1LCCCA. TION$1 Kuparuk River Unit 1390' FSL, 1472' FEL, Sec.22, T12N, R9E, UM i'Surr. ~..~.' 3B-11 At Total Depth IB, H.~[ 11. Field and Pool 1088' FSL, 1253' FEL, Sec.22, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oil Pool 86' RKBI ADL 25633 ALK 2566 ,. . 12. Date Spudded06/18/85 13' Date T'D' Reached06/24/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns06/27/85* N/A feet MSL 1 17. Tot'lDepth(MD+TVD) 18.PIugBackDepth(MD+TVD) 19. Directional Survey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 9235'MD,6391 'TVD 9130'MD,6305'TVD YES []X NO [] 1905 feet MD 1600' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, FDC/CNL/Cal , CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 227 sx PF "C" 9-5/8'" 36.0# J-55 Surf 4219' 12-1/4" 1300 sx AS III & 370 s~ Class G 7" 26.0# J-55 Surf 9215' 8-1/2" 700 sx Class G & 250 s: AS - 24. Perforations open to Production (~D+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8982' - 8987' 3-1/2" 8821' 84&6' & 879R' 8936' - 8946' w/4 spf 8868' - 8918' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8744' - 8752' N/A 8700' - 8707' w/12 spf 8630' - 8670' 27. N/A PRODUCTION TEST I ' Date First Production Method of Operation (Flowing, gas lift, etc.) . ,. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD e , . 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 iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alaska Form 10-407 * NOTE: Tubing was run and the well perforated 7/12/85. TEMP/WC80 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. - ,. Top Upper Sand 8626' 5910' N/A Base Upper Sand 8708' 5971' . Top Lower Sand 8851' 6081' Base Lower Sand 9012' 6209' 31. LIST OF ATTACHMENTS Cyro.~r. npir. Survey (? ~o,ni~.s) . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~ ~ J<~~L~ Title Associate... Engineer Date ~.~~ /2, /~..~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) fordepth-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". SUB. SURFACE DIRECTIONAL SURVEY [~UIDANCE I~]ONTINUOUS I~OOL ComPanY , Well Name Field/Location ATLANTIC RICHFIELD COMPANY ! 3B-11 {1,42' FSL~ ,433' FE.L, S16, T12N. RgE. UMS_ K,UPAR_UK, NORTH SLO~)E~ ALASK~ , Job Reference No. 70666 Loooed By; RECEIVED Date ~ 'i ~' t~ 22-JULY-1985 Computed B~ Alaska Oil & Gas Cons. Cc, rnm!~sio~ ~, ~ ~ ~., .~,.~,~ B0~ GCT DI~CTTO~tA~, SURVFY CU$?OmEP, l,I ST TNC, FO:~ ~RCO ALASKA, INC, lB- 1 1. KIIPARUK I~!OPTH ~Lf'IPF,.:,AhASKA SURVEY [)ATE; 6 dUI, 85 FSGINEE~: T URAM ;~gThnt,)S r]F COMPUTATiOi'~ TOOL bCCA"I'IO.~;; TA~,GEi'~TIAL- averaged deviation and azimuth ~ ,NTERi'OLA'I' I 0~; [,i~'JEAR A~CCl ~ba, L~KA~ THC. 3R-11 fl~R'T'H ,.S[,~JP~i, Cfl?IPl. ITAT10~ L)~'.IJP]: 22-JUL-R5 DATE OF SURVEY: 6 JUL 85 KEbbY BUSHING EGEVATION: ENGINELR: T URAM INTERPOLATED VAT,OFS FDP, EVEH 100 FEET OF MEASURED DEPTH VFRTI(,AI. VERTICAL DEVIATIr~N AZI";UTH DEPTH DEPTH DEG Hlra L)FC; M'l'f~, O,O0 0,00 -86,00 0 0 ~! 0 a F l~tn,n~,; lO0,O0 14,00 0 6 S 3,~ 59 W ?OO.OL, 200.t)P !14.00 0 18 ',~ 79 3% F 3On. AU 3Ou.OA 214,00 0 2P ~ Ak( 3~ F 400,00 3q9.gq tl~,q9 0 24 ~ 72 16 F 500.00 49q,90 413.99 1 2 ,q 7256 F PO0 e0 7n'7.i5 7]~.15 t3 15 S 47 ~3 F 9,)~:n() 8q3..i4 R07,44 17 33 S 46 7 ~ PAGE 86,00 FT lnO0,oO 9~'7.a2 o01.,~2 21 15 11On,mu lU79.73 993.73 24 55 19on,Au 1)69,05 1083 05 2B lg Il(Jo O0 ]255.'11 116q:71 312~ 1400:00 13~9 02 1953,62 34 22 lSO0.O0 1~20:13 1334.73 37 27 1AO0,O0 149~,u2 1412 62 40 2 1700.OU ~572.21 1486,~1 4418 1~00,0() ~ 642.()7 1556.07 471~ lgO0.O0 ~ 70~. 3..9 162~,19 ~938 VERTTCAI. DOGDF. G RECTANGULAR COORDINATES HORZZ, DEPARTURE SF. CTi~,( SEVERITY NORTH/SOU?H EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DE(; MIN 2non nO 1.771 80 1685,g0 51 2toh' : . ,OO !. 83,; (,)6 j. 74fl,Ob 2200.0~) 1895', 65 1~09,65 51 2400.0O ~0~0.11 lqJ4,11 51 4 2500.00 20~3'0q 1g97,09 5() 46 260~,0~ ~14~.46 206~,46 5036 2700.00 2210.21 2124.21 50 53 21~8 53 49 42 2800 O0 2274, 2900'0U. 2339,~ 2253,48 49 5 O.O0 O,UO O,O0 N 0,!4 0,59 0,07 S 0.47 O,j4 0.26 S n.72 0.1~ 0.05 S 1.01 026 0,19 N !,82 2:22 0,17 N 6,3~ 3,U3 2,42 S 1R.37 4,54 9,86 S 37,95 4,5q 22.77 S 64,83 3,06 41.34 S 3000.00 2405 3~ 2319.38 48 46 3100.n0 2471~4R 2385,~8 4~ 21 3200,00 2538.25 2452.25 4756 3300,00 3400 O0 ~673,4 3500 nO ~741,7~ 2655,72 ]600 O0 7810.41 2724,41 4620 370~ OU 2879,'1~ 2793,71 4b 1. 