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185-307
THE STATE °fi-I - - - GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3I-01 Permit to Drill Number: 185-307 Sundry Number: 318-429 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaskc.gov Enclosed is the approved application for the 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, Hollis S. French iL Chair DATED this t0 day of October, 2018. R13DMSi- OCT 10 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SF , r -r5 Lo(1a /if 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend p Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CO261 B Whipstock ❑� . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑' Stratigraphic ❑ Service ❑ 185-307 • 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 50-029-21514-00—W 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 31-01 ' Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25521 Kuparuk River Field / Kuparuk River Oil Pool ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9030 • 6542 8919 6460 4829 N/A 8782 Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 16" 104' 104' Surface 4315' 9-5/8" 4346' 3304' Intermediate Production 8986' 7" 1 9010' 6528' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8734-8760,8770-8798 6326-6345,6352-6373 3-1/2" L-80 8747 Packers and SSSV Type: Packer (Baker 4782 FHL) Packers and SSSV MD (ft) and TVD (ft): Packer (8535 / 6179) 12. Attachments: Proposal Summary , Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 24 -Sep -18 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 20 -Sep -18 % Commission Representative: Victoria Loepp GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Keith Herring Authorized Title: Staff CTD Engineer Contact Email: Keith. E. Herrin 00 .COM Contact Phone: 263-4321 % POoze Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: U Zq Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes ❑ No Subsequent Form Required: �(7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: RBDMS oCT�t2afpegl���� Submit Form and I Form 10-403 Revised 4/2017 Approved applicat he date of approval.t/� A achmentq in Duplicate "0�y z7 - 1 7Z4 -/v ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 25, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set a second whipstock in the KRU 31-01 (PTD# 185-307). Attached to this application are the following documents: - 10-403 Sundry Application for KRU 31-01 - Operations Summary in support of the 10-403 Sundry Application - Proposed Pre -CTD Schematic - Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, /;41� Keith Herring ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 31-01 (PTD# 185-307) Summary for Sund Background KRU well 31-01 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize six laterals to target the Kuparuk sands to the west and north of the existing 31-01 wellbore. The laterals will increase throughput and recovery from a potentially sheltered corner of a fault block. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line set an inner wedge in the tandem wedge at 8729' MD on 9/10/2018. Nabors CDR3-AC rigged up over 31-01 and the rig was accepted on 9/15/2018 at 09:00 hrs. Nabors CDR3-AC began milling the window at 8,729' MD on 9/17/2018 and drilled the 31-01L1 (PTD #218-087) lateral to a depth of 10,022' MD on 9/18/2018 prior to getting suck in the window. The drilling bottom hole assembly (BHA) was successfully pulled free from the window. However, while attempting to cleanout the wellbore the cleanout assembly became stuck across the window on 9/21/2018. ConocoPhillips was not successful in recovering the stuck BHA. The L1 lateral has been renamed to the 31-01UPB1 since it can no longer be accessed. Nabors CDR3-AC ran and set a backup whipstock at 8,682' MD on 9/24/2018 to mill a second window in order to drill the six laterals premised in the project objectives. The six laterals will be drilled in a different order than originally planned but all targets for the permitted laterals remain the same (please - reference the updated 31-01 proposed CTD schematic). 