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Home My WebLink About184-051MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2A-03 KUPARUK RIV UNIT 2A-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/01/2024 2A-03 50-103-20025-00-00 184-051-0 W SPT 5845 1840510 1500 1760 1760 1760 1760 40 40 40 40 4YRTST P Adam Earl 5/19/2024 4-year MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2A-03 Inspection Date: Tubing OA Packer Depth 810 2500 2430 2425IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240521071726 BBL Pumped:1.5 BBL Returned:1.4 Monday, July 1, 2024 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re j� /"Zo DATE: Monday, May 11, 2020 P.I. Supervisor gg ��J �(� �'I SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2A-03 FROM: Guy Cook KUPARUK RIV UNIT 2A-03 Petroleum Inspector Well Name KUPARUK RIV UNIT 2A-03 Insp Num: mitGDC200507155414 Rel Insp Num: Src: Inspector Reviewed By: P.I, Supry J`�JIZ NON -CONFIDENTIAL Comm API Well Number 50-103-20025-00-00 Inspector Name: Guy Cook Permit Number: 184-051-0 Inspection Date: 5/6/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2A -o3 T PTD tsaoslo Type Inype Test! w TVD SsaS Tubing 1286 1289 1285 1284 Well Pt 1500 [A 250 2000 1920 1910 BBL Pumped: 1.8 jBBL Returned: '' 1.6 OA 30 _ 30 - 30 30 IntervalaYRTST P/F P Notes: Testing was done with a Little Red Services pump truck and calibrated gauges. Monday, May 11, 2020 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor ker FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 24, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. 2A-03 KUPARUK RIV UNIT 2A-03 Src: Inspector Reviewed By: P.I.Suprv,lrL Comm Well Name KUPARUK RIV UNIT 2A-03 API Well Number 50-103-20025-00-00 Inspector Name: Bob Noble Permit Number: 184-051-0 Inspection Date: 1/17/2019 InSp Num: mitRCN190117161209 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2A-03 Type Inj w ITVD 5845 Tubing 1446 1440 1438 1438 1413 111 PTD 1840510 Type Test SPT ITest psi 1500 IA 900 1 2190 - 2150. 2180 - 2190. 3I'm BBL Pumper 2.1 BBL Returned: 1.6 OA 26 26 26 26 - 26_-_ 26 Interval 4YRTST P/F P Notes: 75 min T/1/0=1433/2180/26, 90 min T/U0=1425/2180/26. Pretest injection temp was 129 F, 30 min injection temp 128 F, 60 min injection temp was 128 F, 75 min Injection temp was 127 F, and 90 min injection temp was 128 F. Thursday, January 24, 2019 Page I of I RECEIVED • a51 2'Ig•Co3`� SEP 29 2017 WELL LOG TRANSMITTAL#904203426 AOGCC To: Alaska Oil and Gas Conservation Comm. September 26, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED ivl, K BENDER RE: Leak Detect Log: 2A-03 Run Date: 7/30/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-03 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20025-00 Leak Detect Log (Processed Log) 1 Color Log 50-103-20025-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 FRS_ANC@halliburton.com Date: Signed: / va40v / ,.zo:e"""t Tji� • OF I// ,,� THE STATE Alaska Oil and Gas OfLASI�;A Conservation Commission i� _ " A s _— 333 West Seventh Avenue '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'411:A61). Fax: 907.276.7542 www.aogcc.alaska.gov Sara Heskin Associate Wells Engineer 2(t f ConocoPhillips Alaska, Inc. P.O. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A-03 Permit to Drill Number: 184-051 Sundry Number: 316-556 Dear Ms. Heskin: 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, *a/4 Daniel T. Seamount, Jr. Commissioner DATED this�i day of November,2016. RBDMS '- NOV 1 6 2016 • •• RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon U Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑., • Operations shutdownL Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q . Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 184-051 3.Address: Stratigraphic ❑ Service Li 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20025-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a . KRU 2A-03 Will planned perforations require a spacing exception? Yes ❑ No❑� / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025570 • Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7230' 6240' ' 7018' • . 6065' 1769 none 6973',7073',7100' Casing Length Size MD TVD Burst Collapse Conductor 73' 16" 110' 110' Surface 2575' 9.625" 2611' 2611' 7"Tieback 1739' 7 1774' 1774' Production 5441' 7" 7215' 6202' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6838'-6902',6898'-6902', 5940'-5984',5981'-5984', 3.5" L-80 7019' Packers and SSSV Type: PACKER:BAKER FHL RETRIEVABLE PKR Packers and SSSV MD(ft)and TVD(ft): 4 MD=6631 TVD=5796 SSSV: none PACKER:CAMP HRP-1-SP PKR • MD=6703 TVD=5846 PACKER:BAKER-FB-1 WIRELINE SET PKR A MD=7003 TVD=6054 12.Attachments: Proposal Summary ❑ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑� 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/7/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑., GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Sara Heskin @ 265-1027 Email Sara.Heskin ancop.com Printed Name Sara Heskin 265-1027 Title Associate Wells Engineer Phone /� 10/28/2016 Signature W tO �je)J\ Date: I L I I f He COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S Plug Integrity ❑ BOP Test Mechanical Integrity Test Wr Location Clearance ❑ Other: 3 0 / fV zppa ._ * l /c_ ,,4 . c 't"--.... L.-N.,' ei....e-C--0 riP 4/ ‘A 10 2--C-- Post Initial Injection MIT Req'd? Yes r-,— o ❑ ( IL I«�1�.. Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: T 111 6 /t�*-4{ RBDMS NuV 162016 APPROVED BY Approved by: 'So / COMMISSIONER THE COMMISSION RBDMS Date: /! / a//10 --em loials. €7/Z O 'I A .� (� Submit Form and Form 10-403 Revised 11/2015 p� a p (i{'dt slid for 12 months from the date of approval. Attachments in Duplicate • Nov- ConocoPhillips ' 0 Alaska O r i 201b P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 28th,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Injector 2A-03 (PTD# 184-051). Well 2A-03 was drilled and completed in 1984 as a 3-1/2"Kuparuk A and C Sand pre-produced injector.The well was put on production in November of 1984 and was converted to gas injection in March of 1985 until it was shut-in July of 1987.The well was brought online in September 1989 as a Water Alternating Gas(WAG)injector. In 2008,a gyro survey indicated corkscrewed tubing due to subsidence In 2014 a workover was completed to repair a surface casing leak caused by the subsidence damage. Selectivity was not retained post work-over. There are multiple restrictions in the wellbore due to three patches with small ID's.A workover is required to remove the ID restrictions and prepare this well for Coil Tubing Drilling(CTD) operations. The proposed rig work-over will consist of pulling the existing selective completions and installing a new selective completion with a big tailpipe to allow a whipstock to be installed for CTD operations.The motherbore. - perforations will be retained to continue infection support to the current fault block. t-� This Sundry is intended to document the proposed work on KRU 2A-03, including pulling and replacing the selective completion,and to request approval to workover the well. If you have any questions or require any further information,please call me at 265-1027 or email me at sara.heskin@conocophillips.com. Sincerely, Sev\h.. 0:4 Sara Heskin Associate Wells Engineer CPAI Drilling and Wells • • ConocoPhillips 2A-03 Proposed Workover CTD Setup: Pull Selective Completion Original PTD: #184-051 General Well Information: Well Type: Kuparuk A&C-Sand Injector MPSP: 1,769 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 11/2/14: 2,352 psi at 5,842'TVD Equivalent MW:8.2 ppg (125 psi safety factor included) Wellhead Type: FMC Gen V 5K BOP Configuration: Annular/ Pipe Rams/ Blind Rams/Mud Cross/ Pipe Rams MIT Results: 11/23/14: MIT-IA, Passed 10/23/14: CMIT-TxIA Passed Earliest Start Date: 11/07/2016 Production Engineer: Alexandra Caldelas Workover Engineer: Sara Heskin (907) 265-1027 sara.heskin@cop.com Current Well Status: Well 2A-03, a Kuparuk A-&C-sand injector, has been shut in since September of 2015 to manage injection to offset producers.This well has no integrity issues. Scope of Work: The objective of this proposed RWO will be to prepare 2A-03 for Coil Tubing Drilling(CTD).The scope of this proposed RWO will be to remove the patch ID restrictions to CTD by pulling the existing selective completion and installing a new selective completion, including a big tailpipe to allow a whipstock to be installed for CTD operations.The motherbore perforations will be retained to continue injection support to the current fault block. Summary of Proposed RWO Procedure: Proposed Pre-Rig Work: 1. Attempt to fish retrievable patches at 6,538' MD, 6,737' MD, and 6,964' MD a. If patches can be fished, cut 3-%2"tubing as close as possible to one joint above and below the blast rings at 6,851' MD- 6,941' MD. Cut depths TBD based on patch fishing results. 2. Run CBL/GR Log for lower completion depth correlation 3. Obtain new SIBHP ( C 3,11,11> OPEN ?) 4. Punch tubing at—6,559' MD for well kill circulation point 5. Set BPV • ConocoPhillips 2A-03 Proposed Workover CTD Setup: Pull Selective Completion Original PTD: #184-051 Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull BPV. Circulate KWF. Obtain SITP &SICP; if pressure is observed at surface, calculate new KWF and repeat circulation if necessary.Verify well is static prior to proceeding. 3. Set BPV, ND tree, set blanking plug, NU BOPE. &test BOPE to 250/3.000 psig low/high. 4. Pull BPV, screw in landing joint, BOLDS, & unseat tubing hanger. 5. P/U on tubing& pull tubing hanger to the rig floor.Verify well is static&TOH laying down 3-iA" upper completion from seals 6,603' MD. 6. RIH with fishing BHA and engage the upper packer at 6,631' MD and jar free. POOH and lay down packer and fishing assembly. 7. RIH with fishing BHA and engage the tubing stub at 6,670' MD and jar free. POOH and lay down tubing seals and fishing assembly. 8. RIH with fishing BHA and engage the middle packer at 6,703' MD and jar selective free. POOH and lay down packer and fishing assembly. a. If patches are successfully fished pre-rig and the tubing able to be cut,there will be two additional runs to fish the blast rings and then the tubing seals at 6,994' MD. 9. M/U packer mill and RIH to mill the lower packer at 7,002' MD. Push packer to bottom then POOH. 10. M/U casing scraper cleanout BHA and RIH to PBTD to circulate the well clean. 11. RIH with packer and test packer assembly on drill pipe. 12. Drop ball to activate setting tools, and set permanent packer at approximately 6,910' MD 13. Release the setting tools, pull up one joint, set the test packer and pressure test to confirm the lower packer is set. POOH laying down drill pipe. 14. M/U &TIH with new 3-%2" selective packer and upper completion as per design to just above the bottom packer. 15. Spot corrosion inhibited brine in tubing and IA to just above the new packer. 16. Fully locate poor boy overshot and pick up 1'to space out. 17. Pressure up to set packer at approximately 6,660' MD. 18. Pressure test IA to 3000 psi to verify packer is set properly. 19. Shear seal assembly from PBR, slack off to fully locate and space-out seals into existing PBR, mark-pipe at surface. 20. Lay-down two joints, space-out with tubing pups, M/U tubing hanger. 21. Spot corrosion inhibited brine in IA, land hanger, & RILDS. 22. Pressure-test tubing to 3,500 psi & IA to 3,000 psi. Bleed the IA&then the tubing. Ramp up the IA pressure to shear the SOV. 23. Back-out landing joint& install BPV. 24. ND BOPE, install blanking plug, NU tree, & pressure test tree. 25. Remove BPV. 26. Freeze protect well through SOV. 27. Set BPV. 28. RDMO RWO Rig. 1/ r•R • s ConocoPhillips 2A-03 Proposed Workover CTD Setup: Pull Selective Completion Original PTD: #184-051 Proposed Post-Rig Work: 1. Pull BPV. 2. RIH ,d set catcher on top of CA-2 plug body in nipple profile. 3. Run gas.I esign &swap SOV for DV. 4. Retrieve catcher then CA-2 Plug 5. Reset well house(s) & re-attach flow line(s). 6. Turn well over to operations. #11 •',.7 • ` KUP INJ ° Ce't 2A-03 ConocoPhillips m Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl ci MD(ftKB) Act Btm(ftKB) ,,,,,,,,p,,,,p, 501032002500 KUPARUK RIVER UNIT INJ 48.37 5,77500 7,230.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date • 2A-03,12/7/201411:07:12AM SSSV:NIPPLE Last WO: 40.40 4/27/1984 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date •• ••• Last Tag:E-LINE 6,640.0 12/29/2013 Rev Reason:NOTE UPDATE lehallf 12/7/2014 HANGER',34.9- Aw2s using Strings - -- - - - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND) Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 37.0 110.0 110.0 65.50 H-40 Welded � ; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread SURFACE 9 5/8 8.765 36.0 2,611.4 2,611.1 36.00 J-55 BTC Na..Casing Description OD(10) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread 7"Tieback 7 6.276 34.9 1,774.0 1,773.9 26.00 L-80 TC II Lasing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 34.9 7,214.5 6,201.9 26.00 J-55 BTC .AA/CONDUCTOR,37.0-110.0: II .r.Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/21 2.9921 34.9 6,678.81 5,829.11 9.30 L-80 EUEBrd mod NIPPLE;529.8 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Corn (in) • • 34.9 34.9 0.00 HANGER FMC TUBING HANGER 3.500 ( 529.8 529.8 1.13 NIPPLE 'CAMCO DS NIPPLE ' 2.875 6,601.8 5,776.2 46.82 LOCATOR BAKER SEAL ASSEMBLY LOCATOR SUB 2.970 6,602.8 5,776.9 46.83 SEAL ASSY BAKER SEAL ASSEMBLY W1"7 ft STICK-UP" ' 3.000 7"Tieback;34.9-1,774.0 - 6,609.1 5,781.2 46.92PBR BAKER POLISH BORE RECEPTACLE 80/40 2.980 -i 6,631.1 5,796.2 46.86 PACKER BAKER FHL RETRIEVABLE PACKER - 2.930 6,652.9 5,611.2 46.06 NIPPLE CAMCO DS NIPPLE 2.812 SURFACE.36,0.2.611.4 6,670.5 5,823.4 46.42 OVERSHOT BAKER POORBOY OVERSHOT W/7.84'SWALLOW 3.020 • AND 1'SPACEOUT I. Tubing Description String Ma...ID(in) 'Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection PATCH;6,538.0, TUBING-original 41/2 2.992 6,670.0 7,019.41 6,065.9 9.30 J-55 FL4S ABMOD GAS LIFT;6,547.4 Completion Details 1111 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 6,685.5 5,833.7 46.50 SBR CAMCO 2.937 • 6,703.2 5,846.0 46.38 PACKER CAMP HRP-1-SP PACKER 2.867 LOCATOR;6,601.8 6,850.9 5,948.5 45.83 BLAST RINGS BLAST RINGS(3) 2.992 SEAL ASSY;6,602.8 PBR;6,809.1 ';...4 PACKER;6,631. 6,994.5 6,048.6 45.83 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 7,002.8 6,054.3 45.83 PACKER BAKER FB-1 WIRELINE SET PACKER 4.000 7,005.3 6,056.1 45.83 SBE SEAL BORE EXTENSION 2. NIPPLE;6,652.9 _ 7,015.2 6,063.0 45.83 NIPPLE CAMCO'D'NIPPLE 2.75,0 7,018.7 6,065.4 45.831 SOS CAMCO SHEAROUT SUB 2.937 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) OVERSHOT;9670.5 Iill Top(ND) Top Incl Top(ftKB) (ftKB) r) Des Com Run Date ID(in) 3 6,538.0 5,732.6' 47.04'PATCH Set WFT Straddle Patch Assy OAL 23' 11/2/2014 1.810 SBR;6,695.5 .- - 6,737.0 5,869.3 46.19 PATCH Set D&D straddle pack across GLM 7/29/2001 1.500 PACKER;6,703.3 6,964.0 6,027.3 45.83 PATCH Set D&D straddle pack across GLM '7272001 1.500 6,973.0 6,033.6 45.83 FISH Spear Left in Mandrel FISH:.615 Spear Left in top 3/31/1995 INJECTION;6.743.31 P L No Go Sub of Latch GLM k 4 PATCH;6.737.0 7,073.0 6,103.3 45.83 FISH 1"DMY Empty Pocket;Fell to Rathole 429/1995 7,100.0 6,122.1 45.83 FISH Cut TBG TAIL Below FB-1 Pkr/SBE on 7/11/89;See 12/4/1999 0.275 INJECTION;8,812.9 WSR 9/22/97-ELMD END-OF-TUBING @ 6982', SWS IPROF 12/4/1999 Camco'D'NO GO Nipple; - CUT OFF 7/11/89 Camco SOS;CUT OFF 7/11/89 IPERF;6.836.0-6,902.0-r a' IPERF;6.898.0-6,902.0li ^ Perforations&Slots Shot G Top Dens hots/F Top(ftKB) Btm(9K13) _ (ftKB)KB) Btm(ND) (s(ftKB) Zone Date t) Type Com I 6,838.0 6,902.0 5,939.5 5,984.1 C-4,2A-03 6/18/1984 12.0 IPERF 5.5"Csg Gun,120 deg. ph 6,898.0 6,902.0- 5,981.3 5,984.1 C-4,UNIT B, 6/11/1984 4.0 IPERF 4"JJ II Csg Gun 2A-03 IPERF;6,966.0-6,968.0 L _ 6,966.0 6,968.0 6,028.7 6,030.1 UNIT B,2A- 6/15/1984 4.0 IPERF 4"Csg Gun FISH;6,973.01 03 PATCH;8,964.0. INJECTION;6,973.1I 6,993.0 6,997.0 6,047.5 6,050.3 A-5,A-4,2A- 6/11/1984 4.0 IPERF 4"JJ II Csg Gun, 03 Squeezed Perfs on li 6/14)84 6,997.0 7,016.0 6,050.3 6,063.5 A-4,2A-03 6/18/1984 4.0 IPERF 4"Csg Gun,90 deg. IPERF;6,993.0-6,997.0 J ,; phasing SEAL ASSY;6,994.5 51 ® 7,030.0 7,074.0 6,073.3 6,104.0 A-3.2A-03 6/18/1984 4.0 IPERF 4"Csg Gun,90 deg. PACKER;7,002.81 J - phasing PERE;6,997.0-7,016.0,_. '•= SBE;7,005.3 . Cement SQueezes Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (51(13) (ftKB) Des Start Date Com _ 6,993.0 6,997.0 6,047.5 6,050.3 Cement Squeeze 6/14/1984 NI LE;7,015.3 me _ st Mandrel Inserts St SOS;7,018.7- _ a. Ott on Top(TM Valve Latch Port Size TRO Run -- N Top(ftKB) (ftKB) Make Model OD(in) SewType Type (In) (psi) Run Date Com IPERF;7.030.0.7,074.0- 6,547.4 5,738.9 CAMCP KBMM 1 12 GAS LIFT SOV Broken 0.000 0.0 9/14/2014 DCK-2 FISH;7.073.0411 II 2 6,743.2 5,873.6 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 10/11/1999 FISH;7,100.0---1118 3 6,812.9 5,922.0 CAMCO -KBUG 1 INJ DMY 'BK 0.000 0.0 10/11/1999 4 6,973.0" 6,033.6 CAMCO •KBUG 1 INJ DMY 'BK 0.000 0.0 3/31/1995 PRODUCTION;1,774.0-7,214.5 FMC Gen IV 2A-03 ConocoPhillips Kuparuk A & C-Sand Injector Post RWO CTD Setup Design 16"62.5#H-40 WLD, 110' MD, -IP-4- { 7"26#L-80 TCII Tie-Back, 1774'MD --► 9-5/8"36#J-55 BTC,2611' MD —pC - �--a 6930'MD, 3-1/2" 9.3#L-80 EUE-8RD-AB MOD Tbg -1 11/02/14 Last BHP Measurement: 2352 psi at 6698' MD, 5842'TVD -t 6719' MD, 3-1/2"x1 1/2"MMG GLM 6794' MD,7"x 3-1/2" Packer WI 10'80/40 PBR Assembly -_i _�f 6816' MD,3 1/2"x 2.812" nipple Kuparuk C-Sand Perforations * 4 6827'-6907'MD, 3-Y2" Blast Joints 1984-6838' -6902'MD —IP -- 6911'MD,7"x 3-1/2" Packer w/5'80/40 SBE Kuparuk B-Sand Perforations 6928' MD, 3-1/2"x 2.81" nipple 1984-6966'-6968'MD 00 4 6931' -7015' MD,5-1/2" Big Tail Pipe C Kuparuk A-Sand Perforations C Squeezed 1984-6993'-6997'MD - C 1984-6997'-7016' MD —� C _ 1984-7030'-7074' MD FISH, 7073' MD —14 FISH,7100' MD i--�► 7" 26#J-55 BTC,7215' MD I Date: I 02-Nov.-2016 I Drawn By: Sara Baskin S • ' Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Tuesday, November 08, 2016 2:10 PM To: 'Heskin, Sara E' Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2A-03 RWO(pre CTD- PTD 184-051) Sara, You are good to go then. If you decide to start injecting fluids before the CTD sidetrack a witnessed MIT-IA will be required after stabilized injection. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Heskin,Sara E [mailto:Sara.E.Heskin@conocophillips.com] Sent:Tuesday, November 08,2016 1:40 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: KRU 2A-03 RWO(pre CTD-PTD 184-051) Hi Guy, Thank you for taking the time to review the 2A-03 Sundry. I have answered your questions below in red. Please let me know if you need any more information. Sincerely, Sat/wife/slat/I, Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office: 907-265-1027 sara.heskin cr conocophillips.com From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Monday, November 07,2016 11:21 AM 1 To: Heskin,Sara E<Sara.E.Heskin@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]KRU 2A-03 RWO(pre CTD- PTD 184-051) Sara, I am covering for Victoria while she is gone for the month of November. In reviewing your sundry application to do a RWO on 2A-03 a couple questions came up: 1) Provide a proposed schematic for the well after the RWO is completed See attached schematic 2) What do you mean by"a larger tailpipe will be installed for whipstocks" (the current min ID is 2.75" in D nipple)??The attached schematic should help clarify this question. I apologize for not including it in the original submittal. CTD uses whipstocks to exit the motherbore with coil tubing.A big tail pipe (brand name WearSox) is a 5-1/2" OD liner designed to have whipstocks set in the ID.Typically we have 3-1/2"tubing as the tail of our completion, but the 5-1/2" OD gets the name "big tailpipe" because it's larger than the conventional tubing.The whipstock is set post-rig workover.This is the typical completion for our Coil Tubing Rig Workover setups and has be previously used in many Kuparuk CTD wells. 3) Are you planning on restarting injection after the RWO before the CTD operations start? Yes,the asset plans to inject prior to CTD. 4) Is the MPSP based on A sand pressure or C sand or both?The MPSP of 1,769 psi is the combined A and C sand pressure, based on the most recent pressure survey on 11/2/14. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:'his e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.aov). 2 • • Lc) NJ a) Z O LO . .� V z CLO 4-' n3 > C Y O -0 Q3 w w4 CC 0 v) * > �oZ V 4. a c O O ..il ,<,_ Oc�m n5 Y Y C O > ro a p i `��cc 0 0 0 0 co 0 0 o (0 (0 F3- co N O L J a t7 l l l l l l l l _ O 000000000750 > L O N _ � � L N .� 0 0 0 0 0 0 0 0 0 0 0 ° m cn C W N M •47N 0 N 0 0 0 1111 Z. 0 E co U C L Z.^ 9;:Q N N N N N N N M M M U -6 , LO c Z N j Q O C . 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IlIn N U) ICL) UI() If) In Ln I( ISI 0 C co• z Ln o yuo ta) uL a) - E ) on az nw m E Eaa u a W V it t122 12 6.1 aj t N U) M a N CO O N M Y N C Y i d H ho .„j, z o NO .,-. 0 a+ E aJ v v J J } X N m a 7 .;.c E CO VI N .0 CL a N W r N N N N V) Z y O O O y .i �` 3 i = c, E E t� a F- a a F F • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 09,2016 TO: Jim Regg I +I SUBJECT: Mechanical Integrity Tests P.I.Supervisor bee ( t CONOCOPHILLIPS ALASKA INC 2A-03 FROM: Johnnie Hill KUPARUK RIV UNIT 2A-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry zIE — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A-03 API Well Number 50-103-20025-00-00 Inspector Name: Johnnie Hill Permit Number: 184-051-0 Inspection Date: 5/7/2016 Insp Num: mitJWH160508213611 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2A-03 - Type Inj N'TVD 5845 - 'TubingT 1910 H 1910 - 1910 - 1910 4 PTD 1840510 - Type Test SPT Test psi 1500 IA 210 2810 - 2720 2700 Interval 4YRTST - P/F P v OA 20 20 - 20 20 - Notes: 2.3 bbls of diesel SCANNED SEP 2 7 2016 Monday,May 09,2016 Page 1 of 1 Imaf~roject Well History File' CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J ~- ~'~' /' Well History File Identifier RESCAN DIGITAL DATA [3 Color items: [] . Diskettes, No. /~p~ayscale items: D Other, No/Type or Quality Originals: .~ B Other: ~, , NOTES: BY: BRENVINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other DATE: /S/ BY: BEVERLY BR~SHERYL MARIA LOWELl. DATE:7-'~ Isl Scanning Preparation x 30 = + = TOTAL PAGES BY: BEVERLY BREN ~'NCEN,,.~ SHERYL MARIA LOWELL DATE//,)~ IS~ ~. Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: eY: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES NO BEVERLY BREN VINCE~'~-HER~MARIA LOWELL (SCANNING IS COMPLETE AT THIS PO E~IT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVlOUAL PAGE BASIS DUE TO QUALff¥, GRAYSCALE OR COt. OR IMAGES) ReScanned (individual page [special attention] scanning completed) III I IIIIit11111 I]1 III IIIIIIIII III III RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScan ned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: $~( Dpi FILE # ~~~-_ ~~ To request anylall of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 2:05 PM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 -- message 3 Here is the latest addition to the email trail. 20. 2A -03 - AA 2B.050 issued 6/9/2010. 19. 1Y -10 - AA 2B.041 issued 03/11/2009. Well last injected 01/10. 18. 1Y-09 - AA 2B.051 issued 05/20/2010. 17. 1Y-08 - AA 2B.056 issued 10/22/2010. Well last injected 04/07. Are there plans to return the well to operation? 16. 1Y -05 - AA 2B.0015 originally issued 09/12/06, revised 10/21/08. 2 year RST required (condition 3). Original RST 09/01/08, next RST 07/13/10; report "automatically" submitted by Halliburton. Since the RST is a requirement of the AA, the report should be submitted by Problem Wells. 15. 1Y -04 - Last injected 07/09. 7/5/09 email stated intention to keep on injection for diagnostics and possibly apply for AA. Apparently diagnostic results were inadequate for AA. 14. 1Q-11 - AA 2B.058 issued 11/02/2010. I need to review condition 3 of AA for revision. F : Maunder, Thomas E (DOA) Sent. uesday, January 04, 2011 10:53 AM To: NSK ell Integrity Proj Cc: 'NSK Pro. -m Well Supv' Subject: RE: C. '.coPhillips Monthly Injector Report - Dec 2010 All, I am continuing to review t : December Monthly Injector report. I am - ough a total of 13 wells. I wanted to send this latest message due . what I have found or not found on 01-02B. As I continue to work through the report, I plan to send interim mes ses as I get 7 - 10 new wel . eviewed. Call or message with any questions. 13. 1Q-02B - Well name is 1Q-02B. Well las • i• - cted 9/10. I do not show having received any specific notification /request in June, 2010 regardin. i well. There is an email in the file from 4/20/10 reporting diagnostics accomplished to that time cont.. ing a st. -ment that you intend to return the well to injection and remove it from the waiver report in May 12. 1L-05 - AA 2B.054 issued : 22/2010. Well last injected ; 10 11. 1 L -03A - Well name • 1 L -03A. Permit to Drill # is 199 -037. MI : failed 09/25/2010. Well last injected 9/10. 10. 1G-01 - , B.035 issued 7/30/2008. 9. 1F-16:' - Well name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to hay- . assed since. Well last inject :. 4/2007. AA 2B.018 was issued in October 2007, but no injection has occurred int. e well. Looking at th: .ressure plot, it is shown that the IA pressure appears to have been bled off in October an. ovember. Was 1/4/2011 • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM t75\4— s To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 . . ConocoPhillips Well 2A -03 Injection Data • Tbg Psi IA Psi • OA Psi 4000 3500 - 3000 - .°' 2500 - Q a 2000 - ••• 1500 • • 1000 •• ••••w.• 500 • 0 - — - 09/10 10/10 11/10 12/10 01/11 Date PTD 184 -051 AIO 2B.050 issued 6/9/10 Reason: Surface casing leak 5/15/2009 MITIA passed on 05/27/10 AIO 2B.050 requires any pressure bleeds to be reported monthly. No pressure bleeds have occurred in the past month • • ConocoPhillips Well 2A -03 Injection Data • Water Injection • Gas Injection 4000 3500 1 3000 a 2500 to 0. a 2000 M 1500 • • 1000 jot idPie 500 0 1 0 2000 4000 6000 8000 10000 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 2749 0 1164 497 61 30- Dec -10 3929 0 1199 491 60 29- Dec -10 3975 0 1199 472 60 28- Dec -10 3912 0 1188 464 61 27- Dec -10 3877 0 1186 473 61 26- Dec -10 3854 0 1184 475 61 25- Dec -10 3772 0 1171 502 62 24- Dec -10 3848 0 1180 504 62 23- Dec -10 3889 0 1183 499 62 22- Dec -10 3889 0 1181 556 64 21- Dec -10 3875 0 1184 559 63 20- Dec -10 3942 0 1195 525 63 19- Dec -10 3855 0 1180 507 62 18- Dec -10 3784 0 1170 527 62 17- Dec -10 3782 0 1171 564 63 16- Dec -10 3739 0 1167 584 63 15- Dec -10 3835 0 1181 602 64 14- Dec -10 3661 0 1170 625 63 13- Dec -10 5940 0 1602 676 63 12- Dec -10 9326 0 2011 640 63 11- Dec -10 9246 0 1980 651 63 10- Dec -10 9297 0 1975 600 62 9- Dec -10 7033 0 1635 600 61 8- Dec -10 3317 0 1137 442 60 7- Dec -10 3350 0 1143 512 62 6- Dec -10 3377 0 1145 536 62 5- Dec -10 3403 0 1147 520 62 • • 4- Dec -10 3395 0 1141 504 62 3- Dec -10 3519 0 1157 438 60 2- Dec -10 3456 0 1140 432 61 1- Dec -10 2686 0 1012 499 63 30- Nov -10 2160 0 924 454 62 29- Nov -10 2037 0 900 454 62 28- Nov -10 2042 0 904 434 62 27- Nov -10 2117 0 918 433 62 26- Nov -10 2217 0 936 472 63 25- Nov -10 2219 0 943 520 64 24- Nov -10 2261 0 947 400 64 23- Nov -10 2212 0 941 400 70 22- Nov -10 2217 0 927 500 70 21- Nov -10 2060 0 901 500 60 20- Nov -10 697 0 817 450 50 19- Nov -10 2336 0 1028 600 75 18- Nov -10 3426 0 1182 600 75 17- Nov -10 3413 0 1177 547 61 16- Nov -10 3382 0 1167 547 60 15- Nov -10 3385 0 1165 590 60 14- Nov -10 3346 0 1161 602 60 1 13- Nov -10 3329 0 1156 642 61 12- Nov -10 3429 0 1173 625 61 11- Nov -10 3442 0 1175 567 59 10- Nov -10 3422 0 1167 549 58 9- Nov -10 3414 0 1162 593 58 8- Nov -10 3398 0 1160 568 59 7- Nov -10 3525 0 1157 511 58 6- Nov -10 3392 0 1151 466 58 5- Nov -10 3405 0 1153 421 57 4- Nov -10 3385 0 1145 466 57 3- Nov -10 3349 0 1143 442 58 2- Nov -10 3301 0 1133 442 57 1- Nov -10 3290 0 1131 445 57 31- Oct -10 3324 0 1136 453 57 30- Oct -10 3334 0 1136 438 54 29- Oct -10 3267 0 1122 750 51 28- Oct -10 3211 0 1105 550 52 27- Oct -10 3370 0 1134 550 51 26- Oct -10 3529 0 1159 668 51 25- Oct -10 3462 0 1145 626 50 24- Oct -10 3462 0 1138 598 49 23- Oct -10 3374 0 1120 593 49 22- Oct -10 3147 0 1083 559 49 21- Oct -10 3067 0 1066 575 49 20- Oct -10 3042 0 1059 598 49 19- Oct -10 3025 0 1049 546 48 18- Oct -10 3051 0 1044 584 48 17- Oct -10 2976 0 1023 552 47 16- Oct -10 2948 0 1011 578 46 15- Oct -10 2959 0 1010 596 46 14- Oct -10 3017 0 1020 637 46 • # 13- Oct -10 3248 0 1065 596 46 12- Oct -10 3216 0 1049 563 46 11- Oct -10 3236 0 1043 576 45 10- Oct -10 3312 0 1050 595 44 9- Oct -10 3571 0 1092 596 42 8- Oct -10 3694 0 1103 591 39 7- Oct -10 3691 0 1098 554 38 6- Oct -10 3701 0 1089 554 37 5- Oct -10 3707 0 1080 537 36 4- Oct -10 3713 0 1068 450 34 3- Oct -10 3714 0 1055 450 35 2- Oct -10 3742 0 1033 529 32 • • Page 1 of 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] ~~~ ~~Z~do Sent: Saturday, June 05, 2010 8:19 AM To: Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: KRU Pre AA MIT's Attachments: KRU 2A-03 05-27-10.x1s; KRU 1Y-09 05-20-10.x1s Tom, Attached please find MIT forms for Pre AA MIT's on 1Y-09 (PTD183-052) and 2A-03 (PTD 184-051). AA request will follow in a separate email followed by hard copy. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 6/15/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Kuparuk River Unit - 2A 05/27/10 Ives & Mouser AES C~ r Packer Depth Pretest Initial 15 Min. 30 Min. Welt 2A-03 ~ Type Inj. N TVD 5,845' Tubing 950 975 975 975 Interval O P.T.D. 1840510 Type test ~P Test psi ' 1500 Casing 745 3,000 2,925 ' 2,900 P/F P Notes: Diagnostic MIT prior to applying for AA OA 40 40 40 40 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 2A-03 05-27-10.x1s • • ~~Q~~ 0~ p~Q~~{Q /~..M...«~o~~~. ADMINISTRATIVE APPROVAL AIO 2B.050 Ms. M.J. Loveland Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 RE: Request for Administrative Approval KRU 2A-03 (PTD 1840510) Kuparuk River Oil Pool Dear Ms. Loveland: ~: ~* In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Well diagnostics confirm the well has a surface casing leak at a depth of about 120 feet. CPAI does not propose to repair the well at this time however intends to continue to evaluate possible repair/remediation possibilities. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 2A-03 exhibits at least two competent barriers - tubing/packer and production casing - to the release of well pressure. As part of the diagnostic testing, the well passed the standard inner annulus pressure test. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 2A-03 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall limit the inner annulus pressure to 2000 psi and the outer annulus pressure as low as practicable; AIO 2B.050 • • June 9, 2010 Page 2 of 2 4. CPAI shall perform a mechanical integrity test of the inner annulus every 2 years to the maximum anticipated injection pressure; 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is May 27, 2010. DONE at Anchorage, Alaska and dated June 9, 2010. The Alaska Oil ~~G~ Daniel T. Seamount, Jr. K. N Commissioner, Chair Com ' Conservation Commission Cathy . Foerster Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within ]0 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 5, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: • RE~E~VED JUN 0 Q 2010 Alaska Oii ~ Gas Gees. Gortrnission Ancl~erage ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing we112A-03 (PTD 184-051) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or Perry Klein at 659-7043, or Brent Rogers /Martin Walters at 659-7224. Sincerely, %~~ ~~~ ~'~ C2--~ MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 2A-03 (PTD# 184-051) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with a known surface casing leak for Kuparuk injection well 2A-03. Well History and Status Kuparuk River Unit we112A-03 (PTD# 184-051) was drilled and completed in 1984 as a producer and converted to a service well in January 1985. 2A-03 was reported to the Commission on 05/15/09 with a suspected subsidence related surface casing leak. Diagnostics were conducted which verified the surface casing to formation leak to is approximately 120' below the surface (conductor shoe is at 110' RKB). A passing MIT1A was conducted on 05/27/10. Considering that the leak is too deep to access via excavation, the well will require a workover or an alternate repair technology to remediate. ConocoPhillips requests an AA to continue water only injection until the well can be repaired. Barrier and Hazard Evaluation Tubing: The 3-1/2" 9.3# J-55 tubing has integrity to the Packer @ 6703' MD based upon a passing MITIA to 3000 psi on 05/31/09 and 05/27/10. Production casing: The 7" 26# J-55 production casing has integrity to the Packer @ 6703' MD based upon a passing MITIA to 3000 psi on 05/27/10. The production casing is set at 7212' and has an internal yield rating of 4980 psi. Surface casing: The well is completed with 9-5/8" 36# K-55 surface casing in the upper portion of the hole with an internal yield pressure rating of 3520 psi. The surface casing is set at 2612' MD and was arctic packed in 1984. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including ashut-in of the well. T/IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Well Integrity Supervisor 6/3/2010 • Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every 2 years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum). 3. IA pressure not to exceed 2000 psi (40% internal yield). 4. OA pressure will be maintained as low as hydrostatic pressure allows. 5. Submit monthly reports of daily tubing & IA pressures, injection volumes, and any pressure bleeds on any annuli. 6. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification Well Integrity Supervisor 6/3/2010 2 ConocoPhilfips ,1ld~p. ~. Irr',. ••• Well Con -?A-03.11/17/, Schametlc - A< CONDUCTOR, 0-110 SAFETY VALVE, 1,903 SURFACE, 0-1,671 GAS LIFT, 6.896 SBR, 8,686 INJECTION, 6.%93 PATCH t, 8,737 KU P 2A-03 I Attributes x M le & MD TD Wellbore API/UWI Flaltl Nanw 501032002500 KUPARUK RIVER UNIT Well Stetus INJ ProM PWI nJ Type Inc! (°) MD (fiKB) 47.55 5,800.00 Act elm (kKB) 7,230.0 C omment SSSV: LOCKED OUT H25 (ppm) 0 DaW 7/1/2008 Annotahon End Dsta Last WO: KB-Ord (k) 40.40 Rig Release Oete 4127/1984 A nnotation Depth (kKB) End Gb Annotation End Date Last Tag: 7,058.0 6/28/2002 Rev Reason: FORMAT UPDATE 17/11/2008 Casln Strin s Gsing Descnptlon CONDUCTOR String 0. 16 .. Sldng ID ... 15.063 Top (ftKB) 0.0 Sat Depth (f... 110.0 Set Depth (TVD) ... 110.0 SW ng Wt.. 65.50 String ... HAO String Tap Thrd Welded Gsing Descriptlon SURFACE SMng 0. 9518 .. SMng ID ... 8.765 Top (ftKB) 0.0 Set Depth (/... 2,612.0 Sal Depth (TVD) ... 2,611.8 String Wt... 36.00 String ... J-55 String Top Thrd Gsing Deacrip0on Slrtng 0. .. Siring ID ... Top (kK8) Set Depth (f... Set Depth (ND) ... Siring Wt... String ... String Tap Thrd PRODUCTION 7 6.151 0.0 7,212.0 6,199.5 26.00 J-55 Tubin Strin s Tubing Daecriptlon StHrp 0... SMng ID ... TUBING 31/2 2.984 Top (kKB) 0.0 Sel Daplh (/... Set Depth (ND) ... 7,009.7 6,058.5 SMng W1... SMng ... 9.30 J-55 String Top Thrd EUESrdABMOD Com letion Det ails r..., revo~ Top Depth (ND) IkKBI Top Inc! 1°I u.°,° raa..innnn Cemmonl ID Iinl Top (f[KB) InKe) (°) Oeecdptlon Comment Run Deto ID 11n) 6,737.0 5,868.7 46.19 PATCH 1 Set D8D straddle pack across CSM 729101 7/29/2001 1.500 6,964.0 6,026.7 45.83 PATCH 2 Set DSD straddle pads across CSM 727/01 7/27/2001 1.500 6,973.0 6,033.0 45.83 FISH Spear Left in Mandrel FISH:.615 Spear Left in top No Go 3/31/1995 Sub of Latch GLM N 4 7,073.0 6,102.7 45.83 FISH 1" DMY Empry Pocket; Fell to Rathde 4/2911995 7,100.0 6,121.5 45.83 FISH Cut TBG TAIL Below F&1 PkrlSBE on 7/11/89; See WSR 12/411999 0.275 9/22!97- ELMDEND-0F-TUBING @ 6982', SWS IPROF 17/4/1999 Camco'D' NO GO Nipple; CUi OFF 7/11/89 Cameo SOS; CUT OFF 7/11/89 Btm IPERF, 8,898L,902 IPERF, - -_ 8.908$.968 - - FISH, 8,973 A PATCH 2. 8,984 I W ECTION, 6,973 IPERF, - - 8,993E,997 - _ Squeeza Perfe. _ -_ 8,993 - SEALASSY = wAOCATOR, - - 6,995 PACKER, 7,003 - _ IPERF, 8,997-7,018 _ SBE, 7,005 = FISH, 7,0]3 FISH. 7.100 PRODUCTION, 0-7,212 TD.1130 on Sfert Data IStn ITOO IfIKBII ( K9) I IP1 Make I Model (Oin) I Sorv TyM I TYIM S^a; ITR PsRunl Run Deta (Comm... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Kuparuk River Unit - 2A 05/27/10 Ives & Mouser AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2A-03 Type Inj. N TVD 5,845' Tubing 950 975 975 975 Interval O P.T.D. 1840510 Type test P Test psi 1500 Casing 745 3,000 2,925 2,900 P/F P Notes: Diagnostic MIT prior to applying for AA OA 40 40 40 40 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 2A-03 05-27-10.x1s • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 17, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Magnetic Thickness Tool (MTT): 2A-03 Run Date: 1/20/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-03 Digital Data in LAS format, Digital Log Image file, Casing Inspection repc 1 CD Rom 50-103-20025-00 d 1~t45r aK'Y ttl~~.!V ° ~~ y, ~ V PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIlVG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael. b arreto ~ hahbtli=ton. com U~r~r~~-t-OS~ 1 `jG/~~ Date: ~ Signed: { ~' l ~ i'~ ' 2A-03 (PTD 184-051) Report o~ leak to formation • Page 1 of 1 Regg, James B (DOA) From: Sent: NSK Problem Well Supv [n1617@conocophillips.com] Friday, May 15, 2009 2:14 PM '~ ~~~I ~I~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2A-03 (PTD 184-051) Report of SC leak to formation Attachments: 2A-03 schematic.pdf; 2A-03 90 day TIO plot.jpg Jim, Kuparuk WAG injector 2A-03 (PTD 184-051) has a surtace casinq leak to formation. Diagnostics have identified the casin lea an 120'. The TIO during the test was 2725/500/70. The well will be shut in and freeze protected. It will remain SI while a plan forward is developed. Prior to the well being returned to service, an AA application or the appropriate paperwork will be submitted at that time. Attached is the schematic and a 90 day TIO plot. .