3800 O0 ~9~9,40 2P6~,40 4539 3900,00 30.9,~31 2033,43 ~525 4553 F 97.81 4b 13 F ]37.14 40 11 ~ 182,06 45 32 ~ 231'91. 45 15 F 286,25 45 42 F 344'71 4.5 4~ E 407.]9 45 23 ~ 475,03 45 28 ~ 546,54 ,17 38 E 621,53 S 48 24 E 698.6'1 $ 48 12 F' 776 90 S ,18 6 F 85567 $ 48 0 F q34 23 $ 48 14 ~ 1012 19 a 4~ 37 ~ 1089 84 S 48 56 E 1!67.16 ..~49 0 E 1244.16 S a9 7 ~ 132067 g 48 4R ~ 1396165 $ 4~ 7 F '1471.84 $ 48 g E 1546,87 S 48 25 E 1621.29 S '18 25 ~ 1695,2g R 48 ]3 E 1768,65 S 4827 E 1841.6§ S 48 25 F lq14,31 $ 48 17 F 1086,38 ~ 48 18 g 205R.08 S 48 18 F 2~29,46 0,00 0,13 0,40 0,94 1,56 264 646 15 92 10 66 50 09 0 O0 N 0 0 g 0 0 0 1 2 6 18 38 64 14 S 62 3¢ E 48 $ 56 51 g 94 $ 86 41 g 57 N 83 8 g 65 N 86 24 E 90 S 69 27 g 73 $ 58 14 S 53 23 5 S 50 27 g 4 28 3 10 2 91 2 51 ] 19 4 14 2 61 ] 32 3 03 64 91 122 157 195 23~ 280 327 377 429 S 102 57 S 134 30 S 170 56 S 209 51S 250 28 S 295 68 S 343 92 S 394 75 S 449 73 89 E 15 E 137 65 E 18~ 41 E 23 0'3 ~ 286 78 E 344 67 E 407 95 E 475 88 E 546 09 F 621 97 87 $ 49 1 E 17 $ 48 7 E 08 $ 47 41 E 91 $ 4'~ 17 g 25 8 46 54 g 72 $ 4640 g 40 S 46 31 E 05 S 46 23 E 58 $ 46 15 E 58 $ 46 15 E 0,75 0~47 0,60 0 78 0 27 0 82 0 3! 0 4~ 0,64 1,72 481 07 $ 506 70 E 698 70 $ 46 29 g 533 14 S 565 12 E 77b 9] $ 46 40 E 585 b38 690 741 792 843 893 94.:] 69 S 6~3 27 S 682 32 S 740 89 $ 798 79 S 856 36 S 914 53 S 972 35 S 1030 %E 855 ~ 934 25 E 1012 35 E 1089 60 E 1167 73 E 1244 57 E 1320 O0 E 139& 67 $ 4648 E 23 S 4654 E 19 S 4659 E 85 S 47 5 g 7 S 47 12 E 8 $ 47 19 ' 71 S 47 25 ~ 71 $ 47 ~0 E 027 0 45 1043 0 21 1092 0 73 1142 0 JO 1 1 02 1287 0 38 133 0 10 138~ 0 24 1430 993 31 S 1086 23 E 1471 92 $ 47 33 E 10 E 1546 96 $ 47 35 E 40 $ 1142 91 S 1197 07 $ 1253 67 S 1308 03 S 1362 28 S 1417 S 1524 44 S 1577 70 g 1621 03 E 1695 02 E 1768 76 E 1841 10 E 1914 97 E 1986 49 E 2058 78 E 2129 40 S 4737 g 41 S 4739 E 79 S 4741 E 82 $ 4743 g 49 $ 4744 E 58 $ 4746 E 29 S 4747 E 68 S 4748 E C('~,,'IP[)'fAT1F~FiOAT~: 22-J01,-85 PAGE 2 DATE OF SUPVE¥I 6 JUL 85 ~LbY BUSHING EbEVATIONI g6,00 FT ENGINEERI T URAH !4KAS~IRFi') VFRTlrA[, VF~TIC.AL DEVIA?IPt~ VEP, TTCAL nOCUFG R~CTANGU[,AR CDORDZNATE$ HORIZ, DEPARTURE ~]CT].OI~,, SEVEPI~Y N~RTH/SOUTH EAST/~EST DIST, AZIMUTH FF'E~ DEG/100 FEET FEET FEET DEG HZN ~ n£)n, n (..) 30~9,d4 3OU3,Bzt 45 41,jrt, nt;. '~ ~ ~,0 .'/n 3N74.70 44 40 42on,no ~231,g7 3145,g7 44 26 4~(~.O0 ~302.92 3216.g2 45 4600.~0 ~ ~'t o 7 20 341~,~0 53 4700,00 ]657:07 ¢a7~ ,02 52 50 48o0.c, 0 3o17, 13 3551,73 52 400n,e~) 307~,,~3 3592,43 52 39 5non,no 373~.80 3652 RO 52 59 51on,no '.~ 7':~8 ,. 8 o 37i?:99 53 2 5700, oi~ 3859,01 3773' O1 53 4 5~0o,nt) t919.04 3933,~4 K3 q 5400 n~ 3979,t0 3~93,10 52 5~ 55{)n~ n0 4039,7~ 3O53.78 ~2 27 56U0, nt) 4].nO, 5~ 4o14,5~ 52 35 5700 O0 4161,26 4075 26 52 43 5¢~on. aU .a2R1.53 419~,53 53 15 6000 t)(.) 4341,19 4255,19 6100'nO 44n().26 4314,9.6 53 50 6200:00 445R.'1~ 4372,7! ~4 26 6300.O0 4516,~3 g430,6.] 54 42 6400,00 4574,1~ 44~,14 6500,~0 46~1.0g 4545,08 55 7 670d~n0 4'147.U~ 4&bl' .... , 68Un,n0 48o5,00 471a,69 ~00,00 4854.20 477P,~0 54 7000.n,) 49?2,.,,9 4R36,49 54 7100,00 49~0.71 4~94.71 54 22 7900.n0 $036,73 4052,73 S4 7300,00 5096,03 5nl, O,d3 55 7400.o0 5~52.70 5066,70 55 37 7~00.no 5208.67 512~,67 56 76t)n.n0 5263.30 5~77,30 ~7 7700.0u 5316.7~ 5230.75 q7 31 7800.nO 5371.2q 5~g.~9 5~ 6 7aoo.no 54~fl.3~ 534~.3B K4 22 S 48 6 ~ S 48 q E 3038,47 $ 48 9 ~ 311~,36 $ 48 2 F 31.98.33 S 47 44 ~ ]278 27 S ~5 24 ~ J357~74 $ 45 2] ~ 3437.10 ~ 45 33 F 3516 56 S 45 34 E $ 45 35 F 3676,31 S 45 39 F 3756.K4 S 45 36 F 3837,21 S 45 37 E 3999,82 $ 45 3q E 4.081.6:1, S 45 3q K ¢~2~.70 S 45 5 E 4326.67 ~ ~4 55 F 9407,63 S 44 4~ ~ ~488,67 S 44 bO F' 4569,87 e 45 O E 465~ .~2 S 4~ 44 F.: ~732,51 · g 4~ 42 F 4814,40 ~ 44 51 E ~ 45 O E 4970 55 S 45 35 E 5003 2B 5 45 4~ E 5147 ~ 4b 3R F 52,31.56 ~ a5 6 ~ 5313.63 0,23 0,33 0,39 2,42 2,~7 2,67 i.u7 0 84 3i24 0 27 0,26 0,25 0,27 0,52 1.03 0,93 O,i3 0,38 0,17 0 52 0 29 0 33 0 24 0 5O 1,79 0,15 0,27 0,85 0 39 0 88 0 99 o 3!. 