31-01 Proposed CTD Schematic 16" 62# H-40 sho @ 104' MD 9-5/8" 36# J-55 shoe @ 4346' MD ITOWS an. 8682' MD IBU KOP(] 8700' MD A2-s.7d perfs 18734'- 8760' MD [Al .7d perfs 8770' - 8798' MD 7" 26# J-55 shoe @ 9010' MD 3-112" Camco MMG gas lift mandrels @ 3129' RKB Baker Orbit Valve @ 3596' MD 3-12" 9.3# L-80 ELIE 8rd Tubing to surface 3-12" Camco MMG gas lift mandrels @ 4929', 6250', 72711, 8002', & 8464' Baker Locator @ 8517' RKB Baker PBR 80-40 @ 8522' MD (3" ID) Baker FHL Packer @ 8535' MD (4" ID) 3-%" X landing nipple at 8588' MD (2.813" min ID) Top of Wedge Assembly @ 8698' RKB 3-'/3" X landing nipple at 8712' MD (2.813" min ID) Top of Wedge Assembly @ 8728' RKB 3-1/2" X landing nipple at 8742' MD (2.813" min ID) Baker WLEG @ 8747' MD 31-011P81 TO @ 10,032' MD TOP Of fi$h -8,697' MD 31-03L3-52 wp81 TD @ 11,925' MD Top Of liner @ 8,675' MD 31-O1u41.P02 To @ 12,250' MD Billet @ 9,200' MD 31-01L1 wp03 iD @ 11,900' MD Billet@30,650'MD 31 1-OSw�l @ TD12.055MD Billtt @ 9,085' Mp 31-011-04wp01 TD@Bit@ 12,0M'M D 31-01U-03 wpD2 TD @ 12,097' MD B111e1 @ 1ojw Mo VOF T4 • w //7,- 's THE STA Alaska Oil and Gas •+ AL A S KA Conservation Commission Witt : GOVERNOR BILL WALKER 333 West Seventh Avenue Anchorage,hAlaska 99501-3572 ®1"ALAS� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Ron Phillips Sr. Wells Engineer Jury ����� ConocoPhillips Alaska, Inc. PO Box 100360 ib Anchorage, AK 99510 SCOW Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 31-01 Permit to Drill Number: 185-307 Sundry Number: 318-235 Dear Mr. Phillips: Enclosed is the approved application for the 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, Hollis S. French Chair DATED this u day of June, 2018. RBDMS: 1UN 12 2018 REcovED • • STATE OF ALASKA JUN a ' 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 2 • Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Lij Change Approved Program❑ wo Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ other:Nerig in Kuparuk 22.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:)60-77,frr C ConocoPhillips Alaska,Inc. Exploratory 111 Development ❑• 185-307., vf--y 3.Address: Stratigraphic 111Service ❑ 6.API Number: P.O.Box 100360,Anchorage,AK 99510 50-029-21514-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 31-01 • Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25521 • Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): 1Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 9,030' ' 6,542' 8,919' 6,460' 3,335 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 16" 104' 104' Surface 4,315' 9.625" 4,346' 3,304' Intermediate Production 8,986' 7" 9,010' 6,528' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8734'-8760',8770'-8798' 6326-6345',6352'-6373' 2.875" J-55 8,651' Packers and SSSV Type: Packer(Camco HRP-1-SP) Packers and SSSV MD(ft)and ND(ft): Packer(8,574'/6,208') SSSV(Camco TRDP-1A) SSSV(1,780'/1,639') 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 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: 6/7/2018 OIL ❑., • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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. Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: Sr.Wells Engineer Contact Email: Ron.L.PhillipsaCOP.com � � Au.- Contact Phone: 265-6312 Authorized Signature: i W �' ) Date: 6/3/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31,z 35 ElPlug Integrity ❑ BOP Test g/ Mechanical Integrity Test ❑ Location Clearance Other: 5e f i' -t-e, 3.5-e),0 175_17 4 f-r n v/q,—f,r e-Ve-s-, f cr' 74r-a-t, -/0 2 5Go 2 -1 -D (1 C' C co r) -1- /I-73 t✓) f r-) rip 55 )`.