% 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 «2A-03 schematic.pdf» «2A-03 90 day TIO plot.jpg» ~~l~~i ~ Y:y '~. c rks..~. .'-`.'~d f < <- - 7/28/2009 KRU 2A-03 PTD 184-051 5/15/2009 TIO Pressures T/VO P l ot - 2A-03 2000 200 150 1500 ~~,.~--~~~. . . . . . ~~/ _~_:F.__ .-~-~~~ <.~ . . . . . . . . . . . a ~ 100 ~ Y O r t~ ~ o. 1000 500 ~ . . ................................................................................................................................................. ~......~... j .........................................................................................j........ ~.. - 0 I ~ i i~ i~ _, i 15-Feb-09 28-Feb-09 13-Mar-09 26-Mar-09 08-Apr-09 Date 21-Apr-09 04-May-09 50 ~ ~ • ~a '~lips . ~~: ; ~ KUP 2A-03 ~' ~~~ttfe~' ~ ~ a ~~ , ' ~i~ ~~ ;° ' A~t$1&~+~k , a'1'~ ~'y~4ik~ ~ ~ Wellbore API/UWI Field Name ~~~ Well Stahs P~oMnj Type Incl (°) MD (itKB) Aet Btm (ftKB) 501032002500 KUPARUK RIVER UNIT INJ PWI 47.55 5,800.00 7,230.0 Comme~rt H2S (ppm) Dah Mnotation End Date KB-Grd (R) Ri9 Release Date SSSV: IOCKED OUT 0 7/t/2008 Last WO: 40.40 4/27/1984 AnnotMion Depth (RKB) End Drte AnnotMlon Entl Dffie Last Tag: 7,058.0 6/282002 Rev Reason: FORMAT UPDATE 12/112008 r,t.'iI~ ~t~.;s ~{ .- ,a : ~ ~ , ~ ~ i iii~Ci ~~ ~~ i' ~ , i, ~. ~ ; m_" __ ` ; - _ »_. '. Cesireg Deacriptlon String 0... String ID .. . Top (MCB) Set Depth (f... Sot Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.063 0.0 110.0 710.0 65.50 H-40 Welded Caaing Descriptlon String 0... String ID .. . Top (ftNB) Sat Depth ~f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 0.0 2,612.0 2,611.8 36.00 J-55 Casing Dascription Strfng 0... String ID .. . Top (ttKB) Set Depth (f... Sat Dapth (TVD) ... String Wt... String ... 3tring 7op 7hrd PRODUCTION 7 6.151 0.0 7.212.0 6,199.5 26.00 J-55 ~`i R§~~ i~ _ , ~. ,, y r~ ~~~ r r Fr . ~ ~k~~ ~~~,i~ ~ _ ~ _ ~ Tubing Deacription String 0... String 10 .. . Top (ttKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING 31/2 2.984 0.0 7,009.7 6,058.5 9.30 J-55 EUE8rdABMOD ~ B'~'1~~4 ~t!'~l~ = ~ = ~' ~ ~ '~ ~ ' m T "r - - Top Depth ~ND) Top Incl Top (RKB) (nKB) (°) Item Deacriptlon Comme~rt ID (in) 34.9 34.9 0.00 HANGER GRAY GEN III TUBING HANGER 3.50f 1,9432 1,9432 0.49 SAFETY OTIS FMX 3.5" SAFETY VALVE (LOCKED OU~ 2.81~ VALVE GAS LIFf, 6,648 SBR, 6,686 ~ ~ (T~~) Top Ind i. 7~ ~p~{g) (ftK8) (°) pescription Commant Run Data ID . u 6,737.0 5,868J 46.19 PATCH 1 Set D&D straddle padc across CSM 7/29/01 7/29/2001 1, j~; 6,964.0 6,026.7 45.83 PATCH 2 Set D8D straddle pack across CSM 7/27/01 7/27/2001 ~1. INJECTION, ~ 6,9~3.0 6,033.0 45.83 FISH Spear Leh in Mandrel FISH: .615 Spear Left in top No Go 3l31/1995 6.743 PATCH ~, 6 737 Sub ot Latch GLM # 4 , 7,073.0 6,102.7 45.83 FISH 1" DMY Empty Pocket; fell to Rathole 4/29/1995 7,100.0 6,121.5 45.83 FISH Cut TBG TAIL Below FB-1 PW/SBE on 7/11/89; See WSR 12/4/1999 0. 9/22KJ7- ELMD END-0F-TUBING @ 6982', SWS IPROF ~ 12/4/1999 Camco'D' NO GO Nipple; CUT OFF 7/1189 - Camco SOS; CUT OFF 7/11/89 INJECTION. 6 813 M y ~ ~. ~~ a i t E •t; ~ t. . -_ _ ~ ~-~ i ~~ ~ p~ ' . " ~ ~IIC ~ ~~ .FI .~-~ ir4 . - r 1 ~ - ~ - " a~~ 1~~ - I l d 't ~ ~ ~ Shot _ Top (N D) Btm (ND) ~e~ i.,~ ~k~ca~ 5m. ~hKe~ IRKBI (RKBI Zone Date (sh~~~ Tvoe Co mmeM IPERF, ~ fi.B3Bb.902 ~ ~ ~ IPERF, ~ ~ 6,898b,902~ ~ ~ ~ IPERF, - h - ~ 6,9666,968 - I~ - j:, - - FISH, fi,973 PATCH 2. 6,993.0 6,997.0 6,046.9 6,049.7 A-5, A-4, 2A-03 6/11/7984 4.0 IPERF 4" JJ II Csg C;un, Squeezetl Nerts on 6/14/84 6,997.0 7,016.0 6,049.7 6,062.9 A-0, 2A-03 6/18/1984 4.0 IPERF 4" Csg Gun, 90 deg. phasing 7,030.0 7,074.0 6,072.7 6,103.4 A-3, 2A-03 6/18/1984 4.0 IPERF 4" Csg Gun, 90 deg. phasing (ND) (ND) (ftKB) (RKB) Deseriotion ShrtDate CommeM (~) I Make I Motlel I O^ I Serv I 7ype I 7ype I ~~~; ITRP Runl Run Data I Comm... MEMORANDUM • TO: Jim Regg ~ _ P.LSupervisor ~ ~ ~ ~~13~~`~ FROM: John Clisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 07, 2008 SUBJECT: Mechanical Integrity Tests COri'OCOPHILLIPS ALASKA INC 2A-03 KUPARUK RIV CiNIT 2A-03 Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. SuprvJna"- Comm Well Name: KUPARL'K RN UNIT 2A-03 'i InSp Num: mitJCr080504082717 Rel Insp Num: API Well Number: 50-I03-20025-00-00 Inspector Name: John Crisp Permit Number: I84-osl-o ~~ Inspection Date: si2.zoos Packer Depth Pretest Initial 15 Min. 30 Min. 45 NTin. 60 Min. i 2A-03 - -T ---- - -- -- ' , 5845 Well; ___ _TypeInJ. I ~' ~ TVD ~ IA Soso z7zo 2660 ~ z64o --- P.T. is4o~IO LTYPeTest sPT ~ Test psi ! zoo OA so so so ,-_ so T -- -- Y-----, -- r- Interval aYRrsT p~F P - Tubing z3oo z3oo z3oo z3oo NOteS' 3.1 bbl's pumped for test. Wednesday, May 07, 2008 Paee I of I • f Alaska P.Q. -BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK-99501 C L ~ 1~~ I v - s ~~,~ ~ ~,. - l ~ r~ ~ / 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. 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 farm 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor __ _ _ __ • ®C~ ~~~~iS IS ~~CQ Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant 1'op-off Report of Sundry Operations (10-404) Datp Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12/14/2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 ZA-03 184-051 44" na 44" na 50 12/14J2f~7 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3.5 12!14/2007 2A-05 184-067 SF na SF na 5 12/5/2007 , 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14/2007 2A-0$ 185-248 SF na SF na 3 1215/2007 2A-09 186-001 SF na SF na 1.75 .12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A~-13 185-144 SF na SF na 1.75 12!1412007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 ZA-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9/24/2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 MEMORANDUM TO: Jim Regg Pol. Supen'i!ior ~¿.-, ({ZCi/cA { ( FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 2A-03 Insp Num: mnCS040621122049 Rei Insp Num: State of Alaska Alaska Oil and Gas Consen'ation Commission DA TE: Wednesday. June 23. ::!OO4 SlIBJECT: I\.lechanicallntegTlt)' Tests CONOCOPHlLLLPS ALASi-:..A fNC ~A-03 i-:.UPARUK RIV UNIT ~A-03 Src: Inspector NON-CONFIDENTIAL Re\.ie".ed By: Pol. Supn' 5&- Comm API Well Number: 50-103-::!O025-00-00 Permit Number: 184-051-0 Inspector Name: Chuck Scheve Inspection Date: 6/20/2004 Packer Dept h Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2A-03 Type Inj. S TVD 6240 IA 880 2400 ~370 2370 P.T. 1840510 TypeTest SPT Test psi 1.\61 ~5 OA 80 80 80 80 Inten'al ,\'fRTST P/F P Tubing 1700 1700 1700 1700 Notes: The pretest pressures were observed for 30+ minutes and found stable. \Vell demonstrated good mechanical integriT)'. Wednesday. June 23,2004 Page I of 1 Ph...LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 16, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2A-03 (184-051) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the tubing patch operations on the KRU well 2A-03. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooneyv Wells Team Leader Phillips Drilling MM/skad OO T 1 7 200~ Alaska Oil & Gas Cons. Anchorage Commission ORI ®lf',, AL PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Dethlefs Phone (907) 263-4364 Fax: (907) 265-6224 November 14, 2002 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 2A-03 (184-051) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the tubing patch operations on the KRU well 2A-03. If there are any questions, please contact me at 263-4364. Sincerely, J. Dethlefs Kupamk Problem Well Supervisor JD/skad RECEIVED NOV 1 4 2002 .,~aska Oil & Gas Cons. Commissior, Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development__ RKB 130 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 4681' FNL, 5052' FEL, Sec. 13, T11N, R8E, UM (asp's 498621, 5960018) 2A-03 At top of productive interval 9. Permit number / approval number 1444' FSL, 1460' FWL, Sec. 24, T11N, R8E, UM 184-051 / At effective depth 10. APl number 50-103-20025 At total depth 11. Field / Pool 1676' FNL, 3663' FEL, Sec. 24, T11 N, R8E, UM (asp's 500011, 5957745) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7230 feet Plugs (measured) true vertical 6212 feet Effective depth: measured 7070 feet Junk (measured) true vertical 6101 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 200 sx CS, 110' 115' SUR. CASING 2482' 9-5/8" 750 sx PF E, 250 sx PFC 2612' 2612' PROD. CASING 7082' 7" 350 sx Class G 7212' 6200' Perforation depth: measured 6838!: L6902', 6966'! 6968,; 6993, _ 7016', 7030' - 7074' true vertical :5939' ~ 5984'; 6028i ~ 6029':~6047, i-6063', 6073' - 6103' R E C E IV E D : : : Tubing (size, grade, and measured depth) :3-1/2!;9i3#i j;55Tbg:@i 7008! MD.: NOV 1 4 2002 Alaska 0il & Gas Cons. C0mmig~i0r, Packers & SSSV (type & measured depth) CAMCO: HRP~li @ 6703,1MD; BAKER 'FB-I' @ 6992' MD; Anchorage : : :ii:ii ,:! : OTIS 'FMX~:@; 1943! MD, : ::: .: 13. Stimulation or cement squeeze summary Intervals treated (measured) : ::; : ' ': ;: ~ N/A Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation . . . . . N/A - Subsequent to operation : :: ;i :i: : i: N/A - 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X : : O,,' Gas__ Suspended __ Service_ XX W'~ ~ / 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jerry Dethlefs 26F-4364 Signed ~'/~-~'~ ~--~ ~ Title: Kuparuk Problem Well Supervisor Date //,//~/O~-- Jerry Dethlef/ Prepared b)/ Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2A-03 Event History 05/22/02 06/28/O2 06/29/02 LOG STRADDLE PACK ASSEMBLIES W/SWS MEMORY TOOL @ 6699' & 6925' SLM. [LEAK DETECT- PATCH] DRIFT THROUGH D & D PACKOFFS W/1.37" @ 6699' RKB & 6925' RKB. TAG FILL @ 7058' RKB, EST 16' OF FILL. [TAG, LEAK DETECT-PATCH] LEAK DETECT W/PONY TAIL FROM 6955' SLM TO 6700' SLM (INJ RATE 1400 BPD/1 BPM). SLIGHT 150# WT. INCREASE @ 6729' SLM, ESTIMATE 30' INSIDE UPPER D&D PACK OFF. [LEAK DETECT-PATCH] Page 1 of I 11/12/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X Casing Patch 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4681' FNL, 5052' FEL, Sec. 13, T11 N, R8E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Servi~__X (asp 's 498621, 5960018) 6. Datum elevation (DF or KB feet) RKB 130 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2Ao03 At top of productive interval 1444' FSL, 1460' FWL, Sec. 24, T11N, R8E, UM At effective depth At total depth 1676' FNL, 3663' FEL, Sec. 24, T11 N, RSE, UM (asp's 500011, 5957745) 12. Present well condition summary Total depth: measured true vertical 7230 feet Plugs (measured) 6212 feet 9. Permit number / approval number 184-051 / 10. APl number 50-103-20025 11. Field / Pool Kuparuk Oil Pool Effective depth: measured true vertical 7070 feet Junk (measured) 6101 feet Casing Length CONDUCTOR 110' SUR. CASING 2482' PROD. CASING 7082' Size Cemented 16" 200 sx CS II 9-5/8' 750 sx PF E, 250 sx PFC 7" 350 sx Class C Measured Depth 110' 2612' 7212' True vertical Depth 110' 2612' 6200' Perforation depth: measured 6838'-6902', 6966'-6968', 6993'-7016', 7030'-7074' true vertical 5939'-5984', 6028'-6029', 6047'-6063', 6073'-6103' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-551-bg @ 7008' MD. Packers & SSSV (type & measured depth) CAMCO 'HRP-I' @ 6703' MD; BAKER 'FB-I' @ 6992' MD; OTIS 'FMX' (LOCKED OUT) @ 1943' MD. RECEIVED OCT 1 ? 200I Alaska Oil& Gas Cons, Comrnission Anchorage 13. Stimulation or cement squeeze summary I~tervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OikBbl N/A N/A Representative Dally Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations ._X Oil __ Gas __ Suspended __ Service _X Water Injector. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,/<', ~,~/~' ~ ~/ /~/~' //J~>7~/ Title Wells Team Leader Michael Mooney Questions? Carl Mike Mooney 263-4574 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2A-03 Event History 06/14/01 06/15/01 06/16/01 06/23/01 06/27/01 TAGGED FILL @ 7070' RKB. EST.4' FILL. DRIFTED TBG W/2.745"BROACH. IN PROGRESS. [TAG] BROACHED TBG TO 2.795. UNABLE TO GET DUMMY DRIFT TO DEPTH. IN PROGRESS. DRIFTED TBG W/14' DUMMY PATCH (2.765" X 18"TOP, 2.75" X 11 "BTM). SUSPECT ANNULAR COMMUNICATION AS WELL AS C SAND LEAKS. [LEAK DETECT-PATCH] MITIA (ABORTED), LEAKING RING GASKET ON CASING HANGER [MAINTENANCE, MIT, PT TBG-CSG] MITIA, PASSED [MAINTENANCE, WH MAINTENANCE] 07/27/01 SET 3' X 25' D & D STRADLE PACK ASS'Y ACROSS LOWER CSM @ 6973' RKB, UPPER SEAL ELEMENT @ 6964' RKB, LOWER SEAL ELEMENT @ 6987' RKB (MINIMUM ID THRU ASS'Y 1.5") IN PROGRESS. [LEAK DETECT-PATCH] 07/28/01 RUN KOT TO STA-2 TO PIN-POINT PRECISE DEPTH OF MANDREL BTM (6714' SLM). SET AD-2 TBG STOP @ 6725' SLM. A'I-I'EMPT TO SET D&D PACKER (UNSUCCESSFULLY...IS SETTING DOWN HIGH , OR GETTING PUSHED UP HOLE BY C-SANDS, @ 6714' SLM AND 6716' SLM ON CONSECUTIVE RU 07/29/01 COMPLETE SET OF STRADDLE PACKOFF ACROSS CSM# 2. TBG ROSE FROM 1450# TO 1750# INDICATING C-SANDS ARE ISOLATED. Page I of I 10/12/01 / P.T.D.I I Notes: MEMORANDUM TO: Dan seamount 'Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: Jeff Jone~' ~-~ state of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept. 1, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 2A Pad ?.A-01A, 2A-02, 2A-03, ZA-04, 2A-06, 2A-08, 2A-20, 2A-21,2A-23 Petroleum KRUlKuparuk River Field Inspect°rNON' CONFIDENTIAL Packer Depth ~ Pretest In,al 15 Min. 30 Min; ~-°~^ l~'n~'l ~ I~'v'~' I~:1 ~u~'"°l ~0° I ~°° I ~°° I~°° I'nte~va~l 4 184057o ITYPetestl P I Testpsil~ 1449 I CasingI 520 I 176°1 17601 1760 I PIE 'l P P.T.D.I Notes: WellI 2A-03 - P.T.D.I 1840510 Notes: WellI 2A-04 P.T.D.I 1840530 Notes: P.T.D.~ 1840640 Notes: Well[ ' 2A-08 P.T.D.I 1852480 Notes: WellI 2A-20 P.T.D.I 1931510 Notes: WellI 2A-21 P.T.D.I 1931330 Notes: WellI 2A-23 P.T.D.I 1931420 Notes: '2A-02 I Type~nJ.I s IT.V;D- I 5~oo I Tubing l 27401 27501 27501 2750 I lntervall 4 1840500 ITypetestl P ITestpsil 1450 I CasingI 575 I 1710 I 1700 I 1710 I PIF I P I TypelnJ. I G I T.V.D. I5845 ITUbingl3550I 3500 I ~00 I ~00 I lntervall 4 ITypetestI P I Testpsil 146'i IcasingI 1160I 1675I 1610I 1610I P/F'I P 'lT~"ni'l ~ IT'v'~'I ~ ITu~'~I ~00i ~001 ~1 ~S I lntervall 4 ITypetestl P.I TestPsiJ 1453 ICasingI 1150I 1690I 1680I 1680I P/F'I P I Type~nj.IG I:T.v.D- I 5773 I'Tubingl 3~50 I36°° '1 36°° I 36°0 I lnter~a~l 4 [Type testIP I TestpsiJ 144'3 I CasingI 1650I 2200 'l 2200 [ 2200 I PIE I --P J Typelni. I s IT'vID- I 5785 ITubingJ 2f251 2725J 2725J 2725 I~ntervall 4 ITypetgstl p JTestPsil'1446 I casingl 95o I 1625J 1825 I 1625 I PIE I P- I .~,~.1 ' s' i T.vlo. I 5786 I Tubingl 2850 I =eso 1%5ol 2e5o l lntervall 4 Type testJ P I-TestpsiJ 14~7 JCasingJ 1175l 17001 17251 17101-P/F I P I~.,.j.I s"1 ~.v.o. I 5774 I Tubingl 27°°l 27°° l'27°°1 27oo I,.~.~a~l ~" J TypetestJ PJ TestPsiI 1444 JCasingl 60O J 1720 I 1725 I 1725I P/F I P I~.e~"J-IS I~'v'°' I 5785 ITuU"gl ~25 I ~501 ~501 ~50 I~n~.~.~l ~ JTypetestJ p I TestpsiI 1441 J CaSingJ 6OO I 165°1 161°1 1600 I PIE I P Type INJ. Fluid Codes F = FRESH WATER INJ. G -- GAS INJ. S = SALT WATER INJ. N = NOT INJECTING i Type Test M= Annulus Monitoring ' P= Standard Pressure Test R= Internal RadioactiveTracer sUrvey A= TemPerature Anomaly Survey D= Differential Temperature Test Test's Details- Interval I= Initial Test 4= Four Year Cycle · V= Required by Variance W= Test during Workover O= Other (describe in notes) Wednesday, Atm. 30- 2001): I traveled to Phillips Alaska Iuc.,s KRU 2A pad to witness the 4 year MITs on wells # 0lA, 0A, 03, 04, 06, 08, 20, 21, 23. Jerry Dcthlcfs was the PlA reP. In charge of testing. Thc standard annulus pressure test was performed with all nine wells passing the 30 minute pressure tesL Summary: I witnessed nine successful MITs on PIA's KRU 2A Pad. . MJ.T.'s perfOrmed: ~_ Number of Failures: Attachments: Well schematics (It) O_. Total Time during tests: 8 hrs cC: MIT KRu 2A 8-30-00 JJ.xis MIT report form 5112/00 L.G. 9/5/00 · ' STATE OF ALASKA AI_~ OIL AND GAS CONSERVATION COMMISSI°N REPORT OF SUNDRY WELL OPERATIONS Suspend - 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Abandon Alter casing _ Repair well_ Plugging _ Change approved program_ Pull tubing _ 5. Type of Well: Operation Shutdown_ Re-enter suspended well Time extension Stimulate Variance Perforate Other X 6. Datum elevation (DF or KB) 99510 Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 597' FSL, 227' FWL, SEC 13, T11N, R8E, UM At top of productive interval 1444' FSL, 1460' FWL, SEC 24, T11N, R8E, UM At effective depth 1618' FSL, 1579' FWL, SEC 24, T11N, R8E, UM At total depth 1676' FSL, 1627' FWL, SEC 24, T11N, R8E, UM 130' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-03 Snubbing 9, Permit number 84-51 10. APl number 5o-103-20025 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7230' feet Plugs (measured) true vertical 6240' feet NONE measured 71 31 ' feet Junk (measured) true vertical 61 4 1 ' feet NCNE Length Size Cemented Measured depth True vertical depth I 10' 1 6" 200 SX CS II I 10' I 10' 2612' 9 5/8" 750SXPFE 2612' 2612' 25O SX PFC 7 21 2' 7" 350 SX CLASS C 7 21 2' 6 2 01 ' measured 6997'-7016'M 7030'-7074', 6838'-6902' true vertical 6048'-6061 ', 6071 '-6102', 5993'-5982' Tubing (size, grade, and measured depth) 3 1/2", J-55, @ 6987' Packers and SSSV (type and measured depth) BAKER HRP-1 @6670', BAKER FB-1 PACKER @ 6970', OTIS FMX SSSV @ 1910 ECElVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure snub and fish tools J U L 2 3 '{993 Alaska .0il .& Gas Cons. Commission '~n~_hnr~n~ 14. Pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data ........... OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing 2000 500 2400 2000 500 2400 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil ~__ Gas Suspended Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned C,~L)- ~ Title Kuparuk PetroleumEnc~ineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 05/01/89 TO 12/31/89 CPF-2 DS-2A 2A-03 05/06/89 RAN LIB & TAGGED FISH @ 1910'. LIB SHOWS INTERNAL FISHING NECK IS SPLIT. 06/09/89 COMPLETED RIGGING UP HWO UNIT, RIH & TAG FISH @ 1943' RKB, ESTABLISH CIRCULATION, RDFN. 06/10/89 MILLED ON FISH W/ HWO UNIT. 06/11/89 RAN 2" OVERSHOT, DID NOT LATCH FISH. RAN 2.8" MILL, MILLED APPROXIMATELY 6". RDFN. 06/12/89 RAN 2" OVERSHOT, DID NOT LATCH FISH. RAN 2." MILL, MILLED APPROXIMATELY 6". RAN 2" OVERSHOT, DID NOT LATCH. 