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185-284
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 185-284/ C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-11_21073_KRU_3A-16_LeakDetectionSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21073 KRU 3A-16 50-029-21492-00 Leak Detection Survey 11-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD PTD:185-284 T36618 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.17 13:06:31 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-11_21074_KRU_3A-16_CaliperSurvey_CaliperLogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21074 KRU 3A-16 50-029-21492-00 Caliper Survey w/ Caliper Log Data 11-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:185-284 T36609 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.17 08:51:34 -08'00' . • 2 '1"‘ RECEIVED JAN 18 2018 Schlumberger AOGCC 18 JANUARY-2018 Notice of Revisions Please find the enclosed data set for wells 3A-16 to supersede all previous edi- tions received. Revisions made were isolated to 3A-16. No other well data has been changed. A revision was made to the PPROF print and data on 3A-16 to include the cor- rect location. The revised CD is labeled Revl. scANNED FEB 0 6 2.010 Joseph D. Wilson Data Specialist;PetroTechnical Services Schlumberger 6411 A Street Anchorage,AK 99518 I CELL: (907)240-4838 OFFICE(907)273-1702 � � • 1110 � °° ~o g °° o � E = m C7NZ N O i " I CO ..m cu On 4 co > Co b QiY (O `I- -O f6 ! VI Y O E cu Q O U N +�+ > cl O C r r r co (6 +.+ OC Y v LO A-. 03 L a WC -p O @ C Q +-, U E a 6 CO Q 0 W CO CO CO W CO CO CU y t 0 LO N J V C C C C C C ++ a O N C CO CO CO CO CO CO 1- C NF (O r N M LO (O h O ++ C N U -O a3 O +-' Z Z v > -a v a O C i +_, u + ro O Frf ,,f co N -a ,.n U C v a 00000000 en C ;.- O W W W W W W W W Ln N C } r H LL LL LL LL LL LL LL LL Q Q J J J J J J J J a c •C4- 0) (1) Z co a z z z z z z z z aU o v 0 v OO LL LL LL LL LL LL LL LL K -0 +-, > 0 E U cu z to a u > O b ,.,.. C O to(-0 - Co .,. 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P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-16 Sundry Number: 314-099 Dear Mr. Toomey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this 5 day of March, 2014. Encl. STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMI, N RECEIVED APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 FEB 20g S 0_1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell pr Change A..r. . !ISuspend r Rug Perforations r Perforate r Pull Tubing A Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development 17. 185-284 3.Address. Stratigraphic r Service r 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21492-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 - 3A-16 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25631 • Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9155 •6438 9044' 6360' none 8700' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104' 104' SURFACE 4044 9.625 4075' 3185' PRODUCTION 9111 7 9141' 6428' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8666-8682,8800-8826,8842-8900 ` 6102-6113,6193-6211,6222-6262 2.875 J-55 8755 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-UPPER WEATHERFORD ER PACKER(ELMD) t MD=8464 TVD=5962 PACKER-LOWER WEATHERFORD ER PACKER(ELMD) . MD=8513 TVD=5996 PACKER-BAKER HB PACKER W/XO • MD=8532 TVD=6010 PACKER-BAKER 1B PACKER . MD=8736 TVD=6149 SSSV-BAKER FVL SSSV , MD=1823 TVD+1732 11 12.Attachments: Description Summary of Proposal p- . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 17Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/15/2014 Oil r ' Gas r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263-4773 Email: Ian.A.ToomevCc�conocophilliDs.com Printed Name Ian Toomey Title: Workover Engineer Signature ---)-- Phone:263-4773 Date 2-26 .-/Y Commission Use Only Sundry Number: Q p Conditions of approval: Notify Commission so that a representative may witness '1\—`— 0 Plug Integrity r BOP Test J Mechanical Integrity Test r Location Clearance r Other: BOP fe 3 t to ,3691)C?ip 5 • RBDM"I MAY 0 9 2(14 Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 — .i_b ,f , , , (/_ APPROVED BY Approved by: I Y� COMMISSIONER THE COMMISSION Date: 3 -s--/ Approv:�: c�tj61�itTqdALmonths'z. Dpe,drate of approval.Form 10-403(Revised 10/2012) VV / I Submit Form and Attachments in Duplicate V1-/ 3/5/14' "-t,y RECEIVED ConocoPhillips FEB 20 2014 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 19,2014 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk�Well 3A-16(PTD# 185-284). Well 3A-16 was drilled in December 1985 and completed in January 1986 as a selective A and C-sands producer. 