0 82 111 1 40 0 58 1 83 1 38 1477,60 S 1030 86 E 2200 68 $ 47 49 g 1524,57 S 1683 51 E 2271 24 $ 47 50 E 1571 55 $ 1735 1618i67 S 1788 1667 45 S 1842 1718 21 $ 1899 1'17.0 77 S 1958 1824 31 5 2017 1877 83 S 2076 1931 02 S 2135 60 E 234i O0 E 2411 62 E 2485 40 .E 2561 26 E 2640 89 E 2720 62 E 2799 66 E 2879 39 $ 47 50 E 85 $ 47 50 E 08 S 47 51 g 24 $ 47 52 E 15 $ 47 52 E 29 S 4'/ 53 75 S 47 52 22 S 47 52 E !.984 35 S 2194 91. E 2958 93 S 47 53 E 2037 70 8 2254 44 E 3038 87 $ 47 53 g 2090 99 S 231] 2144 40 $ 2373 2197 90 $ 2432 2252,57 $ 2490 2308,40 S 2547 2364,13 $ 2603 2419 94 $ 2660 2475:95 $ 2717 98 E 3118 51 E 3198 93 E 3278 61 g 3358 06 E 3437 74 E 3516 72 E 3596 89 E 3676 77 S 47 53 E 75 $ 47 54 E 71 $ 47 54 g 16 $ 47 52 E 47 S 47 48 g 89 S 47 45 E 60 $ 47 42 E 58 S 47 40 E 2532 08 $ 2775 25 E 3756 78 S 47 37 E 2588 47 S 2832 97 E 3837 43 S 47 34 E 2645 2702 2759 2816 2874 2931 2988 3045 26 S 2890 31S 2949 52 $ 3007 94 S 3066 13 S 3125 08 S 3182 38 S 3239 82 S 3297 93 E 3918 14 E 3999 63 E 4081 44 E 4163 11E 4245 72 E 4326 98 E 4407 22 E 4488 52 S 47 32 E 99 $ 47 30 E 76 S 47 27 g 92 S 47 25 E 81 $ 47 23 E 77 S 47 21 ~," 71 S 47 18 ,. 73 $ 47 16 E 3103 46 $ 3354 49 E 4569 91 S 47 13 E 3160 97 S 3411 97 E 4651 15 S 47 11 E 53 $ 47 8 g 321.8 76 $ 3469 35 E 4732 3276 97 $ 3527 05 E 4814 3335 51, S 3585 02 E 4806 3394 09 S 3643 64 E 4979 3452 89 $ 3703 29 E 5063 3512 02 $ 3763 68 E 5147 3570:49 S 3823 72 E 523~ 3628,17 $ 3882,14 E 531 42 S 47 6 g 73 S 47 3 E 55 S 47 1 E 28 S 47 0 E 77 S 46 '58 E 56 S 46 57 E 63 $ 46 56 g Cflr4PUTATILgN D~TE: 22-J[JL-85 DATE OF SURVE¥~ 6 JUL 85 KELbY BUSHING EbEVATIONI ENGINEER: T URAM PAGE 86,00'FT 1NTFRPOLATED val,ut~S ?'Ot{ EVI-.iN 10o FEF, T OF ~EASURF..D DEPTH TP~? ,q L; n,- S l<~, ',fEa$11Rw(~ v~;hT1CA~. VERTICAb DEVIATIOn'.,~ AT_I~UTh D~DTH D~]PTH DEPTH DEG MTi,I OEG V£R'fTCAL DO~LEG RECTANGUb~R CDORDINATE$ HORIZ, DEPARTURE SECTION TEVEPlTY NORTH/SOUTH EAST/WEST DZST. AZIMUTH FEET [)EG/loO FEET FEET FEET DEG ~IN 9000.00 ~;!9b.~t6 0t17,1~6 3b 16 9100 nO 62~0 43 6194 43 35 2 9o00' ' , . ,. .00 63~2.30 ~2'/6,3u ~5 ~ 9~35,00 ~390,96 03l)~,~6 35 2 S 4,t 2o lC. 5;194.11 $ 43 3fl [< 5473,1~ S 41 31 F 562~.57 $ ~0 3 ~i 5699,15 S ..~H 3] W ~707.g4 ~ 3o 51 ~ $ 3b 32 ~ bgO0.O1 S ~b 37 ~ 596~ ~4 S 36 13 E 0025:43 $ 33 52 ~ ~084.99 S 35 7 F ~141..65 S ]5 7 F 61.97,95 S 35 7 E 5217,52 1,27 1,70 1,90 2,~5 2,49 t,5~ 0,90 2,0~ 1,37 2,85 0,00 0,00 0,00 3685.33 S 3938 88 E 5394 11 $ 46 54 E 3742 29 S 3993 88 E 5473 19 $ 46 51 E ~7n8 86 S 4046 3855 O0 S 4097 3910 27 $ 4144 3964 75 $ 4189 4018 39 S 4230 407! 70 $ 4270 4~3,74 S 4309 4~74,24 $ 4346 74 ~ 5550 07 E 5625 82 F 5698 44 £ 5768 91 ~ 5835 28 E 5900 0~ E 5964 14 E 6026 45 $ '46 48 E 57 S 46 44 E 2~ S 46 40 E 07 $ 46 34 E 07 S 46 28 ~' 35 $ 46 21 ,5 46 15 ~ 04 $ 46 9 E 4223,23 S 4381 88 £ 6085,77 $ 46 3 ~ 4270,42 S 441.5 33 g 6142,61. ~ 45 57 E 4317,38 S 4448 38 E 6199,02 S 45 51 E 4333,82 S 4459 94 E 6218,77 S 45 49 E APCO ,¢bt~.bKA, T?~C. 3~-.! 1 DATE OF SURVEY: 6 JUL 85 KELbY BUSHING £bEVAT]ON: ENGINEER: T URAM 86,00'FT INTFRPOLATEn l~AI.tJE,5 ["OK t~Vk:r' 1000 FEET OF i'iEASURED DEPT MS~;jIIRFL) YFt<TICA{., V~]P~TICiL OEVI~TInN AT1MU'UH DEP'.r M DW. PTit D~PTH DEG Ml~i DFC, VER'I'TC,~I, DOGbEG RF. CTANGULAR C~]ORDINATES HORIZ, DEPARI'IlRE 5EC~I~ SEVERITY NORtH/SOUTH E~ST/WES~ DXST, AZIMUTH F~ET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -86,00 0 n lOO0.0o 9q7,87 m01,82 21 15 2000.nO 1771.~0 1.6~5.80 51 6 3000,~9 ~405.39 2319,38 48 46 4o0o.o{) ~u~9.~4 3003,84 45 5 50O~.~O ~7~8.~o 3659.80 52 59 bA¢)O,O0 4541.1q q755,19 53 35 7000.00 a9~2.4~) 4836,49 54 1~ ~000.~.3 5487.o4 540~,64 53 0 9OUn.00 ~19~,86 Oll~,Bb 36 16 f! 0 O F 0,O0 ~ 45 5~ F 97,8!. S s8 24 ~ 698,67 S 4~ 7 E 14'11.84 S 4~i 24 F 270n,4.4 S a~ ~ F 2~5~,56 S 45 39 F 3756.54 ~ ~4 50 E 4569.87 $ ~ 20 F 5394 11 S ]5 5~ F 608~:89 0,00 0.00 N 4,2~ 64,18 S 0.75 481,07 S 0:23 147,,60 S 0,26 19~4,35 S 0,52 253~:08 S 0,39 310 46 S 1.27 368~:33 $ 2,85 42? 23 S 0 O0 N 0 0 E 0,00 E 73,89 E 97 506 70 E 698 1086 23 E 1471 1630 86 E 2200 2194 91 ~ ~958 2775 25 E 3756 ~354 49 E 4569 3938 88 E 5394 4381 88 E 6085 87' $ 49 1 E 70 $ 46 29 E 92 S 47 33 E 68 $ 47 49 E 93 $ 47 53 E 78 S 47 37 F 91 $ 47 13 1 ! S 46 54 ,_. 77 ~ 46 3 g 9235.00 6390.96 6304,06 35 2 $ 35 7 F b?17,52 0,00 4333,82 S 4459,94 E 6218,77 S 45 49 E ARC~ /~;..,~$~,-.'.%, TNC.. DATE:. 22-JUL-85 PAGE DATE OF SURVE¥~ 6 JUL 85 KEL4Y BUSHING EbEYATIUN: ENGINEER; T DRAM IN'I'FRPfI[,ATED VAI,UF$ [;'DM EVENT 1gO FEET OF SUB-SEA DEPTH ~*L:aSIJR~;) VI::t,~mICAI. VERTICAL DEVIATiO!~ A~IIV~i..lTt-i Pl=PTU [)FPT~t nEPTH DEG NTN t)FG 14Ti,~ 8b,O0 FT 1106.el lOq6,0n lOUO.nO 75 O 1~.'