� \ Post Initial Injection MIT Req'd? Yes ❑ No �� "41'1 Spacing Exception Required? Yes 111Nod /77 re fiSubsequent Form Required: /D a�L \ ��I� APPROVED BY r I Approved by: „ COMMISSIONER THE COMMISSION Date: t{ t; vrc 6/11/» —n ' �. L RBDMSL� 2018 JUN 1 Z Submit Form and ggr�]O p3 Revised 4/2017 Approved appli ti v he date of approval. �� ttachments i ponlicate "t E J o ` VVVIII 70)r - '/v • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 03 June 2018 Commissioner 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 document the startup of AAO Rig#111 in Kuparuk on the workover for Kuparuk Producer 3I-01 (PTD#185-307). Kuparuk well 31-01 was originally drilled and completed in 1986 as an 'A' sand producer in Kuparuk. In 1991 the A sand was re-perforated over the original interval to improve production. In March 2008 a tubing leak was found at 8,384' and patched.The well was recommended for a workover to repair/upsize the tubing from 2-7/8"to 3-1/2" prior to a CTD sidetrack. _- -- The proposed workover scope for 3I-01 will include pulling the 2-7/8"completion with packer and then installing a new 3-1/2"completion to prepare for CTD. This work will be performed by the All American Oilfield Rig#111,which is a new work over rig to the North Slope.AAO#111 also intends to work over a second well, 1F-07(PTD#182-156),with a scope that doesn't require a 10-403.A MPSP will be submitted to Victoria Eer son-at a later date,per her request. °epp If you have any questions or require any further information,please contact me at 265-6312. Sincerely, gr''' Ron Phillips Senior Wells Engineer CPAI Drilling and Wells • • 3I-01 Rig Workover CTD Setup w/New Rig (PTD#: 185-307) Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 2-7/8"completion,and install a new 3-1/2"single packer completion. General Well info: Well Type: Producer MPSP: 3,335 psi using 0.1 psi/ft gradient Static BHP: 3,848 psi/6,054' TVD(12.3 ppg EMW)measured on 05/03/2018 Reservoir Pressure/TVD: 3,967 psi/6,326' TVD(assuming 8.4 ppg water between gauge and top perf) Wellhead type/pressure rating: Cameron Gen IV,5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Pipe Rams MIT results: MIT-IA PASSED—05/7/2018 MIT-OA PASSED—05/7/2018 IC POT&PPPOT PASSED—2/19/2018 • TBG POT&PPPOT PASSED—2/14/2018 Production Engineer: Ethan Plunkett Workover Engineer: Ron Phillips(263-6312/Ron.L.Phillips@ConocoPhillips.com) Pre-Rig Work 1. MIT testing. SBHP test.TBG and CSG PO tests. 2. String shot and chem cut first joint above packer. 3. FT LDS,grease tree valves and set BPV. Workover Procedure 1. MIRU.Pull BPV. Circulate workover fluid. Obtain SITP& SICP, if still seeing pressure at surface,calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 2. Set BPV&blanking plug,ND tree,NU BOPE and pressure test rams to 3500 psi and annular to 2500 psi. 3. Pull blanking plug&BPV. Screw in landing joint,BOLDS's,and pull tbg hgr to the rig floor. 4. POOH laying down 2-7/8"tubing. 5. RIH on DP and fish tubing stub and seals. 6. RIH on DP and fish Camco HRP-1-SP packer. 7. Perform a production casing clean out run to perforations. 8. RIH with 3-1/2"single packer completion. 9. RU E-Line and correlate packer depth to ensure set depth is accurate. Set WRP in tubing tail.RD E-Line. 10. Move packer depth if needed.Pressure up tubing to set packer. 11. Shear out of PBR. Space out and MU tubing hanger. Circulate corrosion inhibited fluid in the IA. Land the tubing hanger,RILDS. 12. PT the tubing. Hold pressure on tubing and pressure test IA and chart.Bleed tubing pressure quickly to shear the SOV. 13. Pull the landing joint, install BPV. 14. ND BOPE.NU tree.Pull BPV and install tree test plug. Test tree and pull test plug. 15. Freeze protect well with diesel. Set BPV. 16. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline.Pull SOV,ball&rod,run GLD then pull catcher and plug. 4. Handoff to operations to put back on production. 1 • • l'i R DI g ilii ii 3 Y'_1 ZO o , , n W U Y o O N 7- 8 a mn A E > B � > ,i § w 4 Oit,m m J0 j r, o mE "' PkEO O m` w .E Ooo®ONa � ii 1i i m OF • nmum nomgv ¢q _ m- i N9 go MI g g L Nom o 1111 ��w�"��� o, , ioLo �N m fou . ,. \\rn S 1K 'e EW ai K to8�:'z( m lc v aMEM MEM m 94S i Ye a Se gy }1 O U 4 K � T�Win..-,,- ,_ gag�ee��P mgi O O = :Yy,,,t,-g,ngq Q Q U Q MEM ,* 1i TU 1k1 o:: II III\ — — boo o®o 000- 00 > C4) BOo°oOO m m rc0O0000 � K —.o®of`—o0 o®o > F IN MI -T't/Jy .1...1 O a m UZ 3E mN Em Uo. Eommm O O'-' ; d0 N� v CV? NI Nbamm n m C, LL 3,, 3.2 06 aN°'�(( i Nam ram `,)3:-;°c� K �yfL ZaK NVK I�K 9Zzeli ■ N=N ■ ■ H-11 MI!. 111 111 II, O a LL Z 1111 111 U I lifill O O_ m Q Q a MUM =MI p mom mim 1n 1 '1�1 1111 T • M 1 ; Well �OD 31-01 ConocoPhihips ell Attrib Max AngOOD TD Field Name Wellbore API/UWI Wellbore Status Incl 0) MO ) Act Btm(ftKB) AI,Ii,kd,I`n.: KUPARUK RIVER UNIT 500292151400 PROD 50.75 3,000.00 9,030.0 ConocaPhillips Comment 82S(ppm) Date Annotation End Date I KB-Grd(ft) Rig Release Date ... SSSV:TRDP 90 12/20/2012 Last WO: 37.40 1/9/1986 31-01,6/4/20186:57:42 AM Last Tag Vertical schematic(actual) Annotation End Date Depth(ftKB) Last Mod By Last Tag:SLM 3/28/2012 8,812.0 osborl - Last Rev Reason HANGER,24.0 ' Annotation End Date Last Mod By Rev Reason:Chemical Cut 5/8/2018 pproven Casing Strings 'w-'aji� ��l� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread • • • , - /�./�ugo CONDUCTOR 16 15.06 31.0 104.0 104.0 62.50 H-40 WELDED //vv�l/h�"Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR;310-104.0-a l' SURFACE 9 5/8 8.92 30.6 4,346.0 3,304.7 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SAFETY VLV;1,779.5 3Ai.. PRODUCTION 7 6.28 24.0 9,010.1 6,527.8 26.00 J-55 BTC 1 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD((...Wt(Ib/ft) Grade Top Connection GAS LIFT;2,711.0 I. TUBING 2.875x2.375@8581' 2718 2.44 24.0 8,651.2 6,265.4 6.50 J-55 EUEBrdABMOD 7 Completion Details SURFACE;30.6-4,346.0 J Top(ND( Top Incl Nominal .9 l Top(ftKB) (ftKB) 0) Item Des Co' ID(in) 24.0 24.0 0.04 HANGER CAMERON TUBING HANGER 2.875 1,779.5 1,639.1 43.49 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE((LOCKED FLAPPER OPEN 2.312 5/5/2018(( II 8,556.2 6,195.0 41.90 PBR CAMCO OEJ PBR 2.313 GAS LIFT;4,975.0 8,573.7 6,208.1 42.00 PACKER CAMCO HRP-1-SP PACKER 2.347 8,581.5 6,213.8 42.04 XO Reducing CROSSOVER 2.875 x 2.375 2.375 GAS LIFT;6,224.8 I 8,615.2 6,238.8 42.28 NIPPLE CAMCO'D'NIPPLE NO GO 1.810 il 8,650.5 6,264.9 42.59 SOS CAMCO SHEAR OUT SUB 2.441 GAS LIFT,0,980.2 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) 0) Des Com Run Date ID(in) GAS LIFT,7,3128III 8,338.0 6,032.2' 41.82 Tubing Cut '•CHEMICAL CUT 5/8/2018 0.000 $ 8,367.0 6,053.8 41.81 PACKER WEATHERFORD WIDEPACK PACKER 11/24/201 1.460 2 GAS LIFT;7,750.8 I 8,370.8 6,056.7 41.81 PATCH SPACER PIPE 8 SNAP LATCH SEAL STINGER 11/24/201 1.310 2 GAS LIFT;8,192.0 Sen 8,396.0 6,075.5 41.80 PACKER WEATHERFORD WIDEPACK PACKER 11/23/201 1.465 2 Perforations&Slots Tubing Cut;8,338.0 iiii Shot il Dens _ Top(ND) Btm(ND) (shots/ft PACKER;8,367.0 Top(ftKB) Btm(ftKB( (ftKB) (ftKB) Linked Zone Date ( Type Corn -:Inc T. 8,734.0 8,754.0 6,326.1 6,340.7 A-2,31-01 1/6/1991 4.0 RPERF 1 11/16 Dyna Strip.Zero PATCH;8,370.8 deg.phasing PACKER;8,396.0 -;-_ 8,740.0 8,760.0 6,330.4 6,345.0 A-2,31-01 5/28/1986 1.0 IPERF 4"Hyper Jet II,90 deg. 111 phasing 8,754.0 8,760.0 6,340.7 6,345.0 A-2,31-01 5/28/1986 1.0 IPERF GAS LIFT;8,510.6 8,770.0 8,798.0 6,352.3 6,372.7 A-1,31-01 5/28/1986 4.0 IPERF 4"HyperJet II,90 deg. I phasing Mandrel Inserts a St atl PBR;8,556.2 = on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com NOPACKER;8,573.7 1 2,710.9 2,253.