3A-16 produced until June 2008 when the well failed a TIFL. A leak detection log was run and found a leak at—5' below gas lift mandrel#6. A retrievable tubing patch was installed and the well resumed production. In June 2013 3A-16 failed another TIFL. A leak detection log was run and found a leak at 8310' RKB. Slickline and Coil Tubing were unsuccessful at pulling the patch across GLM#6;therefore,we will have to deal with it on the rig. The top ER patch packer is set at 8464' RKB with the patch assembly stung into the lower ER patch packer set at 8513' RKB. Standard pre-rig diagnostics could not be completed due to the inability to retrieve the patch. The well has not been and cannot be tested for 7" casing integrity with a CMIT. The possibility exists that either the production casing below the surface casing shoe or the packer is compromised. On 10/12/2013 while prepping the well for the RWO a surface casing leak(SCL)was identified at 942'MD. The proposed workover is to pull the existing 2-7/8"tubing completion, cut and pull the 7" casing above the top of cement(TOC)in the 7"x 9-5/8"annulus,reinstall new 7"casing, and circulate cement into the 7"x 9-5/8"annulus; which will ultimately plug the leak in the 9-5/8" casing. Then install a new 2-7/8" stack packer gas lift tubing completion. This Sundry is intended to document the proposed work on the producer, including the modifications to the production casing, as well as request approval to workover the well. If you have any questions or require any further information,please contact me at 263-4773. Sincerely, Ian Toomey RWO Engineer CPAI Drilling and Wells 3A-16 Kuparuk Producer Rig Workover (PTD #: 185-284) Current Status: i7 S v,-Aa `r C a s,z�5 1 r a 3A-16 is currently shut-in with a known tubing leak and SCL. The well has been loaded with KWF. Scope of Work: The proposed workover is to pull the existing 2-7/8"tubing completion,cut and pull the 7"casing above the top of cement(TOC)in the 7"x 9-5/8"annulus,reinstall new 7"casing,and circulate cement into the 7"x 9-5/8"annulus; which will ultimately plug the leak in the 9-5/8"casing. Then install a new 2-7/8"stack packer gas lift tubing completion. General Well info MPSP: 1492 psi(utilizing 0.1 psi/ft gas gradient and SBHP listed below) Reservoir pressure/TVD: 2088 psi at 5962' TVD SBHP taken on 7/1/13 ✓ Wellhead type/pressure rating: FMC Gen III, 11"5K btm x 7-1/16"5K top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-T: failed June 1,2013 MIT-IA: unable to test due to stuck patch and tubing leak MIT-OA: failed on October 12,2013 Well Type: Producer Estimated Start Date: March 18,2014 Production Engineer: Toon Changludgdee/Suzanne Short Workover Engineer: Ian Toomey(263 -4773/Ian.A.Toomey@ conocophillips.com) Pre-Rig Work Request 1. Set BPV within 24 hours of rig arrival. Proposed Procedure 1. MIRU 2. Pull BPV. Load well with 8.6 ppg seawater. Ensure well is dead. 3. Set BPV and blanking plug or two-way check. ND tree. 4. NU BOPE. Pressure test(PT)BOPE including annular. Pull blanking plug and BPV or two-way check. 5. MU landing joint,BOLDS,POOH laying down tubing,and spooling control line. a. If tubing will not pull free, RU E-line and cut tubing in the middle of the first full joint above the patch. 6. RIH with 7"casing sckper on DP to the top of the PBR or tubing stub,circulate well clean. 7. RIH and set RBP#1 just above PBR or tubing stub. PT to 2500 psi and drawdown test(DDT)to 0 psi. 8. RU E-line: RIH with casing evaluation logs including CBL. Log from top of RBP to surface to determine TOC. Fire string shot across the second collar above the TOC. RD E-line. 9. RIH and set RBP#2 below the TOC. PT to 2500 psi and DDT to 0 psi. Dump 50' of sand on top of plug. 10. ND BOP stack, ND tubing head using Hydratight, spear the 7" casing and re-land in slips. Cut off excess casing growth. 11. NU BOP stack to the casing head(cannot test break due to SCL,BOP stack will be considered a diverter,there are 2 barriers in the well at this point). ✓ 12. RIH with multi-string cutter(MSC)and cut the 7"casing above the top of cement. 13. Spear the casing and circulate out the ArAic Pack from the OA with heated diesel followed by heated seawater. 3A-16 Kuparuk Producer Rig Workover (PTD #: 185-284) —Proposed Procedure Continued- 14. POOH laying down 7"casing. 15. Set test plug in the casing head and PT to 250/3000 psi(test pressure limited by 3M casing head). 16. RIH with 9-5/8"casing scraper to the top of the 7"stub and circulate well clean. 17. RIH with tandem string mill to gauge the 9-5/8"casing for the ES cementer,dummy drift the ES cementer. 18. RIH with the back-off tool to the top of the 7"casing stub,engage the stub,and back-off the casing stub. 19. RIH with 7"casing spear and retrieve 7"casing stub. 20. RIH with new 7"TC-II casing and ES cementer. Screw into top of 7"casing and PT casing to 2500 psi. 21. RU SLB cementers: cement the 7"x 9-5/8"annulus to surface. RD SLB cementers. WOC. / 22. ND BOP stack, pull 7" casing in tension and land in the slips. Cut off excess 7" casing. NU new tubing head and BOP stack,PT BOP. 23. RIH with 6-1/8" mill tooth bit to the TOC, drill up cement, closing plug, and ES cementer. RIH with 6-1/8" concave mill and dry drill any remaining debris on top of the sand. RIH with wash string assembly and circulate out sand on top of the RBP#2. 