{5.72 !286 O0 120o,Ao 32 31 1466,70 13gb~O0 1390,00 35 5a 1710 ~1 ~596 O0 15uO'O0 44 49 2029 ~0 ~ 786.00 1700,00 ~1 15 21S4:33 1~.00 l~O0.O0 ~2 VI~:RTTC~L, DOC. bEG EEC?ANGULAR COORDINATES HORIZ, DEPARTURE 5~3CTION SEVERITY NORTH/SOUTH E~ST/WEBT DISTs AZIMUTH F~ET DEG/IO0 FEET FEET FEET DEG MIN O,Oi) 0,0~ 0,00 n,14 0,59 0,05 0.42 0,60 0,27 n,~8 0,19 0.09 0.97 0,09 0,~6 1.62 1,2~ 0,22 5,30 ~,43 1,7~ ~6,33 4,50 8,57 35.41 4,06 21,05 62,44 3,14 39,69 97,10 4,28 140,0~ 3 77 191,23 3:17 250,82 3,06 319,87 3,42 396.80 3,68 488,~4 2,70 595 72 2,9] 716:]2 0,64 84~,32 0,31 0,00 0,14 E 0,33 0,85 1.46 E 2 4~ E 5 61 E 1.4 33 E 28 7g E 48 37 E 0 O0 N 0 0 E 0 0 0 1 2 5 35 62 5 S 68 59 E 2 S 50 24 E 86 S 84 12 £ 4'; N 83 57 E 43 N 84 51 E 88 S 72 36 E 70 $ 59 7 66 S 53 49 57 s 50 37 ~ 63,69 S 93,56 $ 104 128,91 $ 141 170.58 S 183 218 45 $ 232 272 89 S 288 337 18 S 353 412 18 S 430 492 79 S 519 577 45 S 6~4 73 38 E 24 £ 140 27 £ 191 89 E 250 29 £ 318 09 £ 396 57 E 488 18 E 595 90 E 71,6 61 E 843 97 16 $ 49 2 E 06 S 48 5 E 25 S 47 37 E 82 $ 47 9 E 87 S 46 45 E 81 S 46 33 E 57 S 46 21E 77 S 46 {3 E 34 S 46 32 E 32 S 46 47 E 2~5 61 1986.0¢) lqOO.no SI 2662,.11 21~b,O0 210o,00 50 2o 2~17 72 ~2qb.o0 2~00,00 49 36 2~70:58 ~386.00 2300,n0 ~8 4d 3121.83 249b.00 240n NO 48 15 3771.10 ~SgO,ur) 2~OO~nO 47 3~ 341~,~0 ~b~6,L)O 260n,OO 46 50 3~)4 q3 ~'/~o,u(t 27uO,a{, 4~ 34 3709:0b 268b,O0 2~00,00 45 50 ]852 34 29gO,On 2gO0,O0 45 33 3q94:g6 3(.;R~,~)O 3noo.no 45 6 41.3~,~5 3196,00 3100,00 44 34 42'15,~8 32au,O0 3200,00 45 4422.69 33q6,00 3300,00 48 53 4581"~1 348b,00 3400,00 4747.85 15~L;,OO 3500,00 92 4g12,49 ~6,00 3600,00 52 507~.~b ~7Pe,O0 3700,00 53 4 5244,08 38~b.00 3gun. O0 53 7 $ 48 Ia F i093.40 $ d9 ~ E 1334.17 S a~ 13 F 144~.72 S 48 1~ F' 1563,16 S 48 21 W 167],~6 $ 4~ j4 F 178~,15 S 48 23 F 1888,59 S d.b 1.6 K 199~,91 S 48 16 E 2095,49 $ 48 24 F 21.96 59 S 4'I 58 K 2295:95 S ~8 5 F 2394. i39 $ 4~ 17 K 2624,09 S 47 32 E 2758.01 S 47 56 F 2889 79 $ 4.~ 8 F 302~:35 S 4~ 6 ~: 3~54,34 0 40 0 77 0 56 0 39 0 39 0 58 0 36 0 26 0:39 0.60 0 14 0 46 2 20 2 52 2 16 0 48 0 37 0 26 0 34 b62 08 $ 708 68 E 969 83 S 46 5b E 744 824 902 978 1.054 112'1 1199 1270 1339 24 S 801 26 S 802 36 S 982 55 S 1069 27 S 1154 90 $ 1237 61 S 1318 20 $ 1397 53 S 1475 02 K 1093 76 £ 1215 79 ~ 1334 74 g 1449 24 E i563 08 ~ J674 15 E 1782 85 K 1888 84 E 1993 41 S 47 6 E 08 $ 47 17 E 21 S 47 26 E 79 S 47 32. 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V~DI'TC~L DEVTATIO~ A?i~i.ITM P~PTH D~PTH nEP'I'H DEG klr~ DFG MTN VflPTTCAL OOGbEG RFCTANGUbAN COORDINATES HORIZ, DEPARTURE 6EcTInN SEVERITY NORTH/SOUTH EAST/WEST DI$~, AZZMUTH FEE~ DEC/lOO FEET FEET FEE~ DEG MIN 5411 ,46 39~b,UO 3°Oo,O0 52 54 55TS.q9 4o~u.00 4noo,o0 52 33 5740 a4 41R6 O0 4100,00 52 b~ 5q07~4'/ 4295~00 %?00,00 53 16 5075 77 4390,0n 4~00.00 53 53 6247:05 44~b,00 4400,00 54 36 642fl.69 4596 (.)0 450n,00 55 14 67~6 3~ ,~'1~6,00 4700,00 54 q 6037:a5 48~,00 4800,00 5~ 23 '7100.n5 49R6,00 ~oOO,OO 54 22 7282,39 50~6,00 500n,O0 55 14 7450,33 ql~O on 5100,nO 56 2 7642,~5 5296:00 52u0,00 57 43 7826,25 ~3~6100 5~00,00 55 37 7997.76 5486,00 5400,~0 53 2 U150, ~5 5580,00 55(.)0, C)O 5,;3 33 8312,30 50~6,00 56(.)0. O0 47 3n 8594.01 58~b,00 5R00,00 42 ~ 8727,35 59~o.00 5000.00 40 45 8~57,47 60R6,00 600n,O0 3S 41 ~4,OO 61?6,On blO0,OU )6 42 923~,00 ~3q0,96 b304,o(i 35 ? 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DATE OF SURVEY: 6 dub B5 KELLY RUSHING EbEVATIONI ENGINEMR; T URAM PAGE 8$,O0'FT P,L:T L)~,'! Kb Pt451 , Or`` °01 2, 0235. O0 SURFACE hOCATION O~TGIi~= 142' ¢S1~. 433' FEb, SEC ~6 T12N ~gE, UM mVP RECTANGUhAR C60RD~N~T~,,8 FPON: K~ SI~R-SE~ NORTH/SOUTH EAST/WEST 5nog,C2 5q71,3~ 0390.96 ~8R5 38 5994 96 6122 55 6218 99 6304 96 403~.31 S 4241.25 4075,91 $ 4~73,41 4149,68 S 4328.,3 4228.97 S 4386.02 4284.51 S 4425.~5 4333.82 $ 4459~94 3F~-1! NInR'TH SLL)DE,A!,AS~A PA'IF,: 22'JUL-H5 PAGE {)ATE OF SURVEY: 6 JUL 85 KELLY BUSHING ~VATIUN: ENGINeeR) T URAM 'l' n p P "1' r~ ~AR~FR ". PDLsR I, U w F, R ,~At,C, 0012o00 qi30,Ot~ 023b,OO C~ TG1 'CVD 500q.g2 5 5~71,38 5 ~?0P,55 6 b304.99 6 142' 8R5~8 994.96 ~22o55 218 9q SURFACE LOCATION 433' FEb, SEC ~ 2N CO R~'OT1 , R9E, RFCTANGULAR DINATES NORTH/SOUTH EAST/WEST 4032 4075 4149 4228 42~4 4333 31 $ 42 91S 42~'25 68 ~ 43 '13 97 S 43~'02 ~ 51 $ 44 "25 .94 UM l"l ~,t A P ~- p '£ H ~I'DUE VF~TICAI., DF:PTH 6~90,qb SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY . 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SCALED IN VERTICAl. 0EI:'THS HORIZ SCALE = 1/2000 IN/FT WELL: SURFACE LO~gzz~~ i42' FSL, 433' FEL, S16, T12N, R9E, OM 1000 -lO00 -2000 -9000 -4OOO -~000 HORIZONTAL PROJECTION SCALE = I/'1000 IN/FT .SOUTH-~000 -2000 NEST -I000 0 1000 2000 3000 4000 SO00 GO00 EAST Suggested form to be inserted in each "Active" well folder to check _ _ for timely compliance with our regulations. OP~TOR, WEL~N~IE A~D ~UM~ER Reports and Materials to be received by: Date Required Date Received Remarks Samples Co~e ~.scr~t~o~ . , V Registered Survey Plat Drill Stem Test Reports :~~.,~~._ ~'~~~ ~- .... tog ~un ./~ - - Digitized Data ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-0 8-8 5 TRANSHITTAL NO: 5285 ~ETURN TO: ARCO ALASKA, INC.. KUPARUK OPERATIONS ENGINEEkING ~ECOt%D~ CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 2RANSMITTED HEREWITH ARE ~ECEIPT AND RETURN ONE S BOX 1 OF 2: 3PEN ~OLE LIS TAPES PL THE FOLLOWING IT~/~S. IGNED COPY OF 3C-11 06-23.-85 RUN 3C-10 '" 07-02-85 RUN 3C-9~- 07-10-85 RUN ~C-7~ 07-31-85 RUN 3B-14 - 03-20-85 RUN 3B-12-- 07-03-85 RUN 3B-11~ 06-26-85 RUN 3B-10 ~ 06-17-85 RUN 3 B- 9--~ 06-10-85 RUN 2Z-15" 06-19-85 RUN 2Z-14/ 06-28-85 RUN !Z-13~ 07-05-85 RUN 2Z-12-- ~7-20-85 RUN IZ-11~ 07-27-85 }{UN ~ ACKNOWLEDGE THIS TRANSMITTAL. US LIS%'INGS (ONE COPY OF ~1 4427.5-8881.5 REF ~1 1785.0-8987.5 ~1 3920.0-8332.5 REF #1 4617.5-8747.5 REF #2 3280.0-6803.5 RI-:F ~1 4021.5-8261.5 REF #1 2190.5-9257.0 REF #1 3273.0-727~.5 KEF #1 2092.0-8415.0 REF #1 2658.0-6620.0 REF #1 3876.0-8334.0 REF #1 4180.0-8538.5 REF #1 4409 . 0-9412.5 KEF #1 3531.5-7534.0 EACH) #70597 #70620 #70642 #70706 #70229 #70641 #70598 #70555 #70634 #70562 #70600 #70639 #70661 #70704 [N DOX 2 OF 2: )P-~HOLE LIS TAPES PLUS ~w-16~/ 01-28-85 RUN # ~V-14/~ 05-16-85 ~V-12u/' 04-22-85 U-10~ 04-11-85 .U-7~,f 03-1.9-85 a-13/~ 07-16-85 .K-13'/ 07-27-85 .R-12/'' 07-20-85 _i{- 11'~-' 07-13-85 _R-10~''~ 07-06-~ 5 .R-9'~./ 06-28-85 R-7/~ 06-04-~b ~UN ~ }tUN # ~ON # t~UN # ~U~ ~ RUN ~ RUN ~ RUN ~ RUN ~ RUN ~ LISTINGS (ONE COPY OF 3116.0-7038.5 REF 3047.0-7086.5 REF 3960.0-9265.0 REF 2972.0-7063.0 KEF 3594.5-8179 . 5 REF 7649.5-8160.0 3940.0-8578.0 REF 3935.0-8277.5 KEF 3810.0-7213.5 RIfF 2991.0-8738.0 REF 3991.5-8131.0 REF l&3 0045.5-7103.0 kEF EACH) ~ 70436---REVISED # 7 U 614---REVISED #70613---REVISED ~ # 70612---kEVISED -- # 70505---R~:ViSED -- #70645 #70702 #70660 #70643 #70640 #70601 #70509 ECEIPT ACKNOWLEDGED: PAE · CURRIER iEVRON & M D~<I LLING L. JOHNSTON MOBIL NSK CLERK DISTiCIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL DATE: ~i.o;;.:- ~_~' ~. -2:.~ Cons. Commission STATE OF ALASKA*~'~ SOHIO UNION K. TULIN/VAULT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: 92501 RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION ~ ~' / ,~ ~ RECEIVED: DATED: Copy sent YES to sender NO kT STATE OF ALASKA ALAS}LA oIL AND GAS CONSERVATION CO,.~dISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of Alaska Alaska Oil and C:~,:-: ~- -' ,'" .,~o]~ser, a,:on Commission 3001 Porcu.~ine Drive Anchorage, Maska 99501 RE: Receipt of the following material which was transmitted via ,.,'~f~ ,/ / is hereby acknowledged: 9UANTITY DESCRIPTION / RECEIVED: DATED: Copy sent to sender ARCO Alaska, Inc. Pos! Office Bo~ )360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the June monthly reports for the following wells: 3B-9 3C-11 2V-16 9-33 L2-20 3B-10 3C-12 2Z-14 9-34 L2-24 3B-11 1R-7 2Z-15 11-8 4-13 3B-12 1R-8 2Z-16 11-13 11-5 3C-10 1R-9 4-30 L1-10 11-6 (workover) (workover) (workover) If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU10/L63 Enclosures RECEIVED ] U L 1 ~'3 19~5 'AJaska 0it & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well J~ X Workover operation ~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-115 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21369 142' 4. Location of Well atsurface FSL, 433' FEL, Sec.16, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 6. Lease Designation and Serial No. ADL 25633 ALK 2566 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3B-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. June , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ¢ 1515 hfs, 06/18/85. Drld 12-1/4" hole to 4238', Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 9235'TD (6/24/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 9130'. Secured well & RR ~ 1800 hrs, 6/27/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 100'. Cmtd w/227 PF "C". 