06/13/89 RAN 2" MILL, WOULD NOT TORQUE UP. PUMPED 50 BBL GD TO CIRCULATE UP CUTTINGS. RAN 2.75" LIB, SHOWS JUNK OR METAL ON TOP OF FISH. RAN 2.6" HYD BAILER. NO RESULT. RDFN. 06/14/89 MILLED 3" W/ FLAT BTM HILL, 2.7" OD. RIH W/'2" ID HOLLOW MILL, APPEARS TO HAVE STARTED OVER XO BELOW FISHNECK, GAINED 1 1/2' WITH HOLLOW HILL. POOH, RDFN. 06/15/89 MILLED 7" W/FLAT BOTTOM MILL (2.67"OD). TRIED TO PULL FISH W/2.0" ID OVERSHOT. LOST GRAPPLE, CONTROL RING & 2" OF SKIRT IN WELL. RDFN. 06/16/89 RAN MAGNETS & HYDROSTATIC BAILER. RECOVERED SOME SMALL PIECES. MILLED 1" W/HWO IN 3 HRS. RDFN. 06/17/89 LATCHED FISH W/3" JDC W/CORE REMOVED. BEAT FISH UP TO UPPER POLISHED BORE @ 1905' WLM, THEN BEAT BACK DOWN TO 1913'_WLM. LEFT JDC IN WELL ON FISH. RDFN. 06/18/89 PULLED BULLDOG SPEAR RUN ON 9/24/88 W/SNUBBING UNIT. RECOVERED APPROXIMATELY 40% OF OVERSHOT SKIRT LOST ON 6/14/89. RDFN. 06/19/89 RECOVERED X-LINE FISH NECK ADAPTER LOST 10/27/87. RECOVERED APPROXIMATELY 20% MORE OF BOWEN OVERSHOT IN SMALL PIECES THAT WAS LOST 6/14/89. RDFN. 06/20/89 MILLED DOWN 2-1/2" ON FISH W/ 2.0" HOLLOW HILL. RAN 2" OVERSHOT. COULD ONLY PULL 2000# BEFORE SLIPPING OFF OF FISH. RDFN. 06/21/89 LATCHED FISH. LOST 1-7/8" GRAPPLE IN WELL. RAN MAGNET AND GRAB TO FISH GRAPPLE - NO LUCK. RDFN. 06/22/89 MILLED OVER 1-7/8" BASKET GRAPPLE. SET OBANNON OS ON F~i~~ o.. os IV OBANNON OS STILL ON FISH. RDFN. 06/23/89 'RIH W/1-3/4" BOWEN, LATCH FISH. JAR @ 19000#, 20 PER HR./H1 199 INCREASE RATE TO 40 PER HR, NO LUCK. RDFN. A~as~aOil.& Gas Cons. Commissio~ Anchorage 06/24/89 JAR @ 29,000#, NO GAIN, INCREASE PULL TO 30000W, FISH PULLED UPHOLE 6', HUNG UP AGAIN. JARS QUIT, POOH, SEAL RUPTURED. REPLACE JARS, RIH & LATCH FISH, JAR @ 19000#, NO GAIN, JARS QUIT, ROTATE OFF, POOH. RDFN. 06/25/89 JAR FOR 5 LICKS, FISH CAME UP 10". JAR AGAIN, LOST ALL DRAG POOH TO CHECK TOOLS, BLOWN SEAL ON JARS. RECOVERED OBANNON OS. SKIRT SPLIT AND 2 GRAPPLE TIPS LEFT ON FISH. RIH, COULD NOT LATCH FISH, POOH. RIH W/ 2.7" HILL TO 1945'. CIRCULATE @ 1/4 BPH.. SECURE WELL, RDFN. 06/26/89 HILLED 6-1/2" OF FISH. LOST FISH DOWNHOLE. TAGGED W/ WL @ 6650' RKB. TIGHT SPOT @ 1949 RKB. RDFN. 06/27/89 RAN 2.72" LIB, FOUND TIGHT SPOT @ 6665' RKB. RAN 2.25" LIB, BEAT THROUGH TIGHT SPOT @ 6665', TAGGED FISH @ 6978' RKB. RAN 2.8" GR, HIT TIGHT SPOT @ 1914, BROACHED W/2.7" BROACH TO 6669'. TIGHT SPOT @ 6650' RKB, WORK THROUGH SEVERAL TIMES, BUT STILL TIGHT. JOB SUSPENDED. 06/28/89 RAN CCL TO DETERMINE FISH DEPTH. FOUND FISH @ 6977' RKB. 07/09/89 RAN CLEAN UP HILL THROUGH TIGHT SPOTS AT SSSV, SBR. TAGGED FISH AT 6979' RKB W/ SL. 07/10/89 HILLED 14" OF FISH, TAGGED FISH W/ SL AT 6978'. 07/12/89 CUT TBG BELOW BAKER FB-1 PACKER AND SEAL BORE EXT. RIH W/CCL TO 6985' RKB, TBG CLEAR. 07/21/89 ATTEMPTED TO RUN FXE SSSV. UNABLE TO ESTABLISH HYDRAULIC CONTROL DUE TO LOWER PACKING BORE DAMAGE. GOOD CLOSURE TEST SHOWS GOOD SEAL @ UPPER PACKING BORE. SUSPEND JOB. 08/13/89 CONVERTED FROM PRODUCER TO WAG. 08/25/89 PREP WELL FOR WI. RELACED OU ABOVE TOP PKR W/ DV. PRESS TEST ANNUL TO 2000 PSI. REPLACED C SND DV'S @ 6973' & 6813' W/ HFCV S. RAN OTIS INJECTION VALVE, PRESS TEST GOOD. 12/16/89 THAWED ICE PLUG IN FLOWLINE W/IMPEDENCE HEATER. WELL BACK ON WI. JUL 2 ~Ta-8_Na_Oij & Gas Cons. Commissio,~ ~nchorage STATE OF ALASKA /'3 ALASKA OIL AND GAS CONSERVATION COMMISSION REPOR___ T OF S.._ U_NDRY WELL OPERATIONS on _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program Pull tubing _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) 1. Type of Request: Abandon 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory _ 130' RKB feet Stratigraphic_ 7. Unit or Property name Service X_ Kuparuk River Unit 8. Well number 2A-03 INJECTOR 9. Permit number 84-51 10. APl number sod 03-20025 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 4. Location of well at surface 597' FSL, 227' FWL, SEC 13, T11N, R8E, UM At top of productive interval 1444' FSL, 1460' FWL, SEC 24, T11N, R8E, UM At effective depth 1618' FSL, 1579' FWL, SEC 24, T11N, R8E, UM At total depth 1676' FSL, 1627' FWL, SEC 24, T11N, RSE, UM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7230' feet Plugs (measured) true vertical 6240' feet NONE measured 71 3 1 ' feet Junk (measured) true vertical 61 4 1 ' feet NONE Length Size Cemented Measured depth True vertical depth I 10' 1 6" 200 SX CS II 1 10' 1 1 0' 261 2' 9 5/8" 750SXPFE 261 2' 261 2' 250 SX PFC 721 2' 7" 350SXCLASSC 721 2' 6201 ' measured 6997'-7016'M 7030'-7074', 6838'-6902' true vertical 6048'-6061', 6071'-6102', 5993'-59 Tubing (size, grade, and measured depth) 3 1/2", J-55, @ 6987' Packers and SSSV (type and measured depth) BAKER HRP-1 @6670', BAKER FB-1 PACKER @ 6970', OTIS FMX SSSV @ 1910' 13, Stimulation or cement squeeze summary A__las~a 0il .& Gas Cons. C0rn~issi0~ Intervals treated (measured) ;Anchorage Treatment description including volumes used and/fina, I pressure install injection valve 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 2000 500 2400 2000 500 2400 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run M Water Injector __ Daily Report of Well Operations Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service WAG Signed C-[J'-)' ~ Form 10-404 Rev 06/15/88 Title Kuparuk Petroleum En~lineer Date SUBMIT IN DUPLICATE "~'~ STATE OF ALASKA ", AL, ~ OIL ANDGAS ~SERVATION ~b, ,ON ~ J~ REPORT OF SUNDRY WELL OPERATIONS" __ Stimulate X Plugging Perforate 1. Type of Request: Operation Shutdown Pull tubing Alter casing Repair well Pull tubing 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 897' FSL, 227' FWL, Sec 13, T11N, R8E, UM At top of productive interval 1444' FSL, 1460' FWL, Sec. 24, T12N, R8E, UM At effective depth 1618' FSL, 1579' FWL, Sec. 24, T13N, R8E, UM At total depth 1676' FSL, 1627' FWL~ Sec. 24, T13N, R8E, UM 12. Present well condition summary Total Depth: measured 7 2 3 0' feet true vertical 6240' feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-03 //~ ~' ~ ~ F c~/"- 9.84-51Permit nu~er/a~prova~..~u~Tr 10. APl number 5o-103-20025 11. Field/Pool Kul3aruk River Oil Pool Effective depth: measured 71 31 ' feet true vertical 6 141' feet Junk (measured) Casing Length Size Structural Conductor I 1 0' I 6" Surface 261 2' 9 5/8" Intermediate Production 7 21 2' 7" Cemented Measured depth True vertical depth 200 Sx CS II 1 10' 1 10' 750 Sx PF E & 261 2' 2612' 250 Sx PFC 350 Sx Class C 7121' 6201' Uner Perforation depth: true vertical measured 6997'-7016', 7030'-7074', 6838'-6902' 6048'-6061', 6071'-6102', 5993'-5982___~' TVD Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 6987' Packers and SSSV (type and measured depth) Baker HRP-1 @ 6670', Baker FB-1 at 6970~ Otis FMX SSSV @ 1910' (Locked out~ injection valve installed) 13. Stimulation or cement squeeze summary Converted from production to WAG injection service. SCSSV locked out, injection valve installed. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Gas-Mcf Tubing Pressure Prior to well operation Subsecluent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Water-Bbi Estimated 7,500 BWPD. Casing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas Suspended Service Wag Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form ~ - 4 RC~e 06/15/88 Title Sr. Operations Engineer SUBMIT IN DUPLICATE ARCO Alaska, S~bsidiary of Atlantic Richfield Compan; IPBDTWE~L CONTRACTOR REMARKS WELL SERVICE REPORT FIELD-DISTRICT-STATE IOPERATION AT REPORT TIME cc om?le ~'~ IDAYS i DATE i HOo 5O5' ~ ~oo I'~o j 7s--o E-,eld 23opSg~/~L_ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ' Signed knots ~ C//~~ ~T(....- ~-~-. STATE OF AI_ASKA APPLICATION FOR SUNDRY APPHOVA ' 1 6 1 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 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 897' FSL, 227' FWL, Sec 13, T11N, R8E, UM, At top of productive interval 1444' FSL, 1460' FWL, Sec. 24, T12N, R8E, UM At effective depth 1618' FSL, 1579' FWL, Sec. 24, T13N, R8E, UM At total depth 1676' FSL, 1627' FWL, Sec. 24, T13N, R8E, UM 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-03 //~ 9, Permit number 84-51 10. APl number 5o-1 03-20025 11. Field/Pool Kuparuk River Field Kupar, uk River Oil Pool 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7230' true vertical 6 24 0' measured 71 31 ' true vertical 61 4 1 ' Length Size 110' 16" 2612' 9 5/8" 7212' measured 6997'-7016', true vertical 6048'-6061 ', Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6987' Packers and SSSV (type and measured depth) feet feet feet feet Plugs (measured) Junk (measured) None Cemented Measured depth True vertical depth 200 Sx cS I 1 10' 1 10' 750 Sx PF E & 261 2' 261 2' 250 Sx PFC 350 Sx Class C 7121' 6201' 7O3O'-7O74', 6838'-6902' 6071'-6102', 5993'-5982' TVD RECEIVED Alaska Oil & Gas Cons. Commission Baker HRP-1 ~ 6670'r Baker FB-1 at 6970r Otis FMX SSSV ~ 1910" 13. Attachments Description summary of proposal _ Detailed operation program _ Lock-out Otis SCSSVr install injection valve. 14. Estimated date for commencing operation August. 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service WAG Injector . Anchorage BOP sketch_ Suspended 17. I hereby certify that the~foregoing is true and correct to th~best of my knowledge. 7' ' FOR COMMISSION USE ONLY Conditions of approval: Plug integrity __ BOP Test Mechanical Integrity Test m Notify Commission so representative may witness Location clearance Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Form 10-403 Rev 5/03/89 Commissioner IApproval No. 9- I Approved Copy Returned SUBMIT IN TRIPLICATE 3 I I I I I ! l' 1 I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF Anchorage HIREL INE BOP EOUIPMENT ' STATE OF ALASKA 0 ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator ARCO Alaska, In(;;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 597' FSL, 227' FWL, Sec. 13, T11N, R8E, UM At top of productive interval 1444' FSL, 1460' FWL, Sec. 24, T11N, R8E, UM At effective depth 1618' FSL, 1579' FWL, Sec.24, T11N, R8E, UM At total depth 1676' FSL, 1627' FWL, Sec. 24, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 723 0' feet true vertical 6240' feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-03 9. Permit number 84-51 10. APl number 5o-1 03-20025 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7131 ' feet Junk (measured) true vertical 61 41 ' feet None Casing Length Size Cemented Structural Conductor 1 1 0' 1 6" 200 Sx CS II Surface 261 2' 9 5/8" 750 Sx PF E Intermediate 250 Sx PFC Production 721 2' 7" 350 Sx Class C Liner Perforation depth: measured 6997'-7016', 7030'-7074', 6838'-6902' 13. Description summary of proposal _ Workover well with a snubbing unit to remove a wireline tool 14. Estimated date for commencing operation 15. May 1989 16. If proposal was verbally approved Minder 5/25/89 Name of approver Date approved true vertical 6048'-6061', 6071 '-6102', 5993'-5982' TVD Tubing (size, grade, and measured depth 3 1/2" J-55 at 6987' Packers and SSSV (type and measured depth) Baker HRP-1 at 6670', Baker FB-1 at 6970'~ Otis FMX SSSV at 1910' Attachments Measured depth True vertical depth 110' 110' 2612' 2612' 7212' 6201' Detailed operation program X.~ BOP sketch X strincl that is lodged in the SSSV. Status of well classification as: Oil X Gas ~ Suspended _ Service Will convert to WAG injection after WO 17. I hereby certify that the foregoing is true and correct to t~, best of my knowledge. Signed ~./t.¢ /~ .,.-,_.. e ~..~, ' - ~r/ FOR COMMISSI(~N USE ONLY Conditions of approval: Notify Commission so representative may witness Date IIAppr°val N~;i...- Plug integrity ~ BOP Test Mechanical Integrity Test ~ Approved by the order of the Commission Location clearance Subsequent form require 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned~ Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS - Addendum I . . . Workover fluid will be 6.8 ppg arctic diesel. A BOP sketch is attached. Estimated BHP in the A Sand at 7150' MD (6085' TVD) is 3800 psi. Kuparuk Well 2A-03 Snubbing Unit Workover Procedure AFE #AK4079 1) 2) 3) 4) 5) 5) 6) 7) 8) 9) MIRU 120K snubbing unit, BOPs, flow control and other associated equipment. Pressure test to 5000 psi. Load tubing and annulus with diesel. RIH with the following BHA on 1.25" 3.02# N-80 CS Hydril tubing (bottom to top)' 2.75" OD X 2.00" ID burn over milling shoe hydraulic jars bumper sub back pressure valve 1 joint 1.25" tubing back pressure valve I joint 1.25" tubing 'N' nipple Specifications for the 1.25" workstring are as follows' Tubing O.D. - 1.660" Burst - 16,110 psi Box O.D.- 1.927" Collapse - 16,290 psi I.D. - 1.278" Joint Yield Strength - 71,000 lbs. D.D.- 1.184" Capacity - 0.00159 bbl/ft 3.5"x 1.25" annulus capacity - 0.006 bbl/ft Tag top of fish at +1900'. Mill over Otis 2.5" X lock down to 1.995" stem. POOH. Replace mill with overshot. RIH and latch fish. Jar up and attempt to pull remainder of bulldog spear. POOH. Replace overshot with 2.75" OD flat bottom mill. RIH and tag fish. Mill on fish until it falls into tailpipe. POOH. MIRU slickline unit. Tag TOF and ensure it is below the bottom of the 'FB-I' packer. RDMO slickline and snubbing equipment. MIRU EL unit. - . RIH with ohemio~l outter ~nd out off tailpipe below 'FB-I' paoker. RDMO EL unit. A procedure for pre- and post-conversion slickline work will follow after completion of the workover. Otis Snubbing L- it Layout and Specifications CONTROL PANEL HYDRAUUC BAR CLAMP WORK ~ PLATFORM TRAVELING SLIP~ POWER ROTATING HEAD COUNTER BALANCE WINCH HYDRAUUC BYPAS~ Pill Yell Till COUNTER BALANCE VALVES TWO OR OPERATING CYLINDERS WELDED PLUMBING SPLINEO TELESCOPING GUIDE TUBES SC.,OPING MAST STATIONARY SUPS WINDOW-FOR STRIPPER BOWL OR ANNULAR BOP HANGER FLANGE PR~EI~ER:: =_ ~ STACK - OPEm&10~ SPECIFK~AllON~ Oescdllll Ks Iqr7 ~--l. IJ~ k,,d,, ps~ Hydraulic PTetsum $S.000 Mmxu~um I.~ I.o~ O 3,000 ' ' ps~ HydriuIC Pfe~sizl 120,00~ . . . ~m~11 S~ub Loa~ 36 . · half k:~l) ~.~m,o,,,~ To,,,= ._~."'~-~ ~0~ Wod~ing PresSure Ratio IO.000 psi Pipe ~ Ca,oabilit~ Ohs · ~ 0SO. i~. O.0. mru Z375.i0 0 0. , . , Cy~ndef 1,0. 4- , . . Hydraulic P~mp Output , _ _120/160 gpm Power P~ .. .430 hp @ 2J00 rpm Powe~ P.uge'- ' 10~ ~0 104 g.(x)0 AUx,!ia~/Power P~Cka§' Fud Tank :~0 Gal. Or~ - Pipe Handhng Cylinder in C~adl~ IZ8 28 30 2.600 WOdc a~ Hose Basket 20p~al~.mg Consoln g6 9~ 4~.~ 4.000 8tovro~ Pre~ntef (3) Stict 44 54 87 3.600 Sta~o~h1~y Slips wl~¢-if~.' W'H'HSOw 18 18 3~ 2.100 · 'l~ru 2,875-in, O.D. w/Cavie o~ G~tberson ~ "Depends on Type 60P Ur~d Otis Snubbing Unit Operating Principles OPERATING PRINCIPLES Units have one snubbing speed and two lifting speeds. An O~is stripper bowl, on top of thc BOP stack, is used for rumfing ami pulling premium thread tubing in sizes from l.O50-inch O.D. fluough 2.8?5-inch O.D. in wells with up to 3,000 psi. The blowout preventers are used in wells with ovo' 3,000 psi and when running collared pipe. Thc master ~( is opened with stationary slips closed to prevent well pi,.. ~e from ejecting tubing. Traveling slips arc opened, and thc traveling piston extended. Traveling slips arc then closed; stationary slips opened; and thc traveling piston retracted through its full stroke, forcing pipe into the well. When pipe becomes heavy, the lower set of stationary slips is used in conjunction with the uaveling slips. Upper sta- tionary slips remain open and arc designed to be in position to be actuated if needed when pipe becomes light. NOTE: Neglecting friction, pipe is designated heavy when pipe weight exceeds thc plugged-pipe area times well pres- sure psi. Pipe is designated light when well pressure psi times plugged-pipe area overcomes pipe weight. BENEFITS OF DESIGN PRINCIPLE · Power to move pipe is obtained by a double-acting hy- draulic piston with reversible traveling slips. Assembly can handle 1.050-inch O.D. to 5.500-inch O.D. tubing sizes. · Even thc smallest pipe size is protected against bending when moving against maximum well pressure due to Otis exclusive tubing-support guides. Full length, piston-stroke support speeds-up the operation to reduce well- maintenance time for extra economy. · Three sets of interlocked slips are designed so that one set is always engaged when pipe becomes light or heavy (see OPERATING PRINCIPLES) while snubbing or running. · Pressure accumulators in the hydraulic-power system are designed to provide reserve hydraulic pressure to close the BOP's faster, further reducing well-maintenance time. Ac- cumulators also provide a pressure storage for use in the event of an emergency. · Stripper rubbers may be used, along with ram-type BOP's, to run premium pipe sizes from 1.050-inch O.D. through 2.g'7$-inch O.D. when well pressure is under 3,000 psi. This speeds operation, since time is no[ lost in manipulating BOP's. · Standard blowout preventers, used when well pressure is over 3,000 psi, have 5,000 psi working pressure. BOP's with higher pressure ratings are available. · Power tongs or an integral, hydraulic-powered sub are available for rotating tubing, even with full tubing load. A swivel is available to be attached to the top of joint when circulating and rotating. STANDARD EQUIPMENT AND PERSONNEL Equipment Identifled in ~chematic ~ ~, ::x',~ i. ;i, (~ Traveling Slips (Closed) ....... ,,. Workbasket with consols ........... ::'"~ :,~ ,.L'~ Traveling Slips (O~n) ~,', ....... ~: ~ $~flO~ Snub~s (O~n) ~ SmUo~ry S.p. (0~) ~ Ac~ss Widow ~ Blowout Pr~ter S~ck can bc assembled to meet workovcr requirements. ~c assembly shown 10.~ psi working pressure for 4-t/16 inch uni[s and ~,~ psi for 7-i116 inch uni~. S~ck is complete with tubing hanger, s[fipper ~wl and ms, folding. Concenlrlc Hyd[aullc Workover Unit Operatln9 Schematic. Pis~oo extended and travel/nO Piston te~racte~l and ttave~nO slii~ slips closed pt~ot to forcing pipe open before P~$toe · ~ HYORAULIC CONTROL FLUID Il WELL PRESSURE 1. Type of Request: Abandon m Suspend __ Alter casing __ Repair well Change approved program __ "'--'" STATE OF ALASKA .... A LA,_._ ,A PI L AN D GAS CONSERVATI ON CO M M I',.,_.-..)N APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator ARCO Alaska, Inc. Operation shutdown m Re-enter suspended well ~ Pluggin, g Time extension Stimulate , / ~ ~ Variance P'~'orate O'~r ~,~, ~ -~-~ T' Pull tubing v' __ __ ,Z~~ -. - ~ I5. Type of Well: Development Exploratory t Stratigraphic 99510 0360 Service 3. Address P. 0. Box 100360, Anchorage, AK 6. Datum elevation (DF or KB) RKB 1 30 ' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-0:3 9. Permit number 84-51 10. APl number 50-- 103-20025 11. Field/Pool Kuparuk River Oil Pool 4. Location of well at surface 597' FSL, 227' FWL, Sec.13, T11N, R8E, UM At top of productive interval 1444' FNL, 1460' FWL, 5dC. 24, TllN, R8E, UM At effective depth 1618' FNL, 1579' FWL, 5ec.24, T11N, R8E, UM At total depth 1676' FNL, 1627' FWL, 5ec.24, TllN, R8E, UM 72:3 0 ' feet Plugs (measured) 6240 ' feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 71:31 ' feet Junk (measured) true vertical 61 41 ' feet Size Cemented Measured depth True vertical depth 16" 200 Sx Cold Set II 110' 110' 9-5/8" 750 SX Permafrost E 2612' 2612' 250 Sx Permafrost C 7" 350 Sx Class "G" 7212' 6201 ' 6997'-7016', 250 5x Permafrost C 7030'-7074',68:38'-6902' MD Casing Length Structural Conductor 11 0 ' Surface 261 2 ' Intermediate 7212' Production L~ner Perforation depth: measured true vertical 6048'-606i', 6071'-6102', 5993'-5982 TVD Otis FMX SSSV @ 1910' . I ECEJVED JAN U .5 N~..