24. RIH with RBP retrieving head to the top of the plug,engage RBP#2 and pull to release. 25. RIH with RBP retrieving head to the top of the plug,engage RBP#1 and pull to release. a. If tubing was cut,MU overshot dressed for 2-7/8"tubing and RIH on DP to the top of the tubing stub. Jar seal assembly from the PBR. 26. MU FH packer assembly and RIH with 2-7/8"GL completion to the top of the PBR. 27. Spot corrosion inhibited seawater below the FH packer. 28. Sting into the PBR until fully located, space out 1 ft. from fully located,drop ball&rod, set the FH packer. PT the IA. Shear the PBR. 29. Space out with pups,MU hanger,load the well with corrosion inhibited seawater, land the hanger,and RILDS. 30. PT the tubing and IA. Shear the SOV. 31. Install the BPV or two-way check. Pressure up on the IA to 1000 psi to test the BPV or two-way check from below. Bleed IA to 0 psi. 32. ND BOPE. NU tree. If BPV is installed,pull BPV and install tree test plug. Test tree. 33. Pull test plug/two-way check. Freeze protect well with diesel. Set BPV. 34. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull ball&rod b. Pull SOV and run GLD C. Pull RHC plug body d. RD slickline 4. Return well over to operations. ' Agg KUP PROD 3A-16 • • ConocoPhillips ' ! Well Attributes Max Angle&MD TD • • Alaska,InC Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) (trvxrJMlhpa 500292149200 KUPARUK RIVER UNIT PROD 53.82 3,000.00 9,155.0 .". Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 36-16,9/3020131:38.34 PM SSSV:TRDP Last WO: 35.50 12/27/1985 Vence)schematic(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag: 8,949.0 7/6/2008 Rev Reason:GLV C/O hipshkf 9/13/2013 HANGER;24.0 �:- ' • -_ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 104.0 104.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread • SURFACE 95/8 8.921 30.6 4,074.5 3,184.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread 1.1 i PRODUCTION 7 6.276 30.0 9.141.1 6,428.3 26.00 J-55 BTC I rm,Tubing Strings TT A f Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;31.0-104.0 - TUBING 27/8 2.441 24.0 8,756.3 6,163.6 6.50 J-55 EUE8RD Completion Details INominal ID Top(ftKB) Top(TVD)(ftKB) Top In (") Item Des Com (in) SAFETY VLV;1,8233- -1.•',' 24.0 24.0 0.07 HANGER FMC HANGER W/PUP 2.875 I1,823.3 1,731.6 34.00 SAFETY VLV BAKER FVL SAFETY VALVE 2.312 GAS LIFT;2,548.1 al 8,520.0 6,001.4 45.86 PBR BAKER PBR 3.250 8,531.7 6,009.5 45.92 PACKER BAKER HB PACKER W/XO 3.250 • • 8,676.9 6,109.6 47.07 BLAST RING RICKERT BLAST RING(1) 2.400 8,734.1 6,148.5 47.22 LOCATOR BAKER LOCATOR 2.406 8,735.5 6,149.5 47.22 PACKER BAKER IB PACKER 3.250 SURFACE;30.8.4,074.5- - 8,747.8 6,157.8 47.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,755.3 6,163.0 47.17 SOS BAKER SHEAR OUT SUB 2,375 GAS LIFT;5,115.1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;8,743.3 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,464.0 5,962.4 46.10 PACKER UPPER WEATHERFORD ER PACKER(ELMD) 7/13/2008 1.465 8,466.7 5,964.3 46.08PATCH PATCH ASSEMBLY-SNAP LATCH&SPACER 7/13/2008 1.310 GAS LIFT:7,654.7 PIPE(ECMO) 8,512.7 5,996.3 45.82 PACKER LOWER WEATHERFORD ER PACKER(ELMD) 7/13/2008 1.465 GAS LIFT;8,127.8 8,700.0 6,125.4 47.31 Fish GRAPPLE ONE-HALF OF 7/8"GRAPPLE LOST"' 6/22/2007 SOMEWHERE??""DOWNHOLE Perforations&Slots PACKER;8.4640 Shot Dens lop(TVD) aim (TVD) (shots/f GAS LIFT;8.475.4 Top(ftKB) Btm(ftKB) (itKB) (ftKB) Zone Date t) Type Com PATCH,8.466.7 8,666.0 8,682.0 6,102.3" 6,113.2 UNIT B,C-1, 1/13/1986 12.0 IPERF 5"HJII Csg Gun;90 3A-16 deg.ph f 8,800.0 8,826.0 6,193.4 6,211.1 A-3,A-4,3A- 1/13/1986 4.0 IPERF 4"HJ II Csg Gun;90 PACKER;8,512.7 16 deg.ph t 4 8,800.0 8,826.0 6,193.4 6,211.1 A-3,A-4,3A- 72/1986 1.0 RPERF 2 1/8"Bar Kone II;0 16 deg.phasing PBR;8,520.0 8,842.0 8,900.0 6,222.0 6,261.7 A-2,3A-16 1/13/1986 4.0 IPERF 4"HJ II Csg Gun;90 PACKER;8,531.7 _ 8,842.0 8,860.0 6,222.0 6,234.3 A-2,3A-16 7/2/1986 deg.ph 4.0 RPERF 2 1/8"Bar Kone II;0 deg.ph GAS LIFT;8,569.5 Mandrel Details St atl C GAS LIFT;8,639.2 - on Top(TVD) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date m 1 2,548.2 2,266.2 MERLA TMPD 1 GAS LIFT 'DMY BK 0.000 0.0 9/29/2013 �T 2 5,115.1 3,816.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/29/2013 (PERF;8,666.0.8,682.0� 3 6,743.3 4,811.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/29/2013 4 7,654.7 5,407.8 MERLA 'TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/29/2013 5 8,127.8 5,731.7 MERLA TMPD 1 GAS LIFT OPEN 9/29/2013 Fish;8,700.0 - 6 8,475.4 5,970.3 MERLA TGPD 11/2 GAS LIFT DMY RK- 0.000 0.0 6/11/2008 EXT PKG 7' 8,569.5 6,035.8 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 12/25/1996 8 8,639.2 6,083.