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4219'. Cmtd w/1300 sx AS Ill & 370 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 9215'. Cmtd w/700 ws Class G & 250 sx AS I. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/SP/GR f/9235' - 4219' FDC/CNL/Cal f/9235' - 4250' 16. DST data, perforating data, shows of H2S, miscellaneous data uu,~,,, ¥¥ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -~--E~ ~eport o~rthis form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR65 Submit in duplicate June 3, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3B-11 ARCO Alaska, Inc. Permit No. 85-115 Sur. Loc. 142'FSL, 433'FEL, Sec. 16, T12~!, R9E, Btmhole Loc. 1054'FSL, !035'FEL, Sec. 22, T12~, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa~ing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin Kuparuk River Unit 3B-11 -2- June 3, 1985 To a~d_. us in scheduling field work, please, notify...., this _=~_-_e 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Com~nission may be present to witness testing of the equipment before the surface casing shoe is drilled, k~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 ~ipe. In the event of suspension or abandop~ent, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ,/.-'-'-) A / ' ,"' ..... -" '/' "'-__~57,; '~7/":7 Chairman of-" AZask~ 0~1 and ~s Conservation Co~ission BY ORDER OF THE CO~{ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o eric!. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bc .00360 Anchorafle, Alaska 99510-0360 Telepllone 907 276 1215 Hay 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3B-11 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 3B-11, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plat o Diagram and description of the surface hole diverter system ° Diagram and description of the BOP equipment We estimate spudding this well on June 21, 1985. If you have any questions, please call me at 263-4970. Sincerely, ~j~~in.~~. ~n/~n~n]A~ea Drilling g er JBK/TEM/tw PD/L97 Enclosures Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA U;L AND GAS CONSERVATION COwiMISSION PERMIT TO DRILL DRILL ~X REDRILL [] DEEPEN [] lb. Type of well 20 AAC 25.005 EXPLORATORY [] SERVICE [] STRATI,e:Cf/~HIC DEVELOPMENT OIL ~X SINGLE ZONE [] DEVELOPMENT GAS ~ MULTIPLE~E~ 9. Unit or lease name '~&' Kuparuk River Unit 10. WelI3B_11number 2. Name of operator ARCO Alaska, Inc. _ 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 142' FSL, 433' FEL, $ec.16, T12N, R9E, UN (Approx.) At top of proposed producing interval 1435' FSL, 1433' FEL, Sec.22, T12N, R9E, UN At total depth 1054' FSL, 1035' FEL, Sec.22, T12N, R9E, UN 5. ElevJtion in feet (indicate KB, DF etc.i 6. Lease designation and serial no. RKB 85', PAD 55' ADL 25633 ALK 2566 __ 12. Bond information (see 20 AAC 25.025) Federai insurance Company Type Statewide Surety and/or number #8088-26-27 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount ,$500,000 15. Distance to nearest drilling or completed 3B-lOwell 60' @ surface feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi · NW of Deadhorse miles 142' @ surface feet 16. Proposed dePth (MD & TVD) 17. Number of acres in lease 9366' MD, 6337' TVD lent 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 52 ol (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 06/21/85 2803 psig@ 80°F Surface 3208 psig@ 6318 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT ~-'] Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOMTVD (include stage data) , -2Z~lt~--, 1'6'"- -6~..5~- H-40 We]d 80' 29' . 29' 109! 109' + 2OO cf 12-1/4"! 9-5/8" 36.0# J-55 BTC 4248' 29' I 29' 4276¢1 3246' 1200 sx AS Ill & I HF-ERW 370 Class G I sx 8-1/2" I 7" 26.0# J-55 BTC 9337' 28' II 28' 9366~ 6337' 280 sx Class G blend !---- HF-ERW I I _. _ 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development we]] to approximately 9366~ ND (6337' TVB). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface ho]e. The 9-5/8" casing wi]] be set through the West Sak sands at approximately 4276' ND(3246' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be instal]ed on the 9-5/8" surface pipe. It wi]] be tested upon installation and weekly thereafter. Test pressure wi]] be 3000 psig. Expected maximum surface pressure is 2803 psi. Pressure calculations are based on latest reservoir pressure· Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be ]oggedo The well wi]] be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Selected intervals wi]] be perforated within the Kuparuk formation and reported on subsequent reports. A downho]e safety valve wi]] be (see attached sheet) 23~-h-~re[)~ that the foregoing is true and correct to the best of my knowledge SIGNED / //~~¢,J/~f~/~-~' TITLE Area Dril,ing Engineer ~e sp;ce/~w foC/U~ission u;; DATE CONDITIONS OF APPROVAL r Mud tog required Samples required ! [~] Y ES NO Permit number Approval da // /85 Fo~m 10-401 Rev. 7-1-80 Directional Survey required ' .~/YES FqNO k APl number 50- ¢/ . ¢ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSI ON ER by order of the Commission DATE June 3, 1985 Submit in triplicate PERMIT TO DRILL 3B-11 installed and tested upon completion of the job. 3B-11 will be 60' away from 3B-10 at the surface. 3B-11 will drill past Sinclair Ugnu #1. The closet approach as calculated is 329' at 4090'TVD. Top of cement for the production string will be placed at 7664'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. On completion of disposal injection, the 9-5/8" x 7" annulus will be downsqueeze Arctic packed with approximately 200 sx of Class G cement and sufficient Arctic pack to place the cement/pack interface below the permafrost. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED M,A¥ P 400' Surface Diverter System · 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter, 4. 20" 2000 psi drilling spool ./10" side outlets. 5. 10" ball valves~ hydraulically actuated, w/10" lines to reserve pit. Valves to open automati6al.ly upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. b 1 · . Maintenance & 0Deration -.. Upon initial installation close annular preventer and verify l~hat ball valves have opened properly. Close annular preventer and blow air through diverter lines every 12 hours· 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 (n well under any circumstances. 1 6" Conductor 7 6 5 h DI A(~A4 #1 13-5/8' .....X:X:) PSI RSRRA BOP STACK I. 16' - 21:X)O PSI TN,,i,(~ 5'TN~rlN~ ~ 3. II' - 30D~ PS[ X 13-5/8'-- 5003 PS[ -SPACER SPO~ ,4. 13.-5/8" - 53:)0 PSI PIPE KILL LIliES 6. 13-5/8' - 5C00 PSI DO. BLE ENO'W/PIPE ~ ON TCP, 7. 13..-5/8". - ~_=030_ PSI a ACO..M.LATOR CAPACITY TEST 4 3 , 2 13. 14. RECE 13'-5/8" BOP STACK TEST I. FILL BOP STACK N,~ ~ k'W~FCLD W'[TH AEC'TIC DIESEL. 2. Q-ECK THAT ALL LO~ ~ ~ IN YELLHE/~ ARE FILLY t:~-TEACTED. SEAT TEST PLUG IN V~"~ L~F__AD WITH ~ING JT AN:) ~ IN LCX::XI:O~ 5. Q_OSE ~ PI;EVE~ ~ WANJAL KZLL AND LINE VALVES ADJ,N:ENT TO B~P STAQ~ ALL 4. PRE~ LIP 'TO 250~D FOR I0 I~N. CREA~ PRE~ TO~O PS~ HOLD FOR I0 BLEED PRE~ TO 0 ~ ' 5. (:PEN N,t,,I.L/~ F'EEVF_KTE~ AhD ~ KILL N,,D L]NE VALVES. CLCEE TO:) PIPE ~ N,,D HCR VALVES Chi KILL AJ~D ~ 6. TEST TO 250 PS! /V~D~ PS! ~ IN STEP 4. 7. CCNTIN.E TESTING ALL'~AL-VE:5~ LINES, AkD CHI~S W/TH A 250 PSI LC~ AND 3000 PSI HIGH, TEST AS s'rEP 4. ~3 mT Pm~ T~m' A~ ~ T~T ~hD'r ~ FULL CLOS[NG POS]T]V"~ ~EA[. Q-O~, CN.Y 8o CPEN TCP PIFE ~ AN:) CLQSE BOTTOM P[PE RAI~. lO. Q_~ BL[I~ RAh~ AND TEST TO 250-~I AI',,D 3000 MAN]FO..D AN3 LZI~r.S N;E FLLL CF FLUID. SET ALL VALVES [N ER[LLII~ POS[TICN. 12. TEST s'rANE~Ii:~ VALVES.. Kl~llYo KELLY ~ DRILL PIPE SAFE~ VALYE., AND [NSIDE EQ~> TO 250 PS! AAD FO~,, S]GN. AI~ SEAD TO ER]LLING SLPEEV[SOP.. PEEFCI~ ~ BCPE TEST AFTER I',EPPL]hG UP AN:) ~EEKLY Ti-E:REAFTER FLN:TICNN_LY CI:>EEATE ~ DAILY. 510084001 REV I ARCO Alaska, Inc Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Hrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Conductor As-Built Location Plats - 3B Pad Wells 5-8, 9-12 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L70 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany 4o 3o 2o to 15 Z2 DRIL~---SITE $'B CONDUCTORS AS BUILT LOCATIONS WELL 5 Y: 5,992,109.75 X= 5t8,519.96 989' FSL Lot. 70° 23'Z2.6108" Long. 149° 50' 57.665" 5t0' FEL WELL 6 Y: 5,992,049.98 X= 5t8,525.71 929' FSL Lot. 70° 23'22.0228" Long. t4 9°50'57.!