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/7/2018 2 4,975.0 3,720.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/3/2018 il 3 6,224.8 4,573.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/3/2018 4 6,908.2 5,052.1 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 2/19/2008 NIPPLE;8,615.2 5 7,312.8 5,331.5 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/7/2018 6 7,750.8 5,621.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 2/23/2008 7 8,192.0 5,924.3 CAMCO KBMG 1 GAS LIFT OPEN 5/712018 8 8,510.6 6,161.0 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/19/2008 Notes:General&Safety sos;8,650.5 End Date Annotation 5/28/2005 NOTE:CORKSCREWED TUBING SUSPECTED @ 5800' 4/4/2008 ''NOTE:CALIPER LOG 3615'TO SURFACE 6/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 RPERF;8,734.0-0,754.0�.... /PERF;8,740.0-8,7600-. 1 _ IPERF;8,754.0-8,760.0-. ~ IPERF;8,770.0-8,798.0-. II I PRODUCTION;24.0-9,010.1 l • • Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Monday,June 11, 2018 12:47 PM To: Loepp,Victoria T(DOA);Ward, Dusty K; Kanady, Randall B Cc: Buck, Brian R;Coberly,Jonathan Subject: RE: [EXTERNAL]KRU 1F-07 MPSP and Workover Victoria, The AAO Rig#111 is currently rigging up on 31-01 and will be ready to kill the well Wednesday night 6/13/18. When de you think we can get an approval on the Sundry for 31-01? Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-13-1380 • From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday,June 11,2018 11:20 AM To:Ward, Dusty K<Dusty.Ward@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>;Coberly,Jonathan<Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]KRU 1F-07 MPSP and Workover Please submit a workover sundry for KRU 1F-07. What is the status of the All American Oil Field Rig#111?What is th- estimated commencement of operations on Well KRU 31-01? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepr alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conserva ion 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't to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepn©alaska.gov From:Ward, Dusty K<Dusty.Ward@conocophillips.com> Sent:Wednesday,June 06, 2018 3:02 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> 1 ^ Cc: Buck, Brian R<Brian.R.Buck@ccophillips.com>; Coberly,Jonathan<JonIn.Coberly@conocophillips.com> Subject: 1F-07 MPSP Victoria, Well 1F-07 at CPF1 in Kuparuk had a BHP survey done on 5/30/2018. It was taken at 7403' RKB(6166'TVD)and had a pressure of 2686 psig. Using 0.1 psi/ft gas column gradient for the TVD,yielded a MPSP of 2069 psig. Thanks. Good day. Dusty Ward Senior Wells Engineer Office:907-265-6531 Cell:503-476-2519 2 • P TO <f95--31) -7-- Loepp, o -7--Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,April 25, 2018 9:20 AM To: 'Coberly,Jonathan' Subject: RE: 3I-01 (PTD: 185-307) Request for acceptance of an alternative MPSP calculation method Jonathan, This alternate method of determining the MPSP is denied without prejudice. CPAI has the right to appeal this to the AOGCC. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer %AMR State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a�alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp©alaska.gov From: Coberly,Jonathan<Jonathan.Coberly@conocophillips.com> Sent:Tuesday,April 24, 2018 7:11 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Subject:31-01 (PTD: 185-307) Request for acceptance of an alternative MPSP calculation method Importance: High Victoria, We currently have producer 31-01 (PTD: 185-307)on our schedule for rig workover during the end of May. The scope of the workover is to upsize the single packer completion to 3-1/2"from 2-7/8"and to replace the internal casing packoffs by upgrading the tubing head to a newer model in order to set up the well for