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 6/2/2008 GAS LIFT;8.717.3 9 8,717.3 6,137.1 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 6/2/2008 Notes:General&Safety LOCATOR:8.734.1 End Date Annotation 629/2010 NOTE:View Schematic w/Alaska Schematic9.0 SUB,8.734.5 PACKER:8.735.5 NIPPLE;8,747.8 SOS;8.755.3 IPERF;8,800.0.8,826.0 - RPERF;8,800.0.8,826.0 RPERF;8,842.0.8,8600 IPERF;8,842.0-8.900.0 -. • PRODUCTION;30.0-9,141.1 ~~~~' ConocoPhrllips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seaniount: ti APR p 5~'~2010 ,~~~~,~rnmission ~~~~~ ~~ 3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, t`op of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Fieid Date 3/31/10 30_ ~R sr_ ~r ~N ~~ ~_i inn zn ~ ~R oen~~ Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surtace Na 26" n/a 4.25 3/29/2010 3A-04 50029214330000 1852070 SF Na 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3/29/2010 16 50029214920000 1852840 SF Na 23" n/a 3.4 3/29/2010 3B-10 50029213660000 1851140 6'6" Na 6'6" n/a 25.5 3/28/2010 3C-11 500292135'10000 1851020 SF Na 25" n/a 4.25 3/27/2010 3G-08 50103201280000. 1900650 SF 0.65 27" 3/2/10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 3/28/2010 3H-01 50103200840000 1871100 SF Na 21" n/a 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-14B 50103200920200 2050210 SF n/a 23" Na 3.4 3/29/2010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF n/a 22" n/a 3.4 3/28/2010 3M-05 50029217060000 1870250 SF n/a 21" n/a 3.4 3/29/2010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/29/2010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 3/27/2010 30-16A 50029217960100 1880430 SF n/a 22" Na 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/27/2010 ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: .~ , ~u~ ~ ~ 200 !'181:€~ '4.r'~~ ~ ` ~ , '~ r~'r n; _~., ~.~f'ts ~~,~~3~J11 ~~: ; . - ~,N~~ AUK ~ _F 20D8 Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we113A-16 (PTD 1852840). The report records the successful Tubing patch set to repair the TxIA communication. Please call myself or Martin Walters at 659-7224 or MJ Loveland/Perry Klein at 659- 7043 if you have any questions. Sincerely, /~r Brent Rogers Problem Well Supervisor JRJ~ ~ 7 200$ STATE OF ALASKA ~~8s~~~ ~~ ~' ~~~ ~',;^ s; ~s~"r#T?17~#alt;3di ALASKA OIL AND GAS CONSERVATION COMMISSION B~~r:~~:: ,,:;, REPORT OF SUNDRY WELL OPERATIONS ' 1. Operations Performed: Abandon ^ Repair Well^ _ Plug Perforations ^ Stimulate ^ Other ^/ Tbg Patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhillipS Alaska, InC. Development^ ' Exploratory ^ 185-284 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21492=00 7. KB Elevation (ft): 9. Well Name and Number: RKB 71' ~ 3A-16 ` 8. Property Designation: 10. Field/Pool(s): ADL 25631 `ALK 2565 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9155' feet true vertical 6438' _ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 104' 16" 104' 104' SURFACE 4003' 9-5/8" 4074' 3184' PRODUCTION 9064' 7" 9135' 6424' Perforation depth: Measured depth: 8666-8682, 8800-8826, 8842-8860, 8860-8900 true vertical depth: 6102-6113, 6193-6211, 6222-6234, 6234-6262 Tubing (size, grade, and measured depth) 2-7/$", ~-55, 8756' MD. Packers &SSSV (type & measured depth) pkr= BOT'HB' W/XO ; BOT'1 B' pkr= 8532' ; 8736' SSSV= Baker'FVL' SSSV= 1823' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OiIO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 7/16/2008 Form 10-404 Revised 04/200 ~ ~~ ~uC ~ ~ 2~~~ Submit Original Only ~~~ C~RI~INAL 3A-16 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/06/08 07/07/08 07/11 /08 07/12/08 07/13/08 07/14/08 07/15/08 Summary TAGGED FILL @ 8949' WLM, BRUSH & FLUSH TBG FOR PATCH FROM 8462' RKB TO 8525' RKB, DRIFTED TBG W/ 15' OF 2.125" TO 8600' WLM 'SET 2-7/8" WEATHERFORD ER LOWER PATCH PACKER AT 8512' ELM. WELL LEFT ',SHUT IN. SLICKLINE TO SET UPPER ASSEMBLY. ATTEMPT TO SET TUBING PATCH, SET DOWN HIGH @ 8373' SLM, BRUSH AND FLUSHED, DRIFTED FOR UPPER PATCH ASSEMBLY (QC, 2.281 CENT„XO, 8'x 2.125"STEM, XO, 2.22"CENT, XO, 9' x 2.125"STEM, XO, 9' OF 2.25"DD BAILER- 28.4' OAL) W/O ANY PROBLEMS. SET WEATHERFORD PATCH SNAP LATCH ASSY (OAL=26' 8 1/2" MIN ID 1.31") IN LOWER ER PKR @ 8512' RKB.SET UPPER PATCH ASSY WITH ER PKR (OAL=22' 2"). RAN HOLEFINDER; STA #3 APPEARS TO BE LEAKING.SET TESTTOOL IN ER PKR.REPLACED DV STA # 4 W/ 1/4" OV. PULLED STA#3 OV. REPLACED GLV WITH NEW DESIGN @STA #1,#2 AND #3. PERFORMED POSITIVE TEST ON TBG. DRAWDOWN TEST ON IA FOR PATCH. PULLED 2 7/8" ER TESTTOOL. JOB COMPLETE. TIFL- passed (post patch); Initial T/I//0= 90/1250/300; Shut in WH and LG; Shot initial FL @ 5390 ft. Stacked out TBG with LG; Bled down IA ;Shot second FL @ same location; T/I/0= 1175/675/300. Set Weatherford retrievable patch from 8463' - 8512'. ~i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~~~ ~ ~~~~ ATTN: Beth ' i ~' Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/25/08 iG-14 11964620 INJECTION PROFILE : •- ~ ~ °~ •-Z~/ 'g~ r ~;'"~~f=f 06/13/08 1 1 A-16 11964621 LDL .'