~ &' Gas Cons, -Pdbing (size, grade, and measured depth) :3-1/2", J-55, at 6987'. Packers and SSSV (type and measured depth) Baker HEP-1 (~ 6670', Baker FB-1 (~ 6970. Detailed operations program __ BOP sketch v/ 13. Attachments Description summary of proposal December :30~ 1988 14. Estimated date for commencing operation 16. If proposal was verbally'appro ed Date approved 15. Status of well classification as: Oil v/ Gas__ Suspended_ Service Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢ ~ ~..'"-(-.~..7/ Title A ,L~A- b,.-~-~.t'~5 /-~-.~-"~5 ¢" Date l~/~1 / ¢¢ FOR COMMI$$1ON USE ONLY SA4/035 (,JldBCApprovaI Conditions of approval: Notify Commission so representative may witness No. ~...., ~/'~ Plug integrity __ B .pP,.Test -- Location clearance __ Mechanical Integrity Test7,~ Subsequent form required 10- ~, z/_ -App,'oved Copy Re~urn~¢~ ORIGINAL SIGNED BY / - ~ ONNIE Approved by order of the Commissionerl- _ C. SMITH Commissioner Form !0-403 Rev 06/15/88 Date /-G-~ SUBMIT IN TRIPLICATE Kuparuk River Unit Well 2A-03 Preliminary Workover Procedure SUMMARY: This preliminary procedure calls for pulling the completion down to the permanent packer to remove a wireline fish that is stuck in the SBR. An additional two days of rig time is included to account for any fishing oPerations. Steel blast joints will be rerun instead of carbide blast rings because the well will be converted to injection immediately after the workover. Procedure: 1. Rig up Slickline unit. Obtain BHP. 2. Move in and rig up workover rig. Kill well. 3. Nipple down tree. Nipple up and test BOPE. 4. POH and stand back 3-1/2" tubing. 5. Pickup overshot and 3-1/2" drill pipe. RIH and attempt to fish wireline tools. (assume fishing is unsuccessful) 6. Pickup packer releasing tool. RIH and release retrievable packer. POH with fish, packer, carbide blast rings, GLMs, and seal assembly. LD equipment. 7. Pickup stinger, casing scraper, and junk baskets. Rill and cleanout to D-Nipple. Circulate bottoms Up. POH LD drill pipe. 8. Run 3-1/2" completion assembly. 9. Nipple down BOPE. Nipple up and test tree. 1 0. Displace well to diesel. 11. 12. Test tubing and annulus. Secure well and release rig. Completion Fluid = NaCl/NaBr Brine Expected BHP = 3800 Psi Anticipated Start Date RECEIVED JAN u .'_N_ aslm.~ & ~as Cons. Commissio~ ,~i. Nlcliorage ANNULAR PREVENTER § PIPE RAILS 4 BLIND RAILS TUBIN6 HEAD 2 1. 16' CONDUCTOR SWAGED TO 10-3/4" · 2.11"-3000 PSI STARTING HEAD 3. 11"-3000 PSI X 7-1/16"-5000 TUBING HEAD 4. 7-1/16" - 5000 PS1 PIPE RAMS 5. 7-1 / 16" - ,5000 PSI BLIND RAMS §. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1, CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC. FLUID, 2, ASSURE THAT ACCUMULATOR PRESSURE IS ;~000 PSI WITH 1500 PSI DOWNSTREAI'I OF THE REGULATOR, 3. OBSERVE TII"IE, THEN CLOSE ALL UNITS SltlULTANEOUSLY AND RECORD THE TitlE AND PRESSURE REtlAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUtlP OFF, 4, RECORD ~ THE IADC REPORT, THE ACCEPTABLE LOg~R LltllT IS 45 SECONDS CLOSING Title AND 1200 PSI REtlAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, 2. CHECK THAT ALL HOLD-DOWN S'CPEWS ARE FULLY RE'I'~ACTED. PREDETERtllNE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 5. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO :250 PSi AND HOLD FOR 10 MINUTES, 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI. 6, OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PS! AND HOLD FOR 10 MINUTES, 8, CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES, TEST REtlAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAtl OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEtl TO ZERO PSI, g. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO ,5000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11. TEST STANDPIPE VALVES TO 3000 PSI, 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSi WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. .ll~l .IIIIV'~R I~RR ARCO Alaska, Inc. Date: July 15, 1988 RETURN TO: Transmittal #: 7225 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. ~30-15 Kuparuk · 30-10 Kuparuk e 2 D- 15 Kuparuk · 2 A- 06 Kuparuk ,, 1 G- 07 Kuparuk · ' 1 G- 08 Kuparuk , 1 G-15 Kuparuk ' 31 - 01 Kuparuk w 31-12 - Kuparuk ~,2A-03 . 3H-14 ~ 2B-16 · 3J-10 Please acknowledge receipt and return Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Kuparuk Fluid Level Report Post Frac Job Report Bollom Hole Pressure' Survey Kuparuk Well Pressure Report 7-11-88 7-11-88 7-12-88 7-12-88 7-08-88 7-08-88 7-08-88 7-08-88 7-08-88 7-06088 7-09-88 7-03-88 3-08-88 Tubing Tubing Casing Tubing Casing Casing Casing Tubing Tubing Casing AIIo Frac A-10 PBU Amerad Receipt Acknowledged: ' - ....... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Mobil Unocal Chevron ARCO Alaska, In?- Post Office .,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. The wells were both conversions and fractures as listed below. Well Action Anticipated Start Date 2A-3 ~ Conversion October 19, 1987 2A-6 v Conversion October 19, 1987 2A-7 w Conversion October 19, 1987 3K-15 Conversion October 15, 1987 3N-4 Conversion October 15, 1987 3N-5 Conversion October 15, 1987 3N-11 Conversion October 15, 1987 3Q-5 Conversion October 15, 1987 3Q-12 Conversion October 15, 1987 3Q-15 Conversion October 15, 1987 If you have any questions, please call me at 265-6840. Si ncerely, lwood Senior Operations Engineer GBS-pg'0117 Attachments RECEIVED A!askn Oil & Gas Cons. Commission Anchorage cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA AL/~,~Ix~. OIL AND GAS CONSERVATION CO~v,r~,.,SSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska. In¢, 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 597' FSL, 227' FWL, Sec. 13, T11N, R8E, UM At top of productive interval 1444' FNL, 1460' FWL, Sec. 24, T11N, R8E, UH At effective depth 1618' FNL, 1579' FWL, Sec. 24, T11N, R8E, UM At total depth 1676' FNL, 1627' FWL, Sec. 24, TllN, R8E, UM 11. Present well condition summary 7230' Total depth: measured 6240' feet Plugs (measured) true vertical feet Effective depth: measured 7131 ' feet true vertical 6141' feet Junk (measured) 5. Datum elevation (DF or KB) RKB 130' feet 6. Unit or Property name Kuparuk River Unit 7, Well number 2A-03 8. Permit number 84-51 9. APl number 50-- 103-20025 10. Pool Kuparuk River Oil Pool Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 16" 200 Sx Cold Set II 110' 110' Surface 2612' 9-5/8" 750 Sx Permafrost E 2612' 2612' Intermediate 250 Sx Permafrost C Production 7212' 7" 350 Sx Class "G" 7212' 6201' 250 Sx Permafrost C Liner 6997'-7016' 7030'-7074' 6838'-6902' MD Perforation depth: measured true vertical 6048'-6061', 6071'-6102', 5993'-5982' TVDR ~ [E~VF''~) Tubing (size, grade and measured depth) 3-1/2" J-55 at 6987' Packers and SSSV (type and measured depth) ' ' ' ~12S,[,',~1 Oil & Gas [;0ns. C0m[,*l[SS Baker HRP-1 @ 6670', Baker FB-1 @ 6970', Otis FMX $$SV @ 19 . 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 19, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that ~e foregoing is true i},nd correct to~ best of my knowledge Title, O~.~Jc~r~ _ Commission Use Only Date /90d ~ Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ApFr~ved Ce~'t Commissioner Approval No. ~.¢¢0 by order of oom , sio. Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 2A-3 Well 2A-3 is a selective single comletion currently utilized for gas injection. Surface modifications will be performed to allow production of the well, and subsurface work will be performed to shut-in the C Sand and open A Sand producti on. ARR'tc-O005 ARCO Alaska, Inc. Posl Office Box 100360 Ap. chorage, Alaska 99510-0360 Telephone 907 276 1215 July 28, 1987 Ms.~Fran Jones Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive · Anchorage, Alaska 99501 Subject: Miscellaneous GCT Surveys Dear Fran: Enclosed are additional copies of the 1L-6 2A-2 1L-15 2A-3 1L-16 2A-4 L1-1 2D-11 L2-28 2D-12 following 2G-8 2G-10 2G-13 If you have any questions, Sincerely, · Gruber Associate Engineer please call me at dG:pk JG/78 Enclosures GCT surveys: 263-4944. I £CEI VE8 JUL A/agka 011 & Gas Cons. ~mmissloj~ ~Chorage AIICO Alaska. Inc. is a Subsidiary of AllantlcRIchlleldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-29-$ 5 TRANSMITTAL NO: 5203 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11!5B P.O. BOX 100360 ANCHORAGE, AK 99510 T RANSM ITTED RECEIPT AND HERE%~IT}[ ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS PRESSU~'h DATA . · --~2A-3 PBU- '~' SAND 03-16-85 ,2A-5 SBtlP 11-2 1-8 4 ~2B-1 PBU 04-01-85 ~_2B'2 PBU 04-02-85 ~ 2B-15 PBU- POST FRAC 04-09-85 ----,2B-16 PBU 04-10-85 --~ 2F-_7 PBU- STATE 04-14-85 . 2F-8 ~-~ PBU- 'A' SAND 04-20-85 k~- 2 F? 9 ~/PB U- S T AT E 04 - 13 - 85 '~2G-!2 PBU- 'A' SAND POST FRAC 03-23-85 ,~-2H-!5 ISBHP 04-10-85 ~-2W-13 PBU- 'C' SAND 04-21-85 .... 2X-13 PBU 03-30-85 BAKER/ LYNES PRESSURE REPORTS (ONE COPY OF EACH) SET DEPTH ~ lA-1 PBU 04-23-85 7187 ' ~-~iA- 2 PBU 04-23-85 7476 ' ~lA-2 PBU 04-23-85 7476 ' ·-lA-5 BUILD-UP 04-23-85 6957' lA-6 PBU 04-23-85 8300 ' ,~ lA-6 BUiLD-UP 04-23-85 8300' ~iA-~I 0 BUILD-UP 04-23-85 8415 ' lA-10 BUILD-UP 04-23-85 8415 ' RECEIPT ACKNOWLEDGED: B PAE * B. CURRIER* C lie VROi-I * D & M* DRILLING L. JO[INSTON MOBIL* NSK CLERK DISTRIB UT ION: W. PASHER EXXON PHILLIPS OIL~ J. RATHMELL~ TOOL NO. 1722 1302 1512 1734 1719 2062 1508 1299 DA~.~.Aa O, & ~as Cor. s. Commission Anchorage STATE OF ALASKA~ SOHIO* UNION* K.TULIN/VAULT ARCO Alaska, Inc. Post Office B J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton- Enclosed are revised Well Completion Reports for the following wells' 2A-2 2D-5 2E-14 2A-3 2D-14 2E-16 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the cement quantity used when each well was Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures RECEIVED APR 2 21985 Alaska Oil & Gas Cons. commisslon Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,?~ STATE OF ALASKA .~-. ALASKA _ AND GAS CONSERVATION C~ ,VIISSION WELL COMPLETION OR RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well REV I S I ON GAS [] SUSPENDED [] ABANDONED [] SERVICE~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ~ 84-51 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20025 4. Location of well at surface 9. Unit Or Lease Name 597' FSL, 227' FWL, Sec.13, T11N, R8E, UN Kuparuk River Unit . At Top Producing Interval 10. Well Number 1444' FNL, 1460' FWL, Sec.24, TllN, RSE, UM 2A-3 At Total Depth 11. Field and Pool 1676' FNL, 1627' FWL, Sec.24, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 04/20/84 04/26/84 06/19/84I N/A feet MS L 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost 7230'MD, 6240'TVD 7131 'MD,6141 'TVD YES [~X NO [] 1943 feet MD 1500' (approx} 22. Type Electric or Other Logs Run DIL/EP/SFL/GR/FDC/CNL/Cal, CBL/GR/CCL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 200 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2612' 12-1/4" 750 sx Permafrost E & 2;0 sx Permafrost C 7" 26.0# J-55 Surf 7212' 8-1/2" 350 sx Class G & 250 sx PF "C" . , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6997' - 7016' 3-1/2" 6987' 6703' & 6970' 7030' - 7074' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6838' - 6902' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6966' - 6968' 75 sx Class G 6993' - 6997' 75 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED APR 2 2 -. Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 JMM2/WC02 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . . . NAME Include interval tested, pressure data, all fluids:rL~c°vered and gravity, MEAS. DEPTH TRUE VERT. DEPTH.. GOR, and time of each phase. . . · _ · . Top Upper Sand 683._6.~- 5936' N/A _. . ..... . ' Base UpPer Sand 6900' - - 5980' . Top Lower Sand ~: -6973' 6031' '' " '. '"~ :-:. ':" -. --' -': Base Lower Sand - 7162' 6172' ~: ;,. ;i: . :,,~ ~ . , ,~: '" ' . . , -~ _~.- ~ :'.- -, .... .i .'.~-' : · . . _ · 31. LIST OF ATTACHMENTS , . None - '- -,:-, , - ;- ;".. - ~ : -':' "': " 32. I hereby Certify:that the foregoing is true and correct to the be_St of' my knowledge -. . -. Signed ~ ~ ~/-~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and-leases in Alaska. Item. 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval, to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (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". Fnrm 1 (~-a~7 ARCO Alaska, Inc. Post Office [¢.,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I.%:'Z '", I'll .2 / .'- '.: ,. 'i-H ;I; 5' 'l-I:;; Ai",~,5/i'i ]: 'F'f' ¢~ L, ". ,, · , I)" '""'"' ' ,~' .." -."'r" ,-' i...'~,' i?.;':"l.' .A ,¢.. - ~' Ci H ;f: {;)::'.' · · LIN 3: C}?"..:": ....... l',' '¥'1" ': ......... :" '"' · .,, , ..; i....'. ~ · . '; ... I ARCO. Alaska, inc.. : ._ Post Office B(,.. ,00360 Anchorage, Alaska 99510-0360 Telephone907 276 1215 EVENTZ , · '"Ri I B' !'-i F' P,H "-'"""'" ..... ~- if'Il r'! -i r,I r b, EF' !::£)F,' F,.~,.~l.., · .l.- :.. ' "i :- "~ F',.'T:TU.t.-i,'-ZN.f.{ F:'CIF:.'. FI-...~--:L. F' ;.:-': !.J ,?OURC.[.-E H.,'-~TEF-: HF:':;:TH F<UN Gt...V ' Z,.' . F,.:!.ii'--'., -" ~' {.-:L. ~,' ,::. F' ~:''.v I' 'I .F:' F'6-' !.-[ F' F' E: L.t OPEN 'C' .'.";AND/.?TAT:[C BHF'( IN:[T:[¢iL ) F', T ~ ~UE': ]i NG/F:'F~E---FF;,',,"~C ......... F'REF' FOlk 'C',i-...-'f:~,i"-,!f:, '°'~*-'" ,C '" .. ... ,.,~ ~ ~.T. £-,'1-:I - . .. '~'~'¢~TTC BI-.IF:'/' E." ,SAN!) :E: !"I r: n-, ..t~,las.ka Oil & 6as Cons. Commission ;.-' I"1 -- i::, - ~ , . ..z~ ..... i';~..: . . · i; [.:)I"I ~' r~ :,~. ! IKI '[ r~ :,l :~. ARCO Alaska, In' Post Offic= ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatter Alaska Oil and Ga 3001 Porcupine Dr Anchorage, AK 9 ton, Chairman s Conservation Commission ive 9501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' on Well Action Date Performed 1E-6 Fracture 1/26/85 1E-7 Reperf 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 Fracture 2/7/85 1E-18 Fracture 3/13/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3/23/85 1E-22 Fracture 3/22/85 1E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3/18/85 1Q-10 Fracture 3/5/85 1Q-12 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversion 2X-8 Perforation 1/27/85 If you have any questions, please call Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) me at 263-4253. the ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-51 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 5o- 103-20025 OTHER [] 4. Location of Well SURFACE L0CATION- 597'FSL, 227'FWL, Sec, 13, T11N, R8E, UM BOTTOM HOLE LOCATION' 1503'FNL, 1424'FWL, Sec. 24, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 130' PAD 94' I ADL 25570 ALK 12. 2668 9. Unit or Lease Name KUPARUK RIVER UNIT . 10. Well Number 2A-3 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL P001 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] ' Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10o407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On March 21, 1985, Kuparuk well 2A-3 was converted from a producer to an injector. Injection will be in the "C" sand only. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ _ ~- Title OPERATIONS The space below for Commission use COORDINATOR 3/28/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In/ Post Office ,.,Ox 360 Anchorage, Alaska 99510 ' Telephone 907 277 5637 ARCO Alaska, In~'~" F...'_:.! Ot!~, . 360 /~.r;c~orage. Alaska 99510 Telephone 907 277 5637 Date: 8/17/84 Transmittal No: 4690 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk' ATO-1115B P.O. Box 100360 Anchorage, AK 99510 tted herewith are the following items. Please acknowledge receipt urn one signed copy of this transmittal. PL FINALS/Schlumberger o~iE-30~EPL "Spin/Temp/Tracer" ~ iF-li~~ EPL "Tracer" .~lF-16 ¢' EPL "Temp/Tracer" ~._2A-3- EPL "DDL/Tracer" ./ ; 2A-3 CL Cement Reta±ner S&Sq. Gun "CBL" 2A-3 'j CCL & Perf. Record 2A'3 CCL Cement Retainer "DDL/RTS/CBL" Run 4 5/26/84 6750 - 7080 Run 1 6/24/84 8150 - 8550 " 6/23/84 8000 - 8809 " 6/11/84 6700 - 7050 Runs 1-3 6/15/84 Run 1 6/17/84 " 6/15/84 6850- 6975 2A-3 CCL Product. Packer { "RTS/CBL/Perf" _~2A-4 '/ EPL "GR/ CCL/Tracer" /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron " 6/18/84 6880 - 7010 " 6/08/84 7730- 7950 DISTRIBUTION D&M W.~. Pasher Drilling Geology -Mobil NSK Operations G. Phillips Phillips Oil J.J. Rathmell R&D o ._ C. R. Smith /~lJState '"of..-'~aska ;' Sohio Union Well Files ARCO Alaska, I Post Office: dox 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to stimulate Kuparuk Field well 1F-6 and to convert the following wells: 1Y-2, 1Y-8, 1Y-12, 1Y-15 2A-l, 2A-2, 2A-3, 2A-4, 2A-5, 2A-6, 2A-7 2V-l, 2V-2, 2V-3, 2V-4 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JAN 0 4 1985 Alaska Oil & Gas Cons. C0mmJssi0rl Anchorage ARCO Alaska, Inc. is a subsidiary of AllanflcRlchfieldCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COiViMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-51 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-103-20025 OTHER [] 4. Location of Well SURFACE LOCATION: 597 ' FSL, TllN, R8E, UM 227'FWL, 'Sec. 13, BOTTOM HOLE LOCATION: 1503'FNL, 1424'FWL, Sec. 24, TllN, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 130' PAD 94' I ADL 25570 ALK 2668 1-2. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2A-3 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It. is proposed that Kuparuk well 2A-3 be converted from a producer to a gas injection well. The well has produced from both the "A" and "C" sands. For injection, however, the "A" sand will be blanked off and injection will be in the "C" sand only. ANTICIPATED START DATE: January 23, 1985. RECEIVED. JAN 0 4 1985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS COORDINATOR The space below for Commission use 1/3/85 Date Conditions of Approval, if any: Approved by IttliilltSL $1tN[D Bt LOlll~li; ~.: 8illIl' Approved Cop), Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In( Post Office ,-,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 31, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2A-3 Dear Mr. Chatterton- Enclosed are the Completion Report and gyroscopic'survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw. GRU1/L19 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -~ - STATE OF ALASKA ';~', ALASKa. _ .