~01 504' FEL WELL ? Y:5,991,990.26 X: 5t8,531.34 869' FSL Lat. 70° 23'21.4553" Long ._149° 50' 57. 341" 499' FEL WELL 8 Y: 5,991,930.53 X: 5 18,536.99 810' FSL Lat. 70° 25'20.8476'° Lo ng..149o50'57.179 493' FEL WELL 9 Y = 5,99 t, 383.04 X= 518,589.15 262' FSL Lat. 70 o 25't5.46t3" Long. 149050'55.692'' 444' FEL WELLIO Y= 5,99t ,32;5.38 X: 518,594.93 202'FSL Lot. 70°23' 14.8744" Long. 14 9 050' 55.528" 438' FEL WELL 1t Y: 5,9 91,263.67 X: 518,600.61 142' FSL Lat. 70023' 14.2870" - Long,) 49° 50'55.365" 433' FEL WELL 12 Y: 5,991,204.02 X = 5t8,606.24 83' FS L Lat. 70°23' 13.7001" Long. 149°50'55.205" 428' FEL LOCATED IN PROTRACTED SECTION 16, TOWNSHIP 12 N., RANGE 9 E., UMIAT MERIDIAN. COORDINATES ARE A.S.P., ZONE 4. SECTION LINE DISTANCES ARE TRUE. HORIZONTAL POSITION PER LHD'S ON PAD PILING CONTROL PK'S N 26 + 45 N 13+55 E 11 +70 E 11 +70 VERTICAL POSITION PER LHD'S ALCAP TBM'S 38-1t838-12. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG CED-9800- 3001 ~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF FEB. 17, 1985 FOR WELLS 5-t2. ARCO Alaska, Inc. Kuporuk Project North Slope Drilling DRILL SITE 38 CONDUCTOR AS-BUILT LOCATIONS Stole: AS SHOWN Dwg. No. NSK9.05.302d1 Lease & Well No. (2) Loc (2'~ thru 8) (8 (3) Admin -(ff .t h~u 12) (10 and 12) ( 4 ) C as ~ ~.,~~. ,~,-W~ "' ~'" (i 3- thru 21) (2~_ tfiru 26) YES NO REMARKS !. Is the permit fee attached .......................................... ~,~- '2. Is well to be located in a defined pool ............................ ./~-~ . 3. Is well located proper distance from property line .. 4. Is well located proper distance from other wells . ~ 5. Is sufficient Undedicated acreage available in this pool ........... ~ 3. Is well to be deviated .ani_is-wellbore--ptat-in'clffd~d I§ o.perator:"the only affected party ................................. 3. Can permit be approved before ten-day wait ............... 1O. 1l. 12. 13. 14. 15. 15. !.7. 2.8. i9. f. 0.. 2 1. Does oPerator have a bond in'force .................................. Is a 6onservation order needed ........ .... ........................... Is administrative approval needed ................................... Is"the'-lease number approPriate , ....... , ............................ .Is conductor siring.provided ....................................... Is enough.cement.used to' circulate on conductor and surface ......... Wil. l':'.cement tie.'in 'surface and intermediate or production strings ...~ Will. c~ment-cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing we,llbore ..... · ....... Is old wellbore hbandonment procedure included on 10-403'. .... ' ..... Is adequ.a;te wellbore separation ~proposed ............................. 212. 2'3. :i!:4. 26. :Is-a diverter-system required - . .............. ".. ~. Are necessary:diagrams 'of diverter and BOP equipment attached ....... ~ Does BOPEhave sufficient pressure rating - T. est to ~OOO .psig .. ~_ Doe.s.-the"choke manifold"comply ~/API RP-53 (Feb.78) ................... Is the presence of H2S gas probable ................................. , Add it.ion'al :- re~umremenc s . ..................... · .................... .. . . ~ ~ - ~ I' Addi.tiOn,al .... tRemarks:'~Oh*-'"~.'~/''~O. , ,, . of-X03-1o ~um47. &o 6-o~'.~*~c ~',1]' g~' ~a O~r~ ,w.-J/bom~'~ ,~/~8~ ~Z mm Geology: Eng~eering: WVA~__~ MTM HJH / JAL:~/~ rev: 03/13/8.5 6.011 '"' ' .' "IglTIAL GEO. 'UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE d ' t/1(3,' o'° ' . ...... 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. aB~ot~auv,/ gP.l k .£ S T 4 ? f ~ R.-'EL HE&DER .gATE :~,5f07/ 3 -'RZGZN : CCNT 'NJATZ.]N ~ PR=V'.SjS R=E,. :~iN ~M .CO"~ T:{N T S WN ' 36 -11 6N ,: TO ~N ' 12 ,~ C~,UN; N. S L3P~ STAT; ALASKA ~ T R Y; U S A ~q N ~! M C 0 ,~ T E N T ,S JNi'T dNIT T Y !P E OgO OOO 000 0 O JO O 00 0,30 0 J 0 l' Y ;D E CATE 030 O00 C O0 02,0 0 L~ 0 0 ~ 0 C A T E S i i ,i 005 007 0 02 087 006 0 J I 0'.55 065 055 '~UN '~tl, OAf" LDGf,:b. 3: 26 LC?: L. :~. CuDNEY CASING TY ?E FLUID DENS.ITl V,ISCG$~TY P~ R"~ AT ~riT ,.~, ~. 5.5u 3..~ 90 MATRIX S.,~NDS TONE . ~- DUAL.Ti~-gjCTT2N. S;'H'ERiCAL,._Y. 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