` k 06/14/08 1 1 1 B-14 12061702 LDL G'` '%' U ~-- -~~ 06/15/08 1 1 2N-327 12061704 PRODUCTION PROFILE ~rJ'=~- m ' ~C ~=' av/` ~^-~q 06/17/08 1 1 1 B-04 12061705 INJECTION PROFILE ; T '~ 9 --, '(; ~._ f°'/~ •--^.'~ ': 06/18/08 1 1 2D-05 11964625 INJECTION PROFILE/LDL; ~-- -~~ - ~ ~~"r_ ° ° 06/18/08 1 1 1 E-12 11964628 GLS ~ `;d °(~~;~ ~, ,~q' ~; ~ ~ 06/20!08 1 1 3A-06 12061708 INJECTION PROFILE •' ~ ~ (5 ~~• -~,~~~~ d~?^`~~~~ ~' 06/21/08 1 1 2A-U8 11964629 INJECTION PROFILE~b%„^ ''.~~'~ f~r~'?~r~ 06/21/08 1 1 1L-11 11964630 PRODUCTION PROFILE ~ °- ~- ~~ ~~'°" ~.;.Fl, - 06/23/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • Memory Multi-Finger Caliper Lag Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3A-16 Log Date: June 21, 2008 Field: Kuparuk Log No.: 8690 State: Alaska Run No.: 1 API No.: 50-029-21492-00 Pipet Desc.: 2.875" 6.5 tb. J-55 8RD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 8,594 F'G (MD} Inspection Type : Corrosive 8 Mechanical Damage lnspection COMMENTS This caliper data is tied into the Production Mandrel # 7 ~ 8,569' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 2.875" tubing logged is in good condition. No significant wall penetrations, areas of cross sectional wall loss or LD. restrictions recorded throughout the interval of tubing logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS No areas of wall penetrations (>18%) are recorded in the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (>11%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. ~~~~~~ J U N ~. ~~ 2008 Field Engineer: K. Miller Analyst: J. Thompson Witness: S: Ferfuson ProACtive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888} 565-9085 Fax: (281} 431-7125 E-mail: PDS~~memorylog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fa?c: (907} 659-2314 • • Correlation of Recorded Damag Pipe 1 2.875 in (21.8' - 8577.0') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 3A-16 Kuparuk ConocoPhillips Alaska, Inc. USA June 21, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profile 1 25 22 741 50 1502 75 2295 GLM 1 100 3080 ~ a`, 125 3861 ~ LL E ~ ~ ._ Z s ~ 150 4644 ~o p GLM 2 175 5432 200 6211 GLM 3 225 7001 GLM 4 250 7784 GLM 5 GLM 6 GLM 7 274 8577 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 274 • • PDS Report Overview ~~~.: ~. Body Region Analysis Well: 3A-16 Survey Date: June 21, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: J. Thom son Tubing: Nom.OD Weight Grade & thread Nom.ID Nom. Upset Upper ten. Lower ten. 2.875 ins 6.5 f -55 8RD 2.441 ins 2.875 ins 6.0 ins 0.0 ins Penetration and Metal Loss (°,6 wall) ~ penetration body metal loss body 2 50 200 150 100 50 0 0 to 1 to 10 ro 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal sed total = 277 pene. 0 249 28 loss 152 124 1 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 4 4 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 7 Bottom of Survey = 2 74 Analysis Overview page 2 • • PDS REPORT J OINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 8RD Well: 3A-16 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 21, 2008 Joint No. )t. Depth (Ft) I'~~n. lllnel Iln..) Pen. Body (Ins.) I'en. `% :Metal lost `4i. Min. LD• (fns.) Comments Damage Profile (%wall) 0 50 100 1 22 (I 0.01 4 I .38 2 53 (t 0.01 7 i .37 84 U 0.03 12 i 2.38 4 113 (1 0.01 4 tt 2.36 5 144 U 0.02 ~~ -1 2.37 6 174 tt 0.01 ~ -! 2.35 7 203 a 0.0 I ~1 I I 2.37 8 234 tt 0.02 lU I 2.36 9 265 U 0. 2 1 U t~ 2.36 =, 10 294 U 0.02 ~) (~ 2.35 11 322 U 0.01 7 ~ .38 12 352 U 0.03 13 (, 2.36 Lt De o its. 13 384 tt 0.01 b 5 2.35 14 413 tt 0.02 I1 Is 2.35 15 443 tt 0.03 l .35 16 473 U 0.04 18 ? 2.37 Sallow ittin 17 50 l) 0.03 12 ~ 2.34 Lt. De osits. 18 532 U 0 03 12 t~ .38 19 562 (t 0.01 (> 2.35 20 593 tt 0.01 (~ i, 2.35 21 621 U 0.03 11 is 2.35 22 652 tt 0. 2 £', 1 2.37 3 681 tt 0.03 12 (, 2.38 24 711 t 1 0.01 (> i 2.36 7 U 0.03 1 Z h 2. 7 26 769 t) 0.01 t, I 2.35 27 800 ct 0.02 I1 ~1 2.37 28 830 a 0.01 ~ ~ 2.38 29 860 (t .03 12 tl 2 36 30 891 t1 0.02 ~) ~ 2.37 31 920 (I 0.02 ttl 6 2.36 32 951 t1 0.02 9 5 2.36 33 982 tl 0.02 7 2.36 34 1013 tt 0.03 I2 1 2.36 35 1043 (~ 0.01 (~ 5 2.35 36 1073 U 0.03 15 b 2.37 Shallow ittin . 37 1103 U 0.02 II ~ 2.37 38 1131 tl 0.03 I 7 2.37 39 1162 (t 0.01 7 4 2.35 40 1192 t) 0.02 1O (1 2.36 41 1221 U 0.01 7 1 .37 42 1253 a 0.02 £3 1 2.37 43 1 84 U 0.01 s 1 2.38 44 1315 ~~ 0.02 ~i I 2.37 45 1346 t? 0.01 (, tt 2.37 46 1377 ~~ 0.01 4 I 2.37 47 1408 U 0.01 6 I 2.38 48 1439 i I 0.01 ~1 1 2.37 4 1470 n 0.01 5 tt 2.38 50 1502 ~ ~ 0.02 t~ I 2.38 ®Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 2.875 in 6.5 ppf J-55 8RD Well: 3A-16 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 21, 2008 Joint No. Jt. Depth (Ft.) I'r~n. lllse~t 11n~.) Pen. Body (Ins.) Pen. `% Me1,~l Ic~ss `ii, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 1533 U 0.01 i 1 .38 52 1564 (~ 0.02 `~ t t 2.38 53 1596 U 0.02 t3 I 2.36 54 1627 U 0.01 6 I 2.37 55 165 U 0.01 4 I 2.38 56 1689 t~ 0.01 4 t t 2. 