~ AND GAS CONSERVATION C i:-~ISSION ' WEL-L COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-51' 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- i03-20025 4. Location of well at surface 9. Unit or Lease Name 597' FSL, 227' FWL, Sec.13, TllN, R8E, UM iLOC/-,,T!Ci,~,S] Kuparuk River Unit -' At Top Producing Interval j c~.,,-i..-D ~ 10. Well Number 1444' FNL, 1460' FWL, Sec.24, TllN, R8E, UN At Total Depth ~. H. __~_~ 11. Field and Pool 1676' FNL, 1627' FWL, Sec.24, TllN, R8E, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 04/20/84 04/26/84 06/19/84I N/A feet MS LI 1 17. Total Depth .(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7230'MD, ~TV_D_ 7131 'MD,6141 'TVD YES ~ NO [] 1943 feet MDI 1500' (approx) ~D E~. -- 22. Type Electric or Other Logs Run D IL/SP/SFL/GR/FDC/CNL/Cal, CBL/GR/CCL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD 'CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 200 sx Cold Set il 9-5/8" 36.0# J-55 Surf .: 2612' 12-1/4" 750 sx Permafrost E & 2.~;0 sx Permafrost C 7" 26.0# J-55 Surf 7212' 8-1/2" 350 sx Class G 24. Perforations open to Production (MD+TVD of Top and BOttom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6997' - 7016' 3-1/2" 6987' 6703' & 6970' 7030' - 7074' w/4 sPf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6838' - 6902' w/12 sPf, 120~ Phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6966' - 6968' 75 Sx Class G 6993' - 6997' 75 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF V~ATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOU'R RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE - Form 10-407 GRUS/WC02 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~¢::~ :- 7-..:. F,'~_'-~ , ' . NAME Include interval tested, pressure data, all fluids recover~ and gravity, MEAS2 DEPTH TRUE vERT. DEPTH GOR, and time of each phase. - - ~ . .. . . . - lop ~pper Sand ~e Upper Sand ~.6~00~ 5~80~ lop ko,er Sand '- '. :, ' '~ . -- ':;:L '~ , ~_:.~' :}"~' : . . Base Lower Sand. 7162' "' 6172' - ..~ . . . · ; · . . .. . . , - . .. : : . 31. ~IST OF ATTACHMENTS ' . . . ~ell ~i-s~ory~ ~orkover ~ell Hi~ory~ Gyroscopic,Survey (2 cOpies) -- . ~' 32. I herebg certify that the'fore~oin~ iS tree and correct t° the best of mg knowledge .. ~ .. Si~ned Title ~e~ Beill~nn Fn~ Date INSTRUCTIONS ' ' General: This form is designed for submitting a Complete and correct well completion report and log on all tyPes of lands and leases in Alaska. item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shoWn) for depth measurements given in other spaces on this form and in any attachments. · Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Fnrm I ARCO 011 and Gas Company Wall HIMory - Initial Report - Dally Prepare and ~ubmlt the *'la~lM I~lm~" on the tim WedneM~y after I w.41 II Ii~ddld or workover operltlona itl Itl.dld. Dally work prier te ~ ~ i~ I~mmln'zed on the form giving Inclulivl d'fll only. District IC~,~y, ~ ~r ~ Imm Alaska I North Slope Borough ILea~e or Unit I ADL //25570 ITitle I Drill, Complete & Perforate Field Kuparuk River Auth. or W.O. no'. AgE 901695 Alaska ell no. 2A-3 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun ID.fo IHour [Prior status if Spudded 4/20/84 1930 Hrs. Date and depth as of 8:00 a.m. 4/20/84 thru 4/23/84 4/24/84 4/25/84 . · 4/26/84 Complete record for each day reported 56.24% · W.O. 9-5/8" @ 2612' 3620', (3620'), Drlg Wt. 8.8, PV 4, YP 6, PR 9, WL 10.2, Sol 3 Accept ri~ @ 1700 hrs, 4/20/84. NU riser. Spud well @ 1930 hfs, 4/20/84. Drl 12%" hole to 2630', C&C hole f/egg. RU & rn 66 its, 9-5/8", 36#, J-55 csg w/FS @ 2612', FC @ 2535'. M&P 750 sx PF "E" W 12.3 ppg, followed by 250 sx PF "C" @ 15.7 ppg. Displ w/rig pmp, bump plug. CIP @ 2030 hfs, 4/21/84. NU BOPE & tst to 250/3000 psi; OK. PU 8½" BHA, tag FC, tat csg to 1500 psi; OK. DO FC, cmt, FS + 10' new hole. Conduct leak-off tst to 12.5 EMW. Drl to 2750', Navi-Drl to 3620'. 2750', Assumed vertical 3025', 9.3~, S42E, 2971.27 TVD, 17.58 VS, 13.37S, 12.04E 3247', 18~, S23E, 3191.86 TVD, 71.09 VS, 58.55S, 40.83E 3466', 21~, S25E, 3410.55 TVD, 148.15 VS, 129.30S, 72.32E 9-5/8" @ 2612' 4798', (1178'), TlR Wt. 9.0, PV 7, YP 7, PR 9.5, WL 9.4, Sol 3 Drl 8½" hole to 4798', POR, LD bdlg assy. 3684', 25-1/2~, S32-1/2E, 3594.31TVD, 227.09 VS, 198.52S, l10.30E 4092', 31.75°, S32E, 3955.83 TVD, 426.12 VS, 366.79S, 216.99E 4360', 36.75~, S30E, 4177.16 TVD, 576.98 V$, 495.15S, 296.47E 4721', 43.5~, S29E, 4453.84 TVD, 811.66 VS, 698.42S, 413.74E 9-5/8" @ 2612' 7110', (2312'), Drlg Wt. 10.1, PV 17, YP 8, PH 9.5, WL 5.6, Sol 1'2 Drl 8½" hole to 7110'. 5047', 46.75°, S29.SE, 4670.42 T1rD, 1029.17 VS, 888.21S, 520.02E 5550', 47°, $32.5E, 5014.27 TVD, 1396.16 Va, 1202.86S, 709.08~ 6338', 47°, S34.5E, 5527.81Tt/D, 1945.62 va, 1662.06S, 1013.02E 9-5/8" @ 2612' 7205', (95'), POOH f/logs Wt. 10.1, PV 15, YP 12, PR 9.5, WL 5.2, Sol 12 Drl to 7130', short trip to shoe, circ, POOR f/logs. RIH w/triple combo, bridge @ 4660'. RIR w/bit, rm tight hole. Drl to 7205', POOR f/logs. 7123', 46°, S35.5E, 6137 TVD, 2584.24 VS, 2184.66N, 1385.79E The ~bm~ 15 corrl~t 81gnmum For form preparaUoa ~nd dll~lbulJee, a# Procedum~ MaeuaL 8eg41on 10. 4/26/84 [~ Drilling Superintendent ]Numl~r MI dMly ~1 hlatee/ forum ce~e~rativMy ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "F'Mai Rel~ert" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted slid when operations are suspended for an indefinite or appreciable length of time. On worXovers when an official test is not required upon completion, report completion and repreient, Mive test data Jn blocks provided. The "Final Report" form may be used for reporting Ihs entire operation if space is available. Accounting cost center code District State North Slope Borough Alaska County or Parish Well no. Field I Lease or Unit Kuparuk River [ ADL #25570 2A-3 Auth. or W.O. no. [Title AFE 901695 ] Drill, Complete & Perforate Operator ~[CO Alaska, Inc. A.R.Co. W.I. 56.24% [abandonment[C°stlT°tal centernUmberprior°fof wellSthistO pluggingwell(active and°r inactive) on this Spudded or W.O. begun Date ]Hour [ Prior status if a W.O. Spudded 4/20/84 [ 1930 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. Alaska 4/27/84 4/28/84 7" @ 7212' 7230', (25'), ND BOPE Wt. 10.1+, PV 17, YP 12, PH 9.0, WL 5.8, Sol 12 RU SOS, rn DIL/SP/SFL/GR/FDC/CNL/CAL f/6600'-TD. Drl 8½" hole to 7230'. Rn 184 its, 7", 26#, $-55 butt csg & lnd w/FS @ 7212', FC_7131'. Cml w/350 sx C1 "G" w/l% CFR-2, .3% Halad-24, 5% KC1 @ 15.8 ppg. Displ w/272 bbls 10.1 ppg NaC1/NaBr. Bump plug. CIP @ 0445 hfs, 4/27/84. Full rat's & recap pipe thruout. ND BOPE. 7" @ 7212' 7230', 7131' PBTD, Suspended Wt. 10.1NaC1/NaBr ND BOPE. Instl tree adaptor & master vlv. Tst pkoff @ 3000 psi; OK. Secure well. RR @ 1000 hrs, 4/27/84. Old TD New TO Released rig Date 1000 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing PB Depth 7230' [Xnd of rg 4/27/84 Type completion (single, dual. etc.} Single Official reservoir name(s) Kuparuk Sands [~.;.~ il:'_ . ........ ~i0.~itl~$~ential test data & 7131' Rotary , 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 The above is correct 5/17/84 Drillin8 Superintendent For form preparation and distribution, ~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well hlitory forms consecutively al they are preplred for each well. ]P~ no. Oil and Gas Company O Well History- Initial Report - Dally Prepare and submit the "lnRtll Report" on the first Wednesday after a well is spudded or workover operations are started. DallY wo~ prior to SPudding should be summarized ~ the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 901695 := County, parish or borough IState North Slope Borough I Alaska Lease or Unit flail no. ADL #25570 {2A-3 WO Title Completion Operator ARCO Alaska, Inc. SpuddedorW.O. begun ]D~e IHour Workover 6/10/84 Date and depth as of 8:00 a.m. 6/02/84 6/11/84 6/12/84 6/13/84 6/14/84 6/15/84 Complete record for each day reported The above is correct Signature I^RCO W.,. 56.24% Prior status if a W.O. 2330 Hrs. Rn CBL/VDL/GR/CCL f/4948'-7109' WLM. Rn GCT f/7050'-surf. 7" @ 7212' 7131' PBTD, RIH w/gage ring/JB 10.1NaC1/NaBr Accept rig @ 2330 hfs, 6/10/84. ND tree, NU &tst BOPE; OK. Tst lub to 1500 psi. RIH 4", 4 SPF perf gun, perf 6993'-6997' & 6898'-6902'. RIH w/6.125" gage ring/JB. '> 7" @ 7212' 1_7!31/_ PBTD, POOH w/GR/CCL 10.1 NaCl/NaBr Fin RIH w/6.125" gage ring/3B to 7099' WLM, POOH. RIH w/RTTS; tst ann to 2500 psi, set Champ III RTTS @ 7050', press tbg to 3500 psi, bled off 700#/15 min. Set conventional RTTS @ 2000', press csg to 2500 psi. Set conventional RTTS @ 7050', press tbg to 3500 psi, bled off 100#/15 min. RU Schl, tst lub to 1500 psi. RIH w/GR/CCL, locate btm RTTS @ 6928', POOH w/WL. 7" @ 7212' 7131' PBTD, RIH w/stinger on 3½" DP 10.1 NaCl/NaBr Fin POOH w/WL. Disp1 tbg volume w/crude. Bullhead crude to perfs @ 6993'-6997'. RU & rn GR/CCL/RA Tracer, no notable ann ret's, POOH. Bullhead crude to perfs @ 6993'-6997' . Open RTTS by-pass, rev circ dn ann, taking tbg ret's. Release RTTS, CBU until tbg & ann @ 0 psi, POOH. NU &tst lub. RIH w/EZ Drl SV retnr on WL, set @ 6918 WLM. RIH w/stinger to perform sqz job. 7104' PBTD, POOH w/DD 10.1 NaCl/NaBr Fin RI~nger, stab into retnr @ 6918', sqz perfs @ 6997'~7016~/75 sx C1 "G" @ .8% D-60 & .2% D-46 w/final r~:e,... 0il of 1/8~B/~@ 3400 psi. CIP @ 1050 hfs, 6/13/84. POOH w/stinger. RIH w/DD & Economill to 6410', tag cmt @ 6896', DO cmt, retnr & CO to 7t04' PBTD. Spotted BridgeSal pill. 7" @ 7212' 7104' PBTD, Prep f/cmt sqz 10.1 NaC1/NaBr POOH, LD DD & mill. RIH w/7" csg scrprs/6-1/8" bit, rev circ to cln hole, .~pot 40 bbl BridgeSal pill on btm, POOH. RU Schl, tst lub to 1500 psi, rn CBL (no depths given); poor cmt bond. RIH w/4" perf gun, perf 6966'-6968' @ 4 SPF, POOH. PU EZ Drl converted to a bridge plug, RIH to set BP @ 6978' WLM to isolate lower perfs @ 6993'-6997'. IDat, 6/25/84 JTit,e Drillin~ Superintendent ARco Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting District I!County or Parish I State Alaska I North Slope Borough J Field Lease or Unit · Kuparuk River ADL #25570 Auth. or W.O. no. Title AFE 901695 Completion cost center code Alaska IWell no. 2A-3 WO Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun J Date Workover I 6/10/84 Date and depth as of 8:00 a.m. Complete record for each day reported 6/16/84 thru 6/18/84 Iotal number of wells (active or inactive) on this i cst center prior to plugging and I bandonment of this well I our I Prior status if a W.O, 2330 Hrs.I Drld 6/19/84 6/20/84 7" @ 7212' 7160' PBTD, Prep to set pkr ~=~NaC1/NaBr RIH, set BP @ 6978' WLM. RIH, set EZ Drl @ 6916' WLM. RIH' w/stinger, stab in, sqz w/75 sx Cl "G" w/l% CFR-2, .3% Halad-24 & 5% KC1 w/final press of 2050 psi @ 1/2 BPM. CIP @ 1900 hrs, 6/15/84. FSIP = 950 psi. WOC. RIH, tag cmt @ 6882' DPM, drl firm cmt 6882'-6909', retnr @ 6909', cmt to 6978', BP @ 6978'-6981'. RIH to 7080', drl jnk 7080'-7115', FC @ 7115' & hard cmt to 7160' PBTD. POH, LD DD. RIH w/bit & 2 csg scrprs, rev circ, spot 27 bbl BridgeSal on btm. Perf 6997'-7016', 7030'-7074' @ 4 SPF/90° phasing. Perf 6838'-6902' @ 12 SPF/120° phasing. RU Baker FB-1 pkr. 7" @ 7212' 7160' PBTD, Displ'g well to crude 10.1NaC1/NaBr RIH, set Bkr FB-1 pkr w/tailpipe @ 6970'. MU & rn 215 its, 3½", 9.3#, J-55 8RD EUE AB-Mod tbg & lnd. Press tbg to 3000 psi. Set pkr @ 6703'. ND BOPE, NU tree, tst pack-off @ 5000 psi, tst tree @ 250/5000 psi. Displ well w/30 bbls diesel followed by crude. FMX Safety Vlv @ 1943' - HRP-1 retrv pkr @ 6703' - FB-1 pkr @ 6970' WLM - "D" Nipple @ 6982' WLM GLM's @ 6648', 6743', 6813' & 6973' 7" @ 7212' Fin displ'g well. Set BPV. RR @ 1500 hrs, 6/19/84. Old TO I New TO 7230' I PB Depth Released rig ~ Date J Kind ofrig 1500 Hrs. I 6/19/84 I Classifications (oil, gas, etc.) ~ Type completion (single, dual, etc.) Oil I' Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7160' Rotary Well no. Date !Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected _. The above is correct Signature ,~ ~~~.~ [ Date 6/25/84 I Title ............... i .... rt di.~tribufin~ -- -- Drilling Superintendent GCT DiRE:CT CU~TOMLR ~ ARCh ALASKA INC. ~4ET~,(]D$ OF Cf]~,PIlTATION TI]Oh bUC~TION:' Ii~TERPOLA'[ l ON: V~'~xTICA[, SLC'IION: 2A-3 KUPARUK NURTH SLOPE, SURVEY D ENG1N~ER: ., · · ~ ...... ~ - ~-' - ' ~ .~, ,'1 ,,"~ TANGENTIAL-i,iNEAR averaged Oevlat~zl'mut'l~ .,,,. · ~ ,;~., ,.: i'i.rlklZOl~TA[., DISTA~'~Cf; PROJECTE[i~~N AZIMUTH OF SOUTH 29,EA3T ~'t,'~ ..... L. * SCHL ._ GCT DIRECTION FOR ARCO ALASKA INC. 2A-3 KUPARuK METHODS Ob' COMPUTATION TOOL bOCATION: I NTNRPOLA']IIUN I VEHTICAL 8kC'I'ION: SURVEY DATE: ENGINEER: TANGENTIAb- averageo devlat ~ORIZONTAL DISTANCE PROJECTEt iCO AbA&KR I..3 IPA~UK ~l~Tt4 SLOPE, AbA~KA TRUE SUB-SEA ~6UREO VERTICAb VERTICAh )EPIH 0.00 .00,00 !00, O0 100,00 ~00,00 iO0,O0 iO0,O0 ~00,00 I00,00 )00,00 00 00 00 00 O0 00 00 00 00 00 CO~PUTATIUN UAl'E: 26 JUNE,,198~; ....................... ;,,,.....?,.~:.x,,,,. ,:.,,,:..,., ........ RSE AZANUT~ DEPTH DEPTH DEC; NIN 0.00 -130 O0 ,~ '..~ N 0 O E ,, ~.,'",,; ' 4%!. ~; ,. ,, . ,~ 400,25 270, N 15 W 500,25 3'10,~5 0 :~,0':,: N 5 ~6 E b00.25 ~70.25 0 "0''~ N 20 37 W 800.25 670.25 ........ 00,' N 9 30 E 900.26 770.25 0 0 8 89 42 w ,00 1000,24 B70.24 , O0 1100,24 970.24 O0 1200,24 1070,24 00 1300,24 1170.24 O0 1400,24 1270,24 00 1500,24 1370.24 00 1600 ~al I~70.24 00 1700 24 1570.24 O0 1800 24 1670,~4 O0 1900 24 1770.24 PAGE:. 1 .. !00,00 2100,21 1970,2! ,00 2200,1,9 2070.19 I.~:00 2300,1'1 2170,1't O0 2400.1~ 22't0.14 ~00, O0 2bO0.11 2370.11 i00,00 2600,1,0 2470,10 00,00 2700,0e 2570,06 00.00 2799,98 2669,98 }00,00 2899,29 2769,29 ,.,,.. =~'~ ,~.; <,., ,.~,,<~' ';';:'i:'~?,,,",/~""~:%='z,~'¥'a'' ' ~"~ .:?/';,;':.~m,~ ,,>.;": ~'.:~: ,'. :,,,.;.. <~/,!:xl, ?,(::,~,%1~??,~'~,$~!~.~i~?~,,'.;~:~ FEET 0 34 $ 80 40 W 0 34 N 80 27 W 018 N ~4 36 W 0 0 $ 51 w 0 34 N 8219 0 0 S'55 51 0 34 S 66 42 W 0 0 M 80 42 E 0 0 S 3J 10 W 0 0 N 74 24 E 1 8 N 62 25 E I 8 N 75 56 E 1 8 N 66 51E 1 8 N 65 26 E I 8 N 69 9 E I 8 N 72 45 E I 8 N 68 58 E I 43 m 74 40 E 3 49 S 64 4 g 8 ~5 $ 44 3 if, )00,00 2998,03 2868,(13 9 38 [00,00 3096,21 2966.21. 13 10 ~00,00 3192.b0 3062,60 17 24 {00,00 3287;15 3157,15 )9 28 00,00 3.381,i2 326'1,12 20 25 O000 3474,10 3344,10 22 50 500 O0 3565,71 3435,71 24 41 I00 O0 3655.82 3525,82 26 31 ]00 O0 3'144'~t 3~14.41 2~ 38 )00 O0 3831,76 3701,76 29 36 ~ 38 32 E S 21 18 E ~ 21 17 E $ 18 40 E $ 24 7 E S 29 48 E 831 36 E S 29 43 E S 2U 44 E $ 3~ 36 E 0,00 -0,04 -0,15 '0,55 -1,06 -.l,4b 1,64 -1.97 - 2.0 9 :2,19 2.51 3'09 3~52 3,48 :3.55 -3,44 -3,57 -3,72 -3,42 '2,98 -2,80 -2,56 -2.17 -1,79 -1,35 0,66 11,30 103. 137,69 174,45 2~,49 2 ,82 304,19 352,86 ~ARTURE W W W W W 40 N Il 9 W ,64 ,54 N ~ 50 g N 51 5 E i/I' "'' )I ' 3 . 63e 'CO AbASKA INCv iRTH ~LOPE, AbA~KA TRUF, SUB-SEA COURSE ~ISURED VERTICAb VERT'ICAL r~ ~ M ~EPTH DEPTH DEPTH IN , VERTICAh DOG RXUR~ ~00 O0 3918,i'1 37t~8.17 S 30 27 E I00 O0 4086,01 ~956.01 S 32 0 E ~00,00 424b, 12 4116, ' S 1 E ,00,00 4398,2b 4268, ,,, " :. E ~00:00 4541.~9 4'tlt,89 45 50' S' 29 ~00.00 4610,93 4,680,93 4b 24 S 28 44 E 403.16 511. b70,09' 631,40 '95,22 761.14 .22 ~00.00 4079,,'i,"1 45/i9,q'] 40 44 00.. O0 474E.1~ 4618,16 46 24 ~00,00 4617,19 4687,19 45 5~ ,00.00 4886,77 4756.77 45 5 o ~v,,,O0 5162,78 5032.76 47 15 I00,00 5230,52 5100.52 47 33 )O0,OU 5298,02 5168.02 47 33 )00,00 5365.37 5235.37 4'7 33 O0 O0 5,~32.~3.~ b302.9~ 4'1 33 ~00:00 5500,75 537('). 75 47 33 JO0,O0 '9 5438,,59 4'1 bb6~".47 55U6 .47 4~ 58 LOO,Ou 503~, , iO0 O0 5704.49 bb74,~9 4~ b8 ;00~00 57'/2. Oti 56,.~. 6 [~ 46 58 ~00,00 5841.2t~ 5711,.28 4~ ~00.00 5910,4(.~ 5'180,46 45 50 ;O0,O0 5980015 5850,1b Ab bO S 29 18 E 1045,$9 S 29 18 E 1118.o6 ~ ~9 18 E 1190 40 S 9 53 E 1262:23 S ~ ~3 ~ 1334,o8 S 3 E 1406,18 ~ 30 27 E 14'1~,5B S 30 27 E 154,.,48 S 31 I E 1025,19 $ 31 36 E 1698,92 )00,00 6049,9~ 5919,98 45 50 [00,00 6119,69 5989.69 45 50 [31000 6141,29 6011,29 4b 90 S 31 3b E 17"12.,76 S 31 36 E 1846.34 S 32 10 E 1919.78 S 32 i4 E 1993.12 S 33 19 E 2066,38 S 33 53 E 212,34 ,' ~ 34 15 E 2428,13 ....... $ 34 28 E 2570.79 $ 30 26 E , 30 29 E l{30 32 Z i 41 E tCO A6A~A INC. )RTH ~[.,OPE, A6A~KA '.['RUE ~UD-SEA iSURED VEf(TICAL VERTICAL )EPTH DEPTH DEPTH .00 1OOu,2q .o0 g~l, O0 299~,03 2858 .00 3918,17 0 0,00 46'19, zt7 ,00 53o5,37 OO. O0 ~49, .00 6141 E RCEI A]bA~i<, A UPAI~UK DR'rH ~;[.OPE, AbASKA INTERPOLATED vAI~UES FOR EVEN TRLJE SUB-SEA ASL{RED YERTICAL, V~DT C DEPTH DEPTH EFi~ 0.0o -130.o 30,00 130.00 O. 230,00 330.00 430, UO 530 ~ 00 u30,O0 730 , ~30,00 0 12~ 75 75 429 75 529 75 629 75 729 75 829 75 VERTICAl ' ' ~'EI 929,75 930,00 800,00 029.7b 1030,00 900,00 129,76 ll30,OU 1000,00 229,76 1230.0o llOOiO0 ~ 7~ 133U,Uo 1200,00 76 1430,0o 1300.00 529 7u 1530,0o 1400.00 629 7~ 1630,00 1500.00 729 7b 1730.0u 16o0,00 8.29 76 1830.0n 1700'00 929 77 1930.0o 1800,00 029 129 229 329 429 529 629 729 83O 7'; 2031,,00 79 2130.00 2000.00 81 223~,00 21uO,Oo 84 2330.00 2200,00 8'1 2~30,00 2300,00 89 2530. uO 2400. oO 92 263U, OO 2500. O0 95 2730.0() 2600.oo 0 34 N 39 23 E I 8 N 6b 41 g I 8 N 76 12 E 1 8 h 65 47 E 1 8 N 6b 11E 1 8 N 70 24 E I 8 N 72 45 E 1 43 N 77 36 E 5 31 $ 5& lb E 0.00 0,00 :§ !,68 1,84 '2,02 931,09 2930,00 032,44 3030,00 134,80 313U O0 239,36 3230~00 345,54 3330,uo 452.40 3430.00 5b0,83 353U,OU 671. ~ 7 3630. O0 897,98 3830,00 3700.00 29 -3.00 -3,13 -3,43 -3,50 -3.50 3-43 -3.65 -3,69 -3,26 ~2,92 2,74 -2~4b -2,04 '1,69 '1.13 2,79. 2800,00 9 2900.00 10 24 S 31 52 3000,0o 14 49 S 20 8 E ]~,~ 3{00.00 18 49 S 20 18 ~ , 3300:00 21 41 $ 27 26 3400 O0 23 44 S 3~ I f 198,41 , oo:oo $ 31 g 351,87 JRTH ,SLOPS, TI~UE SUB-SEA C{)IJRSE ~$OKEO VERTICAL V~iRTICA~{~:~" )EPTH DEPTd D E P T H b'~'~;iD ~G ".~~0~~+~- N ~ DEG 5 3930 O0 3800 O0:'~i~~~' , , ' S 30 27 E 88 4130,00 4000, 0 ........... ' ........ S' 6 E I E 29 53 E ,~ 29 18 E 379 35 4230,V0 509:12 4330,0d 4~00, 782 89 4530,00 4400. ~27 70 4630.00 4500.00 - 973 59 47]u,0o 460o,o0 218,42 4830,00 4700,00 4b bO 410 36 362,09 4930,00 480(), OU 4.5 50 506,3'1 5030,00 49o(),. o0 46 24 651 ~2 5130,uo 5()00.00 40 58 799 23 5230,00 51o0.00 47 33 947 4b 5330,00 5200,00 47 33 095 60 5430,00 5300,00 47 33 243 11 5530,0t) 5400,o0 47 1 390 47 563o,00 5500.00 46 5~ 683 60 58~0,00 bT00.00 qU 24 789 99 887.91 S 28 56 E 992,75 S 29 18 E 1098.89 S 29 18 E 1203.65 828,06 5930.00 5800.00 45 50 971 44 6030,00 bgOO,O0 45 50 1,4~80 O130,00 6()00.OU 45 50 131,00 6141,29 o011,29 45 50 8 29 53 E 130b,80 S 29 56 E 1410,78 g 1 E 1624.62 S 10 E 1951,39 $ 3 19 E 2059;39 ~ 3J 53 E 21~e 72 S 34 28 E 2272~96 S 34 28 E 2376.76 $ 34 28 E 2479,08 S 34 28 E 258~.36 S 34 28 E 2592,9~ 0~4~ E 48 g ~CO AbA~KA iNC. )RTH SLOPE:~ ALASKA ~IARKER TOP UPPER SAND BAS~.: UPPER SANU TOP bO~B'R SAND PB TOTAL BASE LOW~R TOTAb D~PTH 5980 6141, {~17,2,22 624,0, F,SL ' ' PAGE 7 DATE OF SURVEY: 2 JUNE 1984 KELLY BUSHING ELEVATIONS 130.00 FT . ENGINEER: MCBRIDE MARKER · .~,, .i,. TVD rkt KB 6042,29 6110,29 SURFACE bOCA?ION 'A~ ORIGIN= 227 FW5 AND 597 SEC 13. ~WN'i~N. R SE' UM RECTANGUbAR COORDINATES NORTH/$OU~H ~AST/WEST 207B, 2215o 5 $ 1)51 2233.35 ~ 1)63 2273~35 S 1399 E ?B E K I,I PA E t. IK INC. AI..A ;'..k A 0.00 100,00 200,00 300.00 400,00 500 O0 600:00 700.00 800,00 900,00 1000,00 1100.00 1200.00 1300,00 14uO,OO 1500.o0 1600,00 1700,0o 1800.00 19UO,O0 2nO0.Ou 2100.00 2200.0() 2300.0o 2400.00 2500 O0 2600:00 2700,00 2800.0O 2900,00 3000,00 31UO.OU 3200,00 3300,00 3400,00 3500,o0 3600,00 J7OO.OO 3800.00 ]900,00 TRUE VERTICAL 1000.24 ! 100.24 12()u,2~ 1300,2.~ 1400. ,/4 I bt)t). 2a 1700,2~ 1800,24 I 900,2 'a .[ '~ i !!'l','{){l][,/l,'l }..1'; VAt,OI,'& P OR F, VEN ,'$~H-Fc,/~ Cr~URbF VER rlC YLR'i'.ICAL. i){sVIh'lli, l~ aZ.l~U'f,i 2000.23 2100.21 19'11~.21 I X ~,{ 7,% 56 P' -3. 2201).19 2()'7(].19 I H ~'~ 65 5] ~' -2. 2300,1'1 21'10,1'i I 8 i,l bb 26 F -2. 2400.1~ 22'I0,14 I P ~: 69 9 h -2. 2500,11 231(J.11 I 8 N 72 45 u -2. 2600.1t) 2470, lo I H K b~ 58 F -1, 2700,00 2b'10.0b i 4.t m 1'1 40 ~' -1. 2799,98 2899,29 21b~.2~ X 45 S 44 ,} t.; 11. 1C,O FEI;' 0~ Si:,V[R 1'1'¥ 'r [;tso/I O0 O0 04 15 55 4~ 64 78 97 09 19 51 '42 09 33 55 44 '72 H 0 56 17 79 6 b 3 ,,i '11 48 71 ~'l 69 45 49 I q U.00 O.ll O. 27 I,), 08 0.13 O.U9 O. 14 0.20 O, 1.)3 U.12 0,16 U. 20 0.23 O. 20 0.26 'U. 38 0,06 0,~4 O, 00 U.70 0.12 U,i2 0,14 0.04 0,41 0,38 0,03 2.Z7 3,54 0,52 3.10 2.14 2,14 2.30 2.04 1.iq PAGE I DATE bF' 5URYE¥= 2 dUNE 1984 KELbY BUSHING ELEVATION-' 130.00 FT LNG I f'~ EF.;R; }qCBRIDE {{F:C'I'ANGULAR COOROINATES I!t.,RIZ. DEPARTURE NO~t'I'H/$OUITH EA6'I'/wE$l DIS1. AZIMUTH FbJEI FEET FRF:T DEG MIN 0.00 N 0.00 E O.O0 N 0 0 E u,ub N 0.02 E 0,06 N 17 17 E 0.15 N 0.02 W 0,16 N 8 51' W U,49 N 0.24 w 0e55 N 2b lB W 0,89 K 0.58 w 1,06 N 33 5 W 1,2U h U.'/O W 1 46 N 28 37 W 1.50 ~, 0.67 W l~b4 N 24 3 W l.gO ~! 0.~3 w ' 1.98 N 24 48 W 1.~2 ~ 0,~5 w 2,09 N 25 53 W 1,02 N 1.23 W 2.20 N 34 3 W 1.82 N 1,88 w 2,62 N 45 51W 1.97 m 2.~'1 w 3 16 N 51 29 W 1,94 N 2,BB W 3~47 N 56 6 W 1.93 ~ 3,39 W 3,90 N 60 20 W 1.92 N 3.79 W 4,25 N 63 8 W 1,52 N 4.26 W 4'55 N ~9 13 W 1.bi N 4.49 w 4.76 N 70 43 W 1.4b g 4,48 w 4,71 N 72 ~ W 1.b4 W 4,5B W 4,83 N 71 27 W 2.12 N 3.85 W 4,40 N 61 9 W 2.16 N 2.08 w 3,45 N 36 58 W 3,34 N 0,12 W 3,34 N 2 6 W 4,2b N 1,~8 E 4,64 N 23 50 E 5.15 N 4.02 E 6.54 N 37 55 E 5,88 N b.12 E 8,48 N 46 9 E 6.b4 N 8,11 E 10.42 N 51 5 E 7,34 N 10,47 E 12,79 N 54 57 E 7.09 N 14,16 E 15,83 N 63 23 E 0,3~ S 22,72 ~: 22.72 S 89 9 E 11. 28 , 53. 83. llb, 148. 220. 260. 302. Y8 S J3.47 E 35,55 $ 70 18 E 52 $ 42,35 F 51,06 $ 56 2 E ~t, $ 51,57 E 74,24 $ 44 0 E 99 5 62,71 [. 104,82 S 36 44 E Y.~ S 74,87 E 138,00 $ 32 51E 58 $ 91,80 E 174,05 $ 31 42 E 9l S 112,t4 E 214,70 $ 31 {t E 20 5 1~4,53 ~; 258,05 $ 31 25 E 91 & 156.76 k J04,38 ~ 10 59 E 92 $ 181,36 E 353.06 $ 30 54 E ,t ~>A ~; U R I< IJ 'i)I<PTH 4(.)00 o 4100o00 4200 o 4300, O0 44uo, ~) ~..) 4500, O0 4600. Oo 4700~ O0 4900, O0 BO00. O0 5100,0U 5200,o0 5 ]00. ou 5400,00 SSO0,Ov 5600~00 ~800 ~ O0 bgo0, OU ~OO0,Ou blO0,OO 6200,00 6300,00 6400,0 U 6500,00 6600, 6700,n0 0800. 6900, O0 7000, O0 71VO, 713~ V t~RT.I L'A t., J91B. ~'~ 4003. 4OHo.(;t 4167. 424~. I 2 4323,0~ 44 I I , 4 45'11. 4610.93 4 ~ 79,4 4746. 4~ ~6, '~ '/ 4950,32 5025. 5094,50 523U,52 529H.U7 5365.37 5432,9H 5500, 't~ 55~ ~. 09 503~. 47 5772,0h 5841,2~ 5910,46 5{80015 6049,98 6119,69 6141,29 5q19,914 45 h(.} 5 .]~ 28 P 3.1o,20 S 207.04 E 403,38 3.'91,49 $ 2~4,51 E 450,27 438,71 ,5 26.t.09 E 512,06 4M8.38 .5 294,83 E 5'10,48 04u,84 ~ 326,06 E 631.83 595,74 5 359,25 R 095,08 hb2.o9 3 392,50 E 161,62 711,81 ,5 420,32 E 829,71 } /J. 11 ,3 451,05 E 900,66 830.92 S ~90,23 E 972,98 90U,50 5 531,03 E 1045,77 963,99 S 5~7.U9 E 1118,42 1027.03 S 602,59 E 1190,76 1Uq. 9,4') ;; 038.U~ E 1262,58 l lbl,'19 S 073,88 E 1334,44 1214,2J .; 709.96 E 1406,55 12't0,'~8 5 '140,45 E 1478,97 ] 332.73 $ 779.3~ t 1543,89 ]~03,0~ 8 821,11 E 1625,63 1460,09 3 859,40 E 1699,41 1528,98 S 898.25 f: 1773,31 15~1,51 $ 937,12 E 1846,97 lb~3.9] $ 976.09 F 1920,48 177'I.5~ 5 1055.41 E 2067,29 183u,'13 8 1095,~2 E 2140,50 2019.43 :; 1217,98 k 2358,2g 2U;8,'12 S 12~8,]2 E 2429,91 2499 · ,12 u. 9n z592.9.) u. 2137.90 S 1298,59 E 2001,39 ;/iv7.(.)2 S 1339,16 ~: 2572,98 2215,J5 ,S 1351,75 ~: 2595,19 ,'.: ,:,.: q,.,- DgPARI AZlMUT DEG MI" S ]0 52 S 5 $]05 1 2 $ 31 7 S 31 7 $ .tl ,5 S 31 $ 30 55 $ 30 47 $ ,t0 39 $ 30 3.{ S 3O 28 $ 30 24 $ JO 21 $ 30 19 $ 3O 18 5 30 19 S 30 20 15 JO 22 S 30 26 S 30 29 S 30 32 $ 30 41 ,5 $0 4'1 $ 3O 53 $ 30 59 $ 31 5 $ 31 11 S Jl 6 31 8 31 16 E 21 g 2..4 E 2A;,3 KI..IPA Ri~K ,vlORTIJ ,$I,L~PI:, , . 1 r.,~£. ~ ~;;A,5 Il R El.) I) [,; P '1' iI 2,', dul~, 1984 T f,)F HFA:-:,LIR PAGE uA'rE ut" ,.SURVEY: 2 dUNE 1984 KE.I,I.,Y I'~ilS}iING F:L,I-.;VAI'IUNI 1]0.00 FT (;l~l.,~h COuRI',)INAI'ES ,~LIU T H ~.A6T/ i' itORIZ, DEPARTURE BIS,T, AZIMUTH FEET DEG MIN ~2 i,~ 1,23 12 ~] 3.H5 2U $ 2(}7.(}4 bh 5 b31,~3 9~ fi 89~.25 3b 5 1351.75 0.00 N 0 0 E 2,20 N 34 3 W 4 ~0 N bl 9 w 35~55 $ 70 18 E 4o3~3a ~ 30 52 E 1045,77 $ 30 33 E 177],~! S30 26 E 2501,39 S 31 10 E 2595,19 8 31 23 E NJ'lt{']H b~lo(;PF.', ^1.,,' :'>t" h, PAGE 4 I)A'/'I< OF' $URVI':"/: 2 JUNE 1984 KLI,I..,'~ P, LI[':,i'tII'~(.; I':IbUVA',['IUN: 130.O(J ["T 29,88 3u,gI~ -I.u~/,~,b u I,~ ~... ld 4b E 329.75 429,75 529.75 530.U{' ,l,~{:.~(, (J '3 ~' 1.2 32 ['" 62~,75 729.75 73U.u~, 8~,.(',. ,~,, N U C~, U 929.75 93U.Ul, 1029.70 103t,,OP 1929.77 lq'lo.gU 18(;'~.n,, 2029,77 2129.79 213t'.0~? 2229.81 223U.U(; 2830. 12 2931 .09 2930,00 3032.4,i 3030.00 2~.~u:). r,v lt) 24 3134.80 $130,00 3Uu(). C~, 14 ,l,q 3230.3t, 3230,00 3345.54 34]30,00 32t,(,,,,,; 203 3452.d0 3430.00 .}?l,~e.r~ 21 /~1. 35b(). t~3 35J0.00 34Uu,~)L~ J671. 1'1 ]6]0.00 3783.~0 3730.00 3R97.gR 383t).0~~ VEI~]'[¢/~i. f~)GhF:G kF:C'i'/~NGIJI.AR COURD1NATF:8 HURIZ, DEPARTURE ,'SEC'.I'J. Ut~, :;c:Ve. JHiT~. ,'~UhTII/SUu'f}.i LA~T/WI~$T DIST, AZII4U'/'H [' l:i'.'! 1)1,(;I I {.)[: P'i':,t':l' FLL"I FEEl' DEG MIN -2.It.' O.3a 1,90 ]'.l 0,91 -2.25 U.20 1,80 ,'! 1.40 -2.6~ t;.UU l.U'/ ',~ 2.07 -3.Of 0.17 1,9H l! 2,b1 -3.13 u.19 1.91 ~,1 3,01 -3,43 u.27 i,9h r,l 3,55 -3,50 0,27 l,Bq ti 3,90 -3,%(: 0,3{~ 1,b'/ H 4,39 -3,53 U,d7 l,bb f'J 4,4B -:~.a3 {.,. 2B 1,41 N 4,52 0.00 N 0 0 E O.O() N 90 0 E 0,09 U I 21 E 0,25 N 13 9 W O. 70 N 29 44 W 1.2o ta 32 53 w 1.52 N 26 41 W 1.08 N 24 5 w 1,84 N 2b ~3 W 2,03 N 2] 59 W -3. b:', o.'13 I.OH N 4,50 -3.~9 U.4'I 2,3~ io 3.39 -3. ;t-, 9.(~6 2.90 "~ 1.49 -2.92 U.09 3.bO N 0.47 -~.14 (.~, i ~ 4.52 ,~ 2,50 -~.13 O.b~: 7.55 N 11,28 2.79 b.(,1 b.7U g 16.19 2.10 N 25 46 W 2.28 N 37 56 W 2,'19 N 47 59 N 3.28 N 52 51 W 3 bb N 57 3b ~ 4~05 N 61 6 W 4,31 N 64 44 W 4.66 N 70 20 W 4,74 N 70 48 W 4,~4 N 72 ]7 W :5 31 52 ~.'. 32.1h 5.29 i; 20 8 lJ 53,'13 5,09 :< ?u 1~ F .~3.F9 3.76 F~. 20 1(; t'; 119.Ob 2.26 : 27 2t, t' ]'35,,53 3,2n t; 31 1 I': 19~.41 Z.25 ~; .lt.)24 fl 245,{31 ;.i31 3~, F: 3bJ .~'l 1...34 4,81 N 69 34 W 4.12 N 55 19 W 3.26 N27 15 W 3 b3 N 7 26 E 5:17 N 28 56 E 7.13 N 40 49 E 9,06 N 47 59 E 11,07 N b~ 13 g 13,58 N 5~ 12 E 17.19 h 70 20 g 3.85 8 2b,07 E 2b,3b S 81 35 E lv.4b $ 36,66 E 40,18 S 65 49 g ~b,31 ~ 45,22 E 58,03 S 5{ 11 g ~.4,Ub $ 56,04 E 85.71 S 40 49 g 9~,5~ 8 b7,77 E 119.~1 ~ 34 30 E 132.91S 8],09 E 15b.74 S 32 0 E 1t, 9.20 6 104,01E 198ebl ~ 31 34 E 2o9.10 S 128.~5 E 245.24 $ 3~ 30 E 254,04 8 153,03 E 29b,57 S ~1 3 E 302.u'! $ 1~0.83 E 352.06 $ 30 54 E ARC[.1 AbAL-4KA Jt"C· 2A-:3 KUPARLIK ,!JIRl'tt 5L, LIPL, A[.,,,.~I' ii PAGE: 5 I)ATk~ OF 5URVkYI 2 ,JUNE 1984 KEi~I.,¥ BUStiIt.:G EbEVATION: 130,00 .,,. I['i-I'IJI,.ATt ' ~,nl,t ~'.,) t'f3t,~ EVEr! 1.(~(~ I"F.?7.1' ~.it' SUB",%f,A DEP'iH IIi..ilI~JJHETI.) ',JJ:'.':RTJ.('tiI. Vk'.l.-t[It'/.l]~ i:~;¥/,q'i'J,.l:,~ [)J%JD'J'J.J i')[.'r'JT,.i {]p,J~ j'i: [,~',,(; ;4 J'[,, J ,JF:t.~ I [', 4132,V9 4379,35 4509 ~ 2 4,33,,~.~,'; ,~)~.~'~ ~',~ 4642:q0 4782.89 453,~.U~ .~. 40,~ .'~(' 4927.7b 5073.59 4'13u. u~ 4~dr,.,,C ab 24 b21R.42 5352.09 49,]U. 0~) 4"U~;,'~u 45 50 5506.31 '~t) Il). b(i ,i9,,~(', ~l., 4h 24 5651,82 513U,U() 5947,~6 bO95.fiO 5430,U(' b'{~)(,, i~,', a. 7 ,~3 6]90.47 563U.O0 6537.40 57~0,0u b683.~0 5830,00 b'/')(), ~ 4u 24 6828.0b 5930,0O 6971.44 6O30.UO 7114.80 blJf).u(~ '7131,n0 5141.29 0o11,29 VgR'.t](.'/~.I, I~,}(;l,k:(.; iekC'iANGUI.,Ab COU~L)][NAI.'F~ HUHIZ. DEPARTURE 6EC':'It..u L~..V~.RI'J'X NLII~TH/bUU'['H ~jAST/WE$'I' DIS'J', AZIMUTH Fl::h~'[ I,,':';/),.,(~ Fb'.KT F't. ET FEET DEG MiN 410.36 ,% 32 10 }1 4'15.74 ,.'7, 31 j6 ~: 547.R1 ,';31 1 F b18,49 ,'<3t, 27 E 'l~;1.1b :- 29 1~: t.' b 2U 5b t'~ 992.75 :~ 2'~ IN k: lOYN.89 5 2~ 1~ F 12OJ,h5 1.7'2 l.b5 2,2(' 2,b4 .i.. 'IL;. 2.44 I , 4 '/ t),/5 U, 1 '! U.47 35Z,39 :* 210.69 E 410,58 S 30 52 E 400.~3 ,'; 243.94 E ~74,02 S 30 58 E 4hb,12 S 2H0.53 E 543.17 S 3J 5 E 529.'7H ~; 32U,00 E biB.92 S 31 8 E t.,(;U,Sh S 352.25 P; 701,61 S 31 5 E o"1";.08 5 4Ub,92 E '190,46 S 30 58 E '/t, 2.9b G 455,05 E 888,36 S 30 48 E Hb4.b~ 5 bOb,OX E 993,15 S 30 37 E 947.21 S 557,73 E 1099.26 S 30 29 E XUJU,b't S 609e~1 E 1204.01 5 30 2J E :4 2.9 b3 E 13UO,SU ,'q 29 bh t'.: 141(),78 3 3U Z7 It; ibl6,.~l ,q 31 I F; !,f.,;;a.b2 S 3't 3b t:: 1'/33.95 .~ 3i 3b ~7 1~43.1!) ;3 32 1(~ E tgb~,3') $ 33 19 ['7 2()5n. 3q :; ..~J b3 l:., 21hb.72 ,.7 31 ~ K 2272.96 U, 34 O. 04 0. '1 >!. 0,38 rj. 15 0,4 ? u.b2 0 · b ,% )t2U,16 S 6b0,23 E; 130'1.16 ,S 30 20 E ]21~.21 S 712,27 E 1411,15 S 30 18 E 13,',~.J~ 5 '165,b1 F. 1516,77 ~ 30 ~8 E 1,495.~3 S H'IT,~J E 1734,47 fi 30 24 E ~b~.8~ S 935.41 E 1843,73 ~ 30 29 E 1771,72 S 1051 57 E 2060,29 fi30 41 E 1861.4~ 5 1111~01 E 2167,82 S 30 49 E 1949,93 5 1170"bO E 2274.32 S 30 58 E J','t 2~ E 2376,76 3,i 21.i t-:: 2479,0~ 3,1 30, 2H. E 2592.93 0,96 1.5'1 O.UO l.I, L) (1 2036.05 $ 1229.34 E 2378,39 $ 31 7 E 2121,02 $ 12~7,11 E 2481.00 fi 31 15 E 2205.7/ S 1345.17 E: 2583 59 8 31 22 E 2Z15,3b S 1351.75 E 2595:19 S 31 23 E I qC. A t.,/~ ,% .,, z\ TOP UPPFR HASI< Ill'PEN ;~A:,~i, TOP b C] ~.' ~] t-~ l.~B TO'FAb PAGE 6 I'.,'Ai'L, UF SUHVI';I: 2. dUNE 1984 KEL, LY P, IJ~H]fIG Eh["'VATION-' 130,00 IrT EN(;T.r,,I-"E~; HCBRIDE $ LI REC'I'A ~ILIR 't 204 20 '1 212 221 223 227 R I"ACE L, UCAT IfJN Al.' = 227 FWl,, AND 59'/ F,SL NGIJhAR Ct]O~DINATI~S 8,72 3,35 1232.54 E 1258 32 E 1287 73 E 1351 75 E 1303 75 IL 1399 75 IL ARvn' ALASKA 2A-3 KUPARUK ~ORTH SLOPEr ~ARKF'R TOP UPPER SRNI) BASE UPPEI~ Sa.r.:D PF TOTAL DEPrI* BA~E ~OWER SAND TOTAL D~PTt, ~,', i< A S U P. ED PEP'IH [.~, k: .I.., U w KB 2~, d{,J~'l~ 19u4 PAGE 7 DA'rE (}F SURVEY: 2 dUNE 1984 KE61, Y ~USHIHG ELEVATION: 130.00 FT 'r v D 5935,54 5805.54 5q80.15 5850.1b tO31.10 !5901,1o h~41.29 6011.29 61'12,29 6042.29 6240.29 6110.2q SUR O~IGIN: ~EC 13 RECTAN NORTH FACE LOCATION AT 227 FWb AND 597 TNN lIN 8E UN 040,76 & 1232.54 078.72 S 1258,32 121.94 ~ 1287.73 215,35 8 1351,75 233,35 ~ 1363,75 273,35 $ ~399,75 Suggested form to be inserted in each "Active" well folder to d'.eck for timely ccmpliance with our regulations. Operato'r, ~ell Name and Number Reports and Materials to be received by: Required Date Received Remarks ... · Ccmpletion Report Yes ~_/~_ ~ ~/ ~_~~ · ~_Well , History. Yes ? __ / ~ .-- ~ ".~_~/~' -. _Samples ~ ~. . · Core Chips -' .//~/"~/'[::-'--~9~ .... - ~/: . Core Description · ~. - ~ . -- Registered Survey Plat y<~_~ Directional Survey \: . ~_~ ~ /~.~,,~.~ -t2 _ Drill Stem Test Reports .~ --/_/' ~ ~ -- , · Digitized Data :~._~_: ~--~'-'. D~ ('~'~. . ~_. -. ARCO Alaska. Ir'--- ~ ~.:u'~',~ ' Anchorage. Aiaska 99510 Telephone 907 277 5637 Return To: ARCO ALASka, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 8/17/84 Transmittal No: 4691 Transmitted herewith are the following items. Please acknowledge receipt and return-one signed copy of this transmittal. CH FINALS/Schlumberger 1G-16~/' CBL Variable Density 5/29/84 8800 - 9050 Run 1 2A-lA CBL " " GCT 6/02/84 5895 - 7502 " 2A-2~ CBL " " GCT 6/02/84 5291 - 6544 " 2A-3~:'' CBL " "' CIS 6/01/84 4948 - 7092 " /. 2A-4/ CBL " " 6/01/84 6750 - 8018 " 2A-3~ CBL " " CRS/RTS/DDL 6/15/84 6583 - 7081 Run 2 & 3 2A-5 "- CBL " " 6/03/84 7695 - 8938 Run 1 2A-6y. CBL " " 6/03/84 6995 - 8078 " 2A-7 ~ CBL " " GCT 6/03/84 6895 - 7823 " 2A-lA ;~'" Gyro Cont. T°ol "CBL/VDL" 6/02/84 60 - 7454 " 2A-2 ~- " " " " " 6/04/84 60 - 8060 " 2A-3 -/~ " " " " " 6/02/84 60.5 - 7050 " 2A_4~ ,, -,, " " " 6/02/84 60.5 - 8003 2A_6?' ,, ,, " " " 6/04/84 60 - 8060 " 2A_7~ ,, ,, " " " 6/04/84 Surf - 7805 " /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron DISTRIBUTION D&M Drilling Geology -Mobil ~SK Operations W.~]. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith ..... .-.-...;.~ ,~.- ..~ .., . , .--~- ,~': ::.~ :- ,- . . Sohio Union Well Files ARCO Alaska, Inc. · ~ost Office 6,,~, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2A-3 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L30 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JUL1 Alaska 0il & Gas Cons. c0mmissio~ Anchorage STATE OF ALASKA .~ . ALASKA ~ AND GAS CONSERVATION C~ 'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL i-XlX 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 597' FSL, 227' FWL, Sec.13, T11N, R8E, UM~ ~ - 5. Elevation in feet (indicate KB, DF, etc.) RKB 130' 6. Lease Designation and Serial No.'~ ADL 25570 ALK 2668 7. Permit No. 84-51 8. APl Number 50-- 103-20025 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2A-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other OTHER [] 13. Describe ProPosed or Completed Operations (Clearly state all pertinent details and giv, e pertinent dates, including estimated date of starting any Proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 2330 hfs, 06/10/84. ND tree. NU BOPE & tstU - ok. RIH & perf'd 6993' - 6997' & 6898' - 6902 w/4 spf. RIH w/6.125" gauge ring/JB to PBTD. RIH w/Champ Ill-type RTTS & set ~ 6795'. Opened by-pass & filled tbg. Closed by-pass. Tstd ann to 3500 psi. Unset RTTS. (Bled off 150 psi in 15 min.)'. Set RTTS ~ 7050'. Pressured tbg to 3500 psi - bled off 700 psi in 15 minute~. POH. RIH w/conventional-type RTTS & set. ~ 7050'. Pressured tbg to 3500 psi - bled off 100 psi in 15 minutes (no notable annulus returns). Unset ' RTTS. Opened by-pass. Disp tbg w/crude. Closed by-pass. Bullheaded crude to perfs @ 6993' - 6997'. RIH ' w/GR/CCL/RA tracer. Located tool w/btm ejector 3' above top of perfs. Made 1st ejection @ 1/4 BPM, 1800 psi 1-second release of RA tracer - no ann returns. 2nd ejection @ 1/4 BPM, 1925 psi, 5-second release - no annI returns. After 3rd ejection, 5-second released, logged up and caught secondary pulse @ 6975'; logged down an¢ caught pulse @ 6958'; logged up - no further pulse detected. Total of 8 ejections ¢ 1/4 BPM w/2000 psi - 2050 psi. Tracer top appeared to go up to 6931' (no ann returns noted). Made 9th and 10th ejections @ 4-3/4 - 4-1/2 BPM @ 2700 psi - 2525 psi - no further channel detected (most of the flow appeared to stay in the top o~ "A" sand). POH. Bullheaded crude to perfs @ 6993' - 6997' w/10.1 ppg brine. Opened RTTS by-pass; rev. circ dOwn ann. Released RTTS. RIH w/EZ drill SV retainer and set @ 6918'WLM. Pumped and squeezed 75 sx Class G emt. RIH & tagged cmt @ 6896'. Drld cmt,. retainer and more cmt to 6998'. Cleaned out to 7104'PBTD. Spotte. 40 bbls Bridgesal ~ 10.8 ppg on btm. Ran CBL - poor bond. RIH & perf'd 6966' - 6968' w/4 spf. RIH w/EZ drill (converted to a bridge plug) and set ~ 6978'WLM (to isolate lower perfs ~ 6993' - 6997'). RIH w/EZ Drill, on W/L, & set ~ 6916'WLM. Pumped & squeezed 75 sx Class G cmt. POH. RIH & tagged cmt 8 6882'. Drld firm cmt & retainer ~ 6909'. Drld more firm cmt to 6978'. RIH to 7080'; drld junk f/7080' - 7115'. Drld FC @ 7115' & hard cmt to 7160'PBTD. Dropped ball and sheared out circ sub. Spotted 27 bbl Bridgesal pill on btm. (see attached sheet) 14. I hereby, fy that the fO~g~e and correct to the best of my knowledge. Signed / /~.-~,~ (~/ ,/, fJ~¢~,~ Title Area Drilling Engineer ace~~ - %....- /~-- The sp o~o///mission use ConditiOns of Appr~f~l, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 GRU8/SN03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Sundry Noti ce 2A-3 Perforated the following intervals: 6997' - 7016' 7030' - 7074' w/4 spf, 90* phasing 6838' - 6902' w/12 spf, 120° phasing RIH w/FB-1 pkr & tailpipe assy & set @ 6970'. Ran 3-1/2" completion assy w/tail ~ 6987'WLM, HRP-1 pkr ~ 6703' & SSSV @ 1943'. Dropped ball & set pkr ~ 6703'. Tstd tbg. Tstd ann to 3000 psi - ok. Set BPV. ND BOPE. NU tree & tstd @ 250 psi & 5000 psi - ok. Tstd packoff to 5000 psi - ok. Disp well w/30 bbls diesel followed by crude. Tstd tbg to 2000 psi - ok. Closed SSSV. Set BPV. Secured well & released rig ~ 1500 hfs, 06/19/84. RECEIVED JUL! Alaska Oil & Gas Cons. Commission Anchorage KUPARUK ENGINEERING Type of Tape Date T_ape N~nber DISTRIBUTION ?sta'%e Of-AK OH LIS Please note: Blueline, Sign & return t~attache'd<;, copy as receipt .~r~ data. '- Return to: ARCO A~S~~'< INC.. ATO-1115B P.0. Box 100360 Anchorage, AK 99510 Sepia,~ Tape, Photocopy ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2A-1 2F-11 WSP #6I 2A-2 2F-12 WSP #5 2A-3 WSP #15I WSP #7 Oliktok Pt. #2 WSP #9 Thank you. Sincerely, ~ In ~r A~ Engine 3BK/SH1: ih RECEIVED MAY1 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany .--..~-. STATE OF ALASKA ..~..~.~ ALASK . AND GAS CONSERVATION ,VIISSION MONTHLY REPORTOF DRILLING AND WORKOVER OPERATIONS 4. Location of Well at surface · Drilling well ~ Workover operation [] 2. Name of operator_ 7. "err~i~N_..~.1 ARCO Alaska, Inc. / 3. Address 8. ^P~ Nu~nl~r_20025 ?. 0. :Box 100360, Anchorage, AK 99510 50- 9. Unit or Lease Name 597' FSL, 227' FWL, Sec.13, TllN, R8E, UM Kuparuk River Unit ' 10. Well No. 2A-3 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. PAD 94', 130' RKBI . ADL 25570 ALK 2668 For the Month of. April 8,419 11. Field and Pool KPK River Unit KPK River Oil Pool 12. Depth at end of month, footage drilled, fishing jpbs, directional drilling problems, spud date, remarks ' Spudded well @ 1930 hrs, 04/20/84. Drld 12¼" hole to 2630'. Ran, cmtd & tstd 9-5:/8" csg. Drld 8½" hole to 7205'. Ran logs. Cont drlg 8½" hole to 7230' TD as of 4/26/84. Ran, cmtd, & tstd 9" csg. Displ brine from well. Secured well and released rig @ 1200 hrs on 4/27/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36¢t J-55 HFERW BTC csg w/shoe @ 2612'. Cmtd w/750 sxs Permafrost "E" & 250. sxs Permafrost "C". 7" 26¢f J-55 HFERW BTC csg w/shoe @ 7212'. Cmtd w/350 sxs class "G". 14. Coring resume and brief description N/A RECEIVED MAY ! 81984 Alaska Oil & Gas Cons. Commission Anchorage 15. Logs run and depth where run DIL/SP/SFL/GR/FDC/CNL/CAL f/7205' to 6600'. 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "SIGNED ,~~~~~~~ TITLE Area Drilling Engineer DATE O~./.~~7 NOTE--Repor/t/on t,~is~r/ is required for each calendar month, regardless of the status of operations, and must be filed ~n duplicate with the Alaska Oil and Gas~onservat~ommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 l-ITT.T./]V[R ] q,c) Submit in duplicate KUPARUK ENGINEERING . . Well Name: C., PD z.