7 57 1721 tl 0.01 1 2.37 58 1751 l) 0.01 4 t~ 2.37 59 1783 U 0.01 a 2.37 59.1 1 14 U 0.02 £3 t~ 2.40 PUP 59.2 1818 U 0 U U 2.3 S SV 59.3 18 1 tl 0.02 7 _' 2.32 PUP 60 1830 a 0.02 t3 I 2.37 61 1861 a 0.01 7 I 2.37 62 1892 U 0.0 6 t ~ 8 63 19 3 u 0.0 6 u 2.37 64 1954 ll 0.0 ~) 1 2.3 b5 1985 (t 0.01 4 1 .37 66 016 (~ 0.0 10 1 2 37 67 2047 a 0.02 `) I .37 6 2078 (r.tlt, 0.02 ti 1 2.37 69 2109 t~ 0.01 a I 2.37 70 240 r) 0.02 Fi I 2.37 71 2171 (~ 0.01 6 1 2.37 72 202 t ~ .O1 6 1 2. 7 73 2233 U 0.01 7 I 2.37 74 265 (1 0.01 7 1 2.36 75 2295 11.U(~ 0.02 9 1 2.37 76 2327 n 0.02 ~) I 2.36 77 2358 (I 0.01 ~~ 2.37 78 2389 (~ 0.02 ti a 2.37 79 2420 U 0.01 6 u 2.37 80 51 t) 0.0 4 I 2.37 81 2482 U 0.01 7 I 2.37 82 2 13 U 0.02 l U t l 2.34 82.1 2543 U 0 l) a N A GLM 1 Latch ®7:00 83 2552 l~ 0.02 t3 I 2.34 84 2582 +~ 0.01 7 I 2.36 8 2613 U 0.01 -1 I 2.3 86 2643 t7 0.02 `i t~ 2.37 7 2675 n 0. 1 7 I .36 88 2705 t) 0.02 t3 I 2.36 89 736 U 0.02 10 1 .36 90 2767 tl 0.01 4 I 2.36 91 2799 O 0.01 i I .36 92 2830 tl 0.01 ~ I 2.35 93 861 (~ 0.01 4 I .36 94 2893 (Ltt; 0.02 Ei I 2.35 95 2923 O 0.01 7 I .35 96 2954 t~ 0.01 7 t~ 2.37 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 8RD Well: 3A-16 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 21, 2008 Joint No. Jt. Depth (Ft.) I'en. Ul~sc~t (Ins.) Pen. Body (Ins.) I'cn. % 1~let.~l loss ';~o Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 2986 tt 0. 1 4 1 2.37 98 3017 (t 0.01 ~ 1 2.36 99 3049 U 0.02 ti I 2.37 1 3080 O 0. ?i I 2.36 1 1 31 1 U 0.0 ~) I 36 10 314 (t 0.02 ~) 1 2.35 103 3174 ~) 0.01 7 2.35 104 0 tt 0.01 5 u .36 1 5 3236 U 0.0 (i 1 .36 106 26 U 0.01 7 1 2.3 107 329 tt 0 1 4 1 6 108 330 a 0.02 ~> ~ t 2.35 109 3361 ~ t .01 4 I 2.36 10 3392 t t 0.01 5 _> .36 111 34 4 ti 0.01 7 _' 2.36 112 3455 a 0.02 9 1 2.35 113 3486 O 0.02 ~t I 2.3 114 3 17 U 0.0 3 I 2.3 115 3549 U 0.01 ~ 1 2.36 116 3 80 a 0.01 6 U .37 17 3611 ~) 0.01 5 1 2.36 118 3642 U 0.0 8 _' .36 119 3674 tt 0.01 ~ I 2.36 120 3705 U 0.01 ~ U 2.35 2 736 tt 0. 1 -1 1 2 3 122 3768 (t 0.01 v .37 12 3799 ~ t 0.02 t5 2.3 124 3830 ~l 0.02 fi I 2.35 125 3861 O 0. 1 4 I 2.3 126 3893 0 0.01 4 ? 2.36 7 3924 O 0.01 i ' 2.36 128 3955 a 0.01 4 ? 2.35 129 3987 It 0.02 ~t ~' .35 130 4018 t) 0.01 (~ 2.36 1 1 4049 ~ t 0.0 i I 2.35 132 4080 tt 0.02 ti 2.35 133 4112 U 0.0 ti I 2.35 134 4143 U 0.01 4 1 2.36 135 4174 U 0.02 1O 1 2.36 136 4205 O 0.01 4 2 2.35 137 4237 U 0.02 ti 3 .35 138 4269 U 0.01 7 tt 2.36 1 9 4300 ~ l 0.01 4 I 2.35 140 4331 U 0.02 (i _' 2.35 141 436 O 0.01 ~ 1 2.36 142 4394 O.U6 0.02 ti 2.35 143 4425 ~~ 0.01 6 1 2.35 144 4456 ~ t 0.01 4 ' 2.35 145 4487 0.01 6 ' 2. 6 146 4518 0.01 E~ 2.35 Penetration Body Metal Loss Body Page 3 • PDS REPORT J OINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf J-55 8RD Well: 3A-16 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 21, 2008 Joint No. Jt. Depth (Ft.) Pc•n. 1 )Lsei (Inti.) Pen. Body (Ins.) Pen. °r~ ~te~~,il I cuss `,~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 7 45 0 U 0.01 7 1 2.36 148 4582 t? 0.01 6 1 .3 149 461 0 0.01 (i I 2.36 150 4644 U 0.01 7 I 2.35 151 4675 t ~ 0.01 ~ I 2.35 15 4706 0 0.01 6 0 .34 153 4738 ~ ~ 0.02 ~) I 2.36 154 4769 a 0.01 b I 2. 5 155 4801 U 0.01 4 2.3 156 483 ~) 0.01 4 ~ 2.3 157 4863 t~ 0.01 d ' 158 895 U 0.01 4 I 35 159 4926 t) 0.01 U I 2.3 160 4957 0 0.01 6 1 2.35 16 4988 U 0.0 t3 I .35 162 5019 0 0.01 4 ~' .33 163 5051 t~ 0.0 is 2.34 164 5082 t~. I ~ 0.02 £3 ~ ~ .33 164.1 5113 ~~ 0 t) t~ N A GLM 2 Latch ~ 2:30 165 5119 t) 0.01 5 s 2.35 166 5152 a 0.01 ~ _' 2.35 167 5183 i).0~) 0.02 8 ? 2.35 168 5214 0 0.01 6 ' 2.35 169 5245 U D.O1 U 2.35 170 76 a 0.02 t3 1 35 171 5307 (~ 0.01 =1 I 2.34 17 5339 t) 0.01 ~ 1 2. 4 173 5370 U 0.02 F3 I 2.35 174 5400 U 0. 2 l U 1 2.35 175 5432 0 0.02 ti 2.35 176 5462 0.10 0.02 ti Z 2.3 177 5493 O.U~ 0.02 f3 ? 2.35 178 5524 a 0.01 4 _' 2.3 179 5555 ~ I 0.02 ti ' 2.34 180 5587 0 0.01 ~ 2.35 181 5617 U 0.02 f~ I 2.36 1 2 5648 U 0.01 7 ~ .35 183 5679 t) 0.01 ~ 0 2.36 184 5710 U 0.02 8 I 2.34 185 5741 0 0.01 3 2 2.35 186 5772 0 0.01 ~1 1 2.35 187 5804 0 0.02 fi 1 2.35 188 5835 U 0.02 I U I 2.35 189 5866 U 0.01 4 I 2.35 190 5898 U 0.01 U ~ 2.34 191 5930 0 0.01 ti ~' 2.35 192 5961 U 0.02 i _' .34 193 5993 ~ ~ 0.01 6 2.35 1 4 6025 0.01 5 2.35 195 6055 0.01 ~ 2.35 Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf )-55 8RD Well: 3A-16 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 21, 2008 Joint No. Jt. Depth (Ft.) I'~~n. I )I,~c~l (Irn.) Pen. Body (Ins.) Pen. °io Metal I os~ ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 196 6087 U 0.02 8 I .35 197 6117 t J 0.02 8 1 .35 198 6149 U 0.01 b I .35 199 6180 t 1 0.02 t3 _' .35 00 6211 t) 0.01 ~ U .32 201 6243 l) 0.01 ~ 1 2.35 02 274 l) 0.01 (~ 1 2.34 203 304 U 0.01 2 34 204 633 (t 0.02 f3 ~ 2.34 205 6367 tt .02 t3 I 2.35 206 6399 l t 0.02 7 2.34 207 64 9 U 0.02 11 tt 2.35 2 8 6460 tt 0.01 6 _' 2.35 209 492 ti 0.0 ti I 2.35 210 652 t ~ 0.02 8 u 2.33 211 6554 a 0.01 6 .' 2.35 212 65 5 tt 0.01 6 Z 2.3 213 6616 tt 0.0 tU tt .35 214 66 8 tt 0.02 8 2.35 21 6679 U 0.02 8 ~' 2.35 16 6710 (t 0.01 ~ .3 Lt. De osits. 216.1 6742 U 0 U t~ N A GI_M 3 Latch ~ 8:00 17 67 1 u 0.02 9 2.32 218 6781 t) 0.01 4 1 2.35 19 t) 01 ~~ 4 220 6843 tl 0.01 G I 2.34 221 68 5 U 0.01 ~ I 2.35 222 6907 U 0.01 t _' 2.35 223 69 7 t l 0.01 4 ? 2 3 224 6969 U.t)i 0.02 (3 1 2.33 2 5 7 01 (t 0.01 (~ ? 2.34 226 7031 t1 0.01 4 ; 2.33 7 7064 U 0.02 ti ~' .33 228 7094 a 0.02 I U ~' 2.34 9 7126 U 0.02 t3 ~' 2.34 230 7157 t1 0.02 t5 _' .34 231 7189 t t 0.01 4 I 2.33 232 7218 U 0.02 (S 2.33 2 3 7250 tl 0.01 4 I 2.35 234 7281 t) 0.01 ~ _' 2.33 235 7313 tt 0.01 I 2.33 236 7343 tt 0.02 t3 U 2.36 237 7374 tt 00 9 2 2.35 238 7405 tt 0.02 8 1 2.34 239 7436 tt 0.01 ~~ 1 .33 240 7467 ~ t 0.02 f> ? 2.33 241 7498 t I 0.01 (> _' 2.35 242 7529 a 0.02 ti I 2.34 243 7560 t t 0.02 i U 2. 4 244 7591 (t 0.01 6 _' 2.34 __ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 8RD Well: 3A-16 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 21, 2008 Joint No. Jt. Depth (Ft.) Pr~n. Ulsc~t Ilrn.) Pen. Body (Ins.) Pen. °io titct,~l Irx~ °„ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 245 7623 t~ 0.02 1O 2.34 245.1 7654 t) 0 O t r N A GLM 4 Latch ~ 2:00 246 7662 ct 0.02 8 2.31 Lt. De osits. 247 7693 tt 0.02 1l) U 2.33 248 7724 a 0.02 8 2.34 249 7754 a 0.0 1 t) I 2.32 250 7784 a .01 - I 2.33 251 7816 n 0.03 12 i 2.33 252 7848 U 2 11 ~ 2.34 253 7878 t t 0.01 6 :' 2.33 254 7908 ! r 0.02 1O ~ 2.32 255 7941 t) 0.02 1(1 ~ 2.33 256 7972 t ~ 0.02 1 I t) 2.32 257 8003 t 1 0.03 12 t ~ 2.33 258 8035 t) 0.01 6 .32 259 8066 t~ 0.02 t3 2.33 260 8097 t) 0.01 7 2.33 260.1 8128 t~ 0 0 U N A GLM 5 Latch ~ 1:00 261 8134 tt 0.02 8 ~ 2.32 262 8167 tt 0.01 i 1 2.32 2 3 8198 c t 0.02 1 1 2.33 264 8229 a 0.02 8 2.33 265 8 60 t) 0.02 11 -~ 2.33 266 8291 U 0.02 10 2.32 2 7 1 1 .02 fi 3 268 8352 U 0.02 1 t) ~ 2.32 269 8382 (t 0.01 7 t) 2.33 270 8413 a 0.02 £~ 1 2.32 271 8445 t) 0.03 15 :_' 32 Shallow 'tti 271.1 8475 [t 0 t) u N A GLM 6 Latch ®6:00 272 8483 l) 0.0 15 s 2.32 Shallow ittin . 272.1 8515 U 0.02 8 1 2.34 PUP 2 2. 8520 U 0 U 0 N A PBR 272.3 8532 U 0 0 O N A Packer 273 8537 t) 0.03 12 U 2.31 273.1 8569 u 0 O ! i N A GLM 7 Latch ®12:00 274 8577 ! ~ 0.03 1 a 2.32 ®Penetration Body Metal Loss Body Page 6 • ConocoPhillips Alaska, Inc. KRU 3A-16 ~ 3M16 API: 500292149200 Well T e: PROD An le TS: 47 de 8640 SSSV T TRDP Ori Com letion: 12/27!1985 An le TD: 46 de 9155 Sssv Annular Fluid: Last W/0: Rev Reason: GLV C/0 FISH (7823-1824, Reference L Ref Lo Date: Last U ate: 8/112007 OD:2.875) Last Ta : 8908 TD: 9155 ftK6 Last Ta Date: 11/62005 Max Hole An le: 54 d 3000 G Litt Cali Stri - L STRINGS as MandrelNahe Des i lion 3'ze Bo m TVD t Grade Thread 7 CONDUCTOR 16.000 0 104 104 62.50 H-40 (2548.2549, SUR. CASING 9.625 0 4074 3184 36.00 J-55 I PROD. CASING 7.000 0 9135 6424 26.00 J-55 Gas Litt Tubi Strin -TUBING MandrelNalve Size To Bottom ND Wt Grade Thread 2 5115 5116 2.875 0 8756 6163 6.50 J-55 SRD ( - , I Perforati Sum a G LiR Interval TVD Zone S1Ht s Ft SPF Date T e Comment as MandrelNalve 8666 - 8682 6102 - 6113 C-1 UNIT B 16 12 1/13/1986 IPERF 5" HJII C Gun' 90 de h 3 (6743-6744, 8800 - 8826 6193 - 6211 A-4,A-3 26 5 7/2/1986 RPERF 2 1/8" Bar Kone II; 0 deg. hasin I 8842 8860 6222 - 6234 A-2 18 8 7/2/1986 RPERF 2 1/8" Bar Kone IP 0 de h 8860 - 8900 6234 - 6262 A-2 40 4 1/13/1986 IPERF 4" HJ II Cs Gun' 90 de h Gas Lift Mandr elsNeives St MD ND Man Mfr Men Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2548 2266 Merla TMPD GLV 1.0 BK 0.125 1260 6/212007 2 5115 3816 Merla TMPD GLV 1.0 BK 0.156 1305 6/212007 3 6743 4811 Merla TMPD OV 1.0 BK 0.250 0 6/212007 4 7655 5408 Merla TMPD DMY 1.0 BK 0.000 0 6/222007 5 8128 5732 Merla TMPD DMY 1.0 BK-2 0.000 0 6/6/1996 6 8475 5970 Merla TGPD DMY 1.5 RK 0.000 0 11/92005 Produc ' on Ma n rels/Va lves St MD ND Men Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 7 8569 6035 Merla TMPD DMY 1,0 BK-2 0.000 0 12/28/1996 Closed PBR 8 8639 6084 Merla TMPD CV 1 0 BK-2 000 0 0 8/312004 OPEN (8520.8527, 9 8717 6137 Merla TMPD CV . 1.0 BK-2 . 0.000 0 8/312004 OPEN oD:2.a7s) Other u ui .etc. -JEWELRY De th D T Descri lion I 1823 1731 SSSV Baker'FVL' 2.312 PKR 8520 6001 PBR BOT 2.500 (8532-8533 8532 6010 PKR BOT'HB' w/X0 3.000 , OD:6.75t) 8736 6150 PKR BOT'1B' 3.250 8748 6158 NIP Camco'D' Ni le NO GO 2.250 8755 6163 SOS BOT 2.441 8756 6163 TTL 2.441 Fish - FISH De fh pescri lion Comment 8700 GRAPPLE ONE-HALF OF 7/8" GRAPPLE LOST'"' SOMEWHERE?? "• DOWNHOLE General Notes Date Note P~~10^ M d lN l 10/15/ 1997 NOTE: "Bell DN GLM 8475"• an re a ve 8 (8639.8640, Perf (8666-8682) Production ' MandrelNalve 9 (8717-8718, PKR (8736-8737, OD:6.151) NIP (8748749, OD:2.875) TUBING (0.8756, OD:2.875, ID:2.441) Pert (8800-8826) Pert (8842-8860) 3A-16 (PTD 1852840) Report of suspect TxIA communication • Regg, James B (DOA) From; NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, June 12, 2008 2:37 PM ~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3A-16 (PTD 1852840) Report of suspect TxIA communication Attachments: 3A-16 90 day TIO plot.jpg; 3A-16 schematic.pdf Tom & Jim, Page 1 of 1 Kuparuk gas lifted producer 3A-16 (PTD 1852840) was reported to have suspect TxIA communication. While performing a Gas fi t'fi work and installing a new gas lift design, a suspected leak around sta # 6. At this time it has not been determined if the GLV is the source of the leak. The TIO prior to the slickline work was 350/870/280. The well is currently shut in and waiting for E-line to perform a Leak Detect Log. If repairing the leak requires more work other than replacing a gas lift valve, the appropriate paperwork will be submitted upon repair. Attached is a schematic and a 90 day TIO plot. «3A-16 90 day TIO plot.jpg» «3A-16 schematic.pdf» ~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/5/2008 KRU 3A-16 PTD 185-284 1400 1200 1000 800 a 600 400 200 0 TlI/t~ P I crt - 3A-'I ~ ....................................................................................................................................1.;.. ~: .. . - _ _ _ _ --- '' I '~~, 01-Apr-08 01-May-08 d~t~ 01-Jun-OS 200 150 • a. E 100 ~ 0 z 50 0 ~~ ~~ r CanacaPhillps Alaska, Inc. 3A-16 SSSV -- (1823-1824, ---_ _- KRU 3A-16 _ - ~~ API: 500292149200 Well T e: PROD An le TS: 47 de w So4i1 SSSV T e: TRDP Ori Com letion: 12/27/1985 An le TD: 46 de 9155 Annular Fluid: Last W/O: Rev Reason: GLV CIO FISH Reference Lo Ref Lo Date: Last U date: 8/11/2007 Last Ta : 8908 TD: 9155 ftK6 Last Ta Date; 11/6/2005___ Max Hole An le: 54 deg @ 3000______ Lift G Casing String -ALL STRINGS ----._ .__... as MandrolNalve - DeSCrI tion Size TO Bottom TVD Wt Grade 1 CONDUCTOR 16.000 0 104 104 62.50 H-40 (25as-25as, SUR. CASING 9.625 0 4074 3184 36.00 J-55 PROD. r.ASINr_, 7 nnn 0 Q1'tF 8424 2&nn J-55 _ -- Tttbf(i SfrlR E -TUBING Gas Lin g ~ -- Mandrewalve ° _ Size Top Bottom TVD I Wt ~ Grade Thread 2 ~ _ 2.875 I U ~ ts75b ~ 6163 ~ fi.SU I J-55 I tSRD (51155116, ( _ Perforations Summary _ Interval TVD Zone Status Ft SPF Date T e Comment Gas Lift MandrelNalve = 8666 - 8682 6102 - 6113 C-1 UNIT B 16 12 1!13/1986 IPERF 5" HJII Cs Gun; 90 r 3 - 8800 - 8826 6193 - 6211 A-4,A-3 26 5 7/2/1986 RPERF 2 1/8" Bar Kone II; 0 c (s743-s7aa, ~ hasin ': PBR (8520-8521, OD:2.875) PKR (8532-8533, OD:6.151) Production MandrelNalve 8 (8639640, Perf (8666682) Production MandrelNalve 9 (8717-8718, PKR (8736-8737, OD:6.151) NIP (8748-8749, OD:2.875) TUBING (0-8756, OD:2.875, ID:2.441) Perf (8800-8826) Perf (8842-8860) 8842 - 8860 6222 - 6234 A-2 18 8 7/2/1986 RPERF 2 1/8" Bar Kone II; 0 de h RR62 - Ronp 6234 - 6262 A-2 40 4 1/13/1986 IPERF 4" HJ II Cs Gun; 90 de h Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr _ V Type _ V OD Latch Pon TRO Date Run Viv Cmnt 1 2548 2266 Meda TMPD GLV 1.0 BK 0.125 1260 6/21/2007 2 5115 3816 Meda TMPD GLV 1.0 BK 0.156 1305 6/21/2007 Production Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V VD Latch Port TRO Date Run Vlv Cmnt 7 8569 6035 Merla TMPD DMY 1.0 BK-2 0.000 0 12/28/1996 Closed 8 8639 6084 Meda TMPD CV 1.0 BK-2 0.000 0 8/31/2004 OPEN 9 8717 6137 Merla TMPD CV 1.0 BK-2 0.000 0 8/31/2004 OPEN Other (plugs, equip., etc.) -JEWELRY I 8756 16163 I TTL I ___ I 244.1 Fish -FISH _ _ __ _-_-. ~_ De th Description _ Comment 8700_ C_;RAPFI_E __ ON_E_-HALF OF 7/8" GRAPPLE L ~~ST ;OME ,HERE"' C _~'S~' h1-ALE General Notes Y`7 ..._° ~- (pa^ouJe~l 'oop j! peB!SSel~Ur'l)le!~uepguoc) peg!SSelOUrl X SO ~O-Z-~ ped B~ rl~l~l SAS SO ~0-/_-~ pecl Vg rl~l~t sas :~,u9LuqoeR¥ seJnl!eJ 0 eJnl!eJ ~ suop, oedsu! esnoqlle~ 6 ~ '~ueuodu~oo Z:~ 'Slle~ 9 'peal ~!~ na~ 's3,ueuod[uoo 9~ 'Slle~ 8 'ped YS 'Ple!.-I Je^!EI >lmedn>l aql u! sped Bg ~ Vg le 6u!lsal SAS lenuue !uJes eql pessaup. 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I5©cl -~iNOZ.~©H ~ '3fl~L 38V S3DN~'I$1G 3N'- NOI.L?-3.c -2 -Z -I g'.9 ti'at II CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (2) Loc (/~'---- (2 thru 8) , , ..",/ ...~ ..~ ._ '(8) " (:~) Admin ¢...... "/' :~'4'5' (9' thru 12) 10. (10 and 1'2) / 12. (13' thru (22 thrt(26) (6) Add: 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO ., 1. 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 6. Is well to be deviated and is wellbore plat included ... .~']___ 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait .......................... (-~--- REMARKS Does operator have a bond in force ................... , .............. ~ ~ Is a conservation order needed .... . Is administrative approval needed . Is the lease number appropriate .. ~__ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... j~f~' Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~¢Y~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: Gaology: Eng}r~eering: :cs ,"/W'.' JAL ~ rev: 03/13/85 6.011 I INITIAL GEO. ONIT ON/OFF '. CLASS STATUS AREA NO. SHORE POOL 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. 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