(. f,' 'Bq-f..,S DISTRIBUTION NSK Operation Blueline Dr ill ing Bluel ine Geology/L. J. Bi/Se R&D B lu el in e D&M Blueline ~State B1/SE F.G. Baker Blueline D.B. Schafer Blueline G eology/Ken Film ~gn' & return the atta~A,,0r~D~ copy/~s receipt of data[ Return to: ARCO ALASKA, INC. ATTN:. D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 MEMORANDUM State of Alaska ALAS~ OIL ~AND GAS CONSERVATION COM~iISSION TO: C. ' terton DATE: Cha~z_~~l]~ FI LE NO: THRU; Lonnie C. Smith TELEPHONE NO: Co~issioner April 30, 1984 D.21.14 FROM: Harold R. Hawkins 2,~4¢,~,./.?~ SUBJECT: Petroleum Inspector Witness BOPE Test ARCO Alaska, Inc., Kuparuk River Unit 2A-3, Sec. 13, TllN,RSE,UM, Permit No. 84-51. Saturday, April 21, 1984: I left Anchorage at 2:40 pm by Alaska Airlines t° P-rudh~ Bay~ arriving at 4:20 pm and at the Kuparuk River Unit 2A-3 at 6:30 pm. Sunday.,...Apr~i! 22, 1984..- I witnessed the ROPE test and checked the 'trip t~nk, flow 'line indicators,-that, operated okay. There were no failures. I filled out an AOGCC report which is attached. In summary, I witnessed the BOPE test and checked the mud flow line indicators on Doyon Rig No. 9. The BOPE"s tests and flow line indicator checks were satisfactorily performed. Attachment 02-00IA(Rev. 10/79) O&~ ~4 ~/ao STATE OF AI,ASKA OIL & GAS CO:;$EF:VATiON CO:.IHISSION B.O.P.E. Inspection Report Inspector Date, Wel 1 --- Operator t/~/f~O /4~./~ ,f/~4~. /,0~4'L Representative./34g~-~- / Well /~/2~/~FU/F ./~f~/~ ~/3/~- .~/~-3 Permit # .,-- Location: Sec /3 T//~/ R~6U ~, /~-~.~ Casing Set @ ~ J // ft. Drilling Contractor /~ ?.49 / DO//~-~Rig ~ /. ~ Representativ~./~O)/~/~AfP~qzg/° Location, General , Well Sign . ~/~ General Housekeeping ~7/~ ReseJve pit . Rig ~/~ - BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ~ ACCUtIUb~TO R S'YSTEH ,,Full Charge Pressure. ,9.~/C~0~ ps.ig il Pressure After Closure ./ ~ psig 200 psig Above Precharge Attained: -- Full Charge Pressure Attained: Cqntrols: Master . Remote (9/~ Blinds switci~ cove_r Test Pres.~ure ~?~ dO Lower Kelly, Bal 1 Type Ins ide BOP Choke Manifold ~:o. Valves. / '3-' I40. flanges Jd Adjustable Chokes ?~0 Kelly and Floor Safety Valves Test Pressurq Test Pres sure Test Pressure Test Pressure Test Pressure /'est Results: Failures .... llydrauically operated choke _~~ Repair or Replacement of failed equipment to be made within ~ days and"" Inspector/Corem/anion office notified. ,PI ~- . .V~9~ ,tl,<,c/, ~zo ~ 4 /~- /~'Q I,<-,4 7'~P?/ o/¢ ~min~ sec min .~0 sec Distribution orig.' - AO£,GCC cc - Operator cc - Supervisor ARCO Alaska, Ir Post Offic,. ~.,~x 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 April 9, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2A-Pad Wells !-8 Dear Elaine- Enclosed is an as-built location plat for th'e subject wells. If you have any'questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG6/L85-tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~2 0 ~ 0 ~o0 ~0 013 0~5 / 0 ~6 80 Gl 70 Oz' 50 04 14._~1:5 25 I 2_4 LOCATED IN SECTIONS _ T liN',. RSE. UMIAT MERIDIAN. . o. - . . .- ~ .- _ . D.S 2-A . _ DRi~L.L. SITE 2.A CONDUCTORS BUILT LOCATIONS WELL-I ¥: X · 498,G2QggG 227'FWL, 717~SL LAW.= 70° 18' 0836 "/'3" LONG: 150° OO' 40Zll" EL =.94.3, 0G:89.9 WELL-2 y = 5,960,078.4ZD LaT=70°lS'077789-' X= 498,6ZD. 914 LONG =lSOOCO~ 4'0213" - 227' FW'L., 657'FSL EL: 94.4, OG =89.8 WELL-$ y :5,960, 018. 185 LAT = 70° 18' 071865'' x: 498,620.91Z LONG '- 150° O0'40213' ZZT'F'a'L~ 597'FSL ' EL= 94.4~ OG= 89.6 WELL-4 Y: 5,g 59,958.355 LAT =. 70° 18' 065580''' X= 4c--~,SZO.g69 LONG: 150°O0'40ZII# Z?..7'FWL~537'FSL ' EL=94.SiOG=90.4 WELL -5 Y=5~959,958.?-61 LAT = 70°16'065965= X= 498~340.910 LO..NG=ISO° 00'48376" 53'FEL ~537'FSL. Et.=D4.0mOG:~9-5 WELL-6 Y = 5 ~960,018.:541 I_AT=TO° 18' 071874'" X-' 498~340.95G LONG:ISO°O0'48376'' 53'FEL~ 597' FSL : EL'-95.9~ OG ~- 8 9. E. WELL-7 Y= 5,9G0~07 8. Z 81 ~(~ 498~3 40.9 06 53'FEL= 657'FSL ' LAT-= 70° 18'077769' LONG = 150000'4 8377' EL=93.8,0G:88.7 WELL-8 Y :5,960, 13 8. 371 X = 498m 3 a,.O.g"K~ 53'FEL~ 717 FSL LA, T= 70°! 8'08~6 80" LONG=IS0°00'4 857 7" EL.=95.7~OG=87.8 DAVID FILUCCI 5276-S LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF. ~ TH~, THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION ~ THAT ALL DETAILS ARE . ~~;~ ARCO Alaska, Inc. CONDUCTOR AS'BUILT ~ ~'~ ~' ,~ LOC AT I 0 N S ~ ~~ Date: 5 21 84 Scale: I = 300 . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 5, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2A-3 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. We expect to start this work on May 31, 1984. If you have any questions, please call me at 263-4970. Si/~9~ely' A~ea D~illing Engineer TLF/JG'tw GRU6/L79 Enclosures ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASK~ OIL AND GAS CONSERVATION L, oMMISSION SUNDRY NOTICES AND REPORTS ON WELLS - DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360, Anchoraqe, AK 99510 4. Location of Well . Surface: 597' FSL, 227' FWL, Sec.13, T11N., R8E, UN 5. Elevation in feet (ir~dicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7. Permit No. 84-51 '8. APl Number 50-- 103-20025 9. Unit or Lease Name . Kup~_rUk River I_ln~t 10. Well Number 2A-3 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. 130' RKB ADL 25570 ALK 2668 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-t70), ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. ThE subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: May 31, 1984 Subsequent Work Beported 14. I hereby cer, t-iC~that the foregoing is .true and correct to the best of my knowledge. Signed /~~/~_~_~,__~~ Title Area Drilling Engineer The space ssion use Conditio~ of Appr~v,~f, if any: Date Approved Copy ~. ~eturr~ed Approved by COMMISSIONER the Commission Form 10403 Rev. 7-1~0 GRUG/SN36 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate M~reh 29, 198~ Mr. Jeffrey B. Kew_in Area Drilling ~gIneer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2A-3 ARCO Alaska, Inc. Permit No. 8~-5t Sur. Loc. 597'F~To_~, 227'~, Sec. Btmhole Loc. !503'~, 1424'F'~L, Sec. 24, TllN, RSE, t~,!. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced w~ll. If eorlng is-conducted, a one cubic Inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized Iog information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous .fish, Operations in these a~eas are sub!eot to AS !6.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Devartm~nt of Fish and Game. ~ Pollution of-any waters of the State is prohibited by AS 46, Chapter 3, ~tlcla 7 ~nd' the regulations promulgated thereunder (Title 18, Alaska Admin~strative Code, Chapter 70) and by the Federal Water Pollution Control Act, a~ amended. Prior ~o c~encing operations you may be contacted by a rePresentative of the Department of Envi~onme-nta! Conservat!on~ To aid ua in mcheduling field work, please notify this o~..,~.~= hours prior to commencing installation of the blowout prevention - ~- :~arch 4 e~t,.l~m~n~ so that a representative of the Comm~ss~on m~V be present ~n ~itness ~s~n~ of "h= e~ni~ent before the surfac~ casing shoe is drilled. ~ere a ~iverter system is required, ~a=~ alson~~~ thi~ ~c~~_ ~ ~ ~ ~ honr~ prior ~o co~enc~,. ~n~ before ~ ~ below the shom of ~h~ conductor ~ ~ In the event of s~mpe~s~on please give th~.s ..... ~ ~ j ' a~v~nce not~f~cat~on ~o that we may ha~,e a Very truly vonr~ C. V. Chatterton C ..... servat~on Co~ission Alaska Oil and Gas o= .... ~- cc: Department of Fish & Garage, Mabitat Section w/o enc!. Depart~nt of Envlronment~! Co~servatlon w/o eno!. ARCO Alaska, Inc. Post Office B~,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Harch 27, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2A-3 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 2A-3, along with a $100. application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on April 21, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG6L65: tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA L,,~ AND GAS CONSERVATION CO,~,MISSION P :RMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL ~( REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~]X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 597' FSL, 227' FWL, Sec.13, T11N, R8E, UN At top of proposed producing interval 1251' FNL, 1281' FWL, Sec. 24, T11N, RSE, UM At total depth 1503' FNL, 1424' FWL, Sec. 24, TllN, R8E, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 2A-3 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 130', PAD 94' ADL 25570 ALK 2668 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 3777 feet 2A-2 well 60' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7070' MD, 6221' TVD feet 2560 04/21/84 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2715 . psig@ 80°F Surface KICK OFF POINT 2750 feet. MAXIMUM HOLE ANGLE 41.3 oI (see 20 AAC 25.035 (c) (2) psig@ 6071 ft. TD (TVD) 3120 21 Proposed Casing, Liner and Cementing Program i SIZE SETTING DEPTH QUANTITY OF CEMENT Hole 24" Casing Weight 16" 65.5# 9-5/8" 36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade I Coupling H-40 / Weld J-55 HF-IRW BTC ~J-55 HF-IRW BTC Length MD TOP TVD 80 36' I 36' 2580' 35' I 35' I 7037' I 33' I I 33' I M D BOTTOM TV D 116'1 116' I 2615~ i 2615' I 7070'16221' I I (include stage data) ± 200 cf 546 sx Permafrost E- ~-- 250 sx Permafrost C 300 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7070' MD (6221' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. it will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2715 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will b~ tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig will be covered under a separate sundry notice. 2A-3 will be 60' away from 2A-2 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The space use Samples required i I--lYES [~0 Permit number APPROVED BY ~(~~~~ -- _ Form 10401 GRUS/PD23 TITLE Area Dri 11 lng Engineer DATE CONDITIONS OF APPROVAL Mud Icg required Directional Survey required APl number []YES ~ ,,~.Y__ E S []NO 50--/C~ ~ - ~l.~ Approval date SEE COVER LETTER FOR OTHER REOUIREMENTS -"'-) ,,...-,, 0 3~ 2~/8 4 ,COMMISSIONER DATE March 29, 1984 by order of the Commission Submit in triplicate I ~ ~T-~~ - ~ ~ ~ ~ --~ ~ , ~ · ~ i i t : '. ~ ~ ' ' · I ' i i i . . ~ ; : i~ .t,~m~2~ '. ~ ~ ~ ~ ', ~ : i ! ~ t t : ~ J Iii i ; . i i, ~ ~ i i ~ '. ~, [ ~ [ [ I' i~ ~ ! I~ '. ~ k i I ' ' i ' ' ' I : ~ , ' ' I . - i I~ !i ---:. ' :.,: f -H-H ........ . : ~ ~ , , . , ~ ; . , ;~_~_ ~ , i , , : , ; ' ' ~_ {~i: ~i ~ ~',i~ i~i ~:, , , -~,, ~ ~", ,, , ,':~'": '' ~ i ,~, :~:=__~;~ :~: .;~ i~, iii} . t i i , i i ;~-] i:i.LL :TT[ i ~ i i ~ i i i ! i i ~ ; ~ ~ i i { i i ~ ! I i !~i~ I i ~! ~ ~ i'I i i I I~ i i i i i ! 1 i i{ ~ j 'il'! I I i I i I i i i i i I I RI ,~ ~lli~ Ii~q~> I i i I ~1 ii',l I I I { { I ! ~ I ~ { i { I ' ~ i I l~ ! I l'{ ' i I i i i I i i I ~ I I i I I i ! ; { , , , i_, li.i~_ ,Il , ,~, k , ' '' -'i!I ii , , , ~i; iii~ i i[ii [* iii [ill fill · llli {I', i. ili iii:: '~il I~ ll'l , ' _ ~ ~ ~ ! I I i i I I ~ i i i ~ ~ i I i ' i I i l~ t . I ~ ~ ~ f ~ , r-; ~ ; [ { i i i I i ' .... ii,_ :::~ , ilii ~ll{ i{i~ il{i .... ~{l~ : i{ { ii ~!i{ ' : ~ ...... {:ii l{il ~${~ i i i [ bi.J ! { ]Iii [I I , i : { I { &~ i , i : ; ~ i I i I i ~ r ~ , __~.~.~ ~ : ~ ~ _~ ,, ~ ; : ~ , ~ . ~ ~ : : : . I , : I ~ ~ , , , ~ ' ~ i i ~ ¢,~ i , . ,, ~, I · ~ ; ........... : , , ! i i I i i i I i i ! i ~ ~ i ! i ' ; ;~: ~ : ' : ~ I i i i i ! i ~ I ...... . . .. ii~:, ~i~ . I ~ ~ i ! i I i I I i!1 ..... ~'.. ~ ~ ~ ~ ~ !il! !iii i !ii~ I!~i ~, ~i ~ !~ i__~ i ~ i:: ! I1 .I i1i _.: .,. ~~_:; .... ,,~ ,:,: ,Il, : : ''' ~ :ii{ ijIi ....... ~:, : _ , , , ~, , ~ ~, ~. ~. I ! i I II - ii 6 ¢' Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & Ooeration Upon initial installation close annular preventer and verify 6hat 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 in well under any circumstances. 16" Conductor PREYE TE PIP~ ~ BLIND }ID 2 DIAGRAM 41 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco s%ar%ing head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13~5/8" - 5000 psi pipe rams B. 13-5/8" - 5000 psi blind rams 9. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FI_UID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13. 14. 15.- 16. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHF.3%D. RUN IN LOCK DOWN SCREWS IN -HEAD. 3. CLOSE ANNULAR PREVENTER AND V. AL~V-]~S TLJPS~ O1~ C/-]O~S. DON-~ TBST AGAINST CLOSF_D CHOI<BS. 4.TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0 8. 'PR SSUR DOWN OF ODK ISOLA?TON V/)uT_,.V]~S. TO ZERO PSI TO TEST VALVES. TEST RE)iAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO 7.ERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY CDC)CS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (2) Loc ........ thru 8) (8) (3) Admin ~;~;.~, 5-' ~4' ''~ f~ ( 11) 10 and 11) (4) ,C,.asg //y/zz .~- ~ ,-~ (12 thru 20) (5) BOPE ~,~fff C-C~'~q (21 thru 24) 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 well bore plat included .... ' ...... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait ....... , ....... i 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20.. 21. 22. 23. 24. REMARKS 25. Does operator have a bond in force ................................. Is a conservation order needed ...... Is administrative approval needed .. . Is conductor string provided ......................................, Is enough cement used to circulate on conductor and surface Will cement tie in surface and intermediate or production strings Will 'cement cover all known productive horizons ................. Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and ~grst Is this well to be kidked off from an existing wellbore .. Is old wellbore abandonment procedure included on 10-403 ........... Is adequate well bore separation proposed .......................... Is a diverter system required ...................................... Are necessary diagrams of diverter and BOP equipment'attached . Does BOPE have sufficient pressure rating- Test to Does the choke manifold comply w/API RP-53 (Feb. 78) .. Additional requirements ............................................. ~ Additional Remarks: Geology: Engineering HWK ~:c,.' LCS~.~. BEW rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE i 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. · I-- LTS VE~ IF~. CATIC]N' I~ISTING IINI:T TYPE CATE SIZE CODE o00 o0o 016 0~5 000 000 004 0:65 0oo 0o0 008 065 000 000 002 065 000 00(,) oo4 065 000 000 002 065 00() OeO nO8 065 000 000 006 065 o00 o00 004 065 OB ~}~.~FR AT .ACC: 60!.81 YDE, ~-'~..~Ti) = WEIGHTED E~TST'.I'.'Y = lO.1 l,~/('. ,, R~. = 3.060 ~. 80 DF ISCf'~S'II'Y : 3~.(~ S R~F = 2.350 ~! : 9.5 ~,(~ = 2.420 bOG TYP~7 CLASS ~OP ~O. I.,EVEL CODE 69 68 6~ 6 6~ 6~ 4.7 5 3 9 'ir L t3 3.7 '7 1 5 I b ~'~ 4,0 0 O0 fi,0547 n, c) 24. 9 l,.: R a T 1. ~ 4 ?. n 0 n 0 F' C ~ 11,, 261 ,950o GR -99q. ?500 UR,~T -099,2500 ~33,6250 -999,2500 FCY t., 3.767~ Th ] 41.,3'15() 6. 09711 93.1250 3.1,42:6 707.00(')0 ¢{n. I1562 ?. 4922 1 t 6R 12.1641 83,3 '150 ~.46. nog0 ~.. 8 r,'.52 !17.3125 3,4~6~9 567. 000 2.0.137 !43.2500 3.4893 'i06. 3.8~67 955. ~! 25O 3.3'7~ 1 483. nO00 2,7598 ~ 61.25 n ,'.) -099,2500 3,57~3 ~33,6250 -qgq,2500 -n99,2509 ],3242 1.4:~ ,3750 -qgO.2500 -9gg, [250 O C A l', T [, P CAI.., c AT,X C A 1,, I TLM CAT.,[ CAT, C A L T [,~ C~LI T CAT, E[ T i,,~ C~T.i 50 n 0 3.957o ,226 (3 3477 6.44'14 3' .4141 1,5,3359 ~. 9375 I 3. ~172 9. ~109 3 ' 0762 2,0703 ,4375 ..~719 2,!.367 0.4375 3.8,379 g.47~6 3,8125 ~,9785 9,5313 -g99,2500 3,7246 q 8750 .99q' · .2500 3,4.805 !~.0469 -999,2500 4. r~O08 1,3~, ~500 -99c' . 2500 1. 1 P. 75o0 -099. 4,3906 12..31.25 -099. c~99 ~. 2500 3:' 8867 1.1 -t~99. 250O 5.2 5 0 -99q, 999',~5 4.0195 ? 5 o ("~ 25O0 3,5977 .! 4,,0. 2500 -q99, ?5o0 -999.~500 ,3.654:3 ~ 16.0625 -999,250(.) 1.1.7.I875 q 99. ? 50 () -n99.2500 3.0313 ~ ~ R, 75o0 -99o . 25~0 -~g0.2500 ,I)__. ,q. '7 P 9 0,,4. q3'! 5 -o9q,, ?5OO -099. ,2500 5.85~4 85.3125 -q99.2500 -099. ?500 3,671.9 62.25o0 -qc]9,2500 -099.25°,0 CA[,I [':! ft R A (" II!,, l P,N~A T L~'~ CALl CAf.,,[ CAI,l: ~664, 7891 25OO 4 0234 10 6875 -Og9 2500 3,6660 lO, 1:875 -990. 2500 4.¢,875 q,9141 -999.25OO -999.2500 3.i891 1,0. 156 -999. 3.5410 9,~!41 3.1309 9.91a, I -q99.~500 2,q66B 9,8359 -099.2500 6og609 9.4141 -q9g.2500 3.~t)47 10.3672 -099,25o0 2.6738 ! ~2, ~7 ~(,~ -e99. 2.19 c'.~ 2 210,,2500 , .,':,. 2.~ . 0 4. ~ 67,75n0 - 6 9 <~ , 2 5 0 _ t~ g q. z . ~ ~7~ -qq9,25 -999-2500 ~ '7285 I 0 q. 1 ~ 75 -g99,2500 -09g. 2,0629 -999,25n() -o99.2500 ~, ~ 660 ~ 1.~ ,4375 - 6 9 ,2 5 -099. ! 11 .norm -ggq. 250 {) -qgg, 2.4492 ! I 7. 3750 -990,2500 ~. I O55 I 16. 6250 -ogg. 253o -~9q. 2500 2.7 3 4 4 !, {')~. -gg() 2.8457 10,'137~ -099.2500 9, .... 297 -999. 4:?f413 tO 1750 -999 2500 I, 9'!55 10.3125 -99g. 25nn 9,7266 -999. 2500 3.0313 9,2500 -Q99.25nO 3,2656 -999.2500 2,4395 lO,0313 2.4590 10,1953 -999,,2500 3.2lo9 9.6953 -n9g,2500 2,7441 9.6094 -99g.2500 r;' ,'o T 30 t", n OOnil qFT.ii . o 9 q. 9 5 0 ~) t;' C :,,~ I, 3.3 7 ~ 9 T 13 137.82 g 0 ~ R -qgg. ?fig0 5.5313 TLr) 97. c,)375 CR -0<,)0. ?5n() FCI, '2, ] 074 107'8125 -999,,,2500 '~99. 2500 -~99. 2500 -99q. 2500 ~'CNL .~. 03 ~ 2 1 L n 99.5 f) 0 u C R -999. ~500 ~:.R~,T -n99. 2500 F(,?. W I., 3 o 4 34 '9 I 0,:,.t ,,, _ 375 -ogq. ?500 -o99.75n0 ~'CNI ?. 3],25 87,4,3'75 -09a.2500 .o9q.2500 3 ,. 2 109 T t..:f) 8'7. 0000 .ag 9., 2500 iUR ~T 'Oq9 ,, ..9,500 5.6875 TL, n 9!. ,0675 -990,9,500 r'RaT -999.25o0 3. 1. '197 1. 1i.., P 1. 09. (';250 dR .-ogq, ?%0o :3,3750 1. 37,62~S0 - q g o. 2 5 O 0 ,~ .:~. 25 97. 0375 -,q99.25,30 .- 099.25 ,ri 0 2.30 0 8 t, 07.8125 -999,2500 -~99,2590 3. 2919 107 . 3750 -999. 2500 -q9° . 2500 3.0a, 69 ~.,1875 -099.2500 -099.2500 3.0215 99. 5000 -9i~9. 2500 -,:~9~. ,. 3 7 ,:~ 104,9 ~" -ggg,?500 -99go2500 ?.5449 -999,2500 -099.2500 3.3789 87.0000 -999.250,) -999.2500 4.2579 91.0625 -99e,2500 -999.2500 109,6250 T T ~r C A L 1', CA[,I R N R A CALl Cat.,I RNRA T 1.., Yl CALl R l',~m A CAf, 11, P, N R A T L ~ CALl: CALl R I'~R A C A 1, I CALl -qgg, 2500 3.900:4 ~ ~688 -999~ 500 8,9S:31 -999.2500 3.3945 9,2734 -99q.2500 2. 9941 9.4141 -099.25C)0 3.R301 9.5781 -q99.2500 2,34.3R 8.710 9 -999. 2500 3.3359 10,3750 -090.25O0 4.5938 1.1..17!9 -099.2500 2.5703 12,078l ° -67, ~ 5.3184 TLD 200 ri.. o000 'f Lr' - o 9 O, 2500 r,,, R .t q 99 ' 2 50 o f:' C N 15 2nO0,0000 ILD -999,2500 -999. 250() 6.1133 81 .7500 -g99: 500 6. 824.2 . 89.3 7 S 999 .~500 -999.750o ,1, o,7969 65, -99g. 2500 0 0 O0 ,6563 2:00'{ 250'0 C A 1, I I. L a C ~ L 1, PhRA CA L I C A L I -o99.25C)0 5,2266 g,5~69 -ggg.2500 5,~031 563 -qgg.2500 5.914'1, -990,2500 2000,0000 9.~906 -o99.2500 2000,0000 q,3906 ; RF},,T, ff' a ,^ ,I f, [f !'> *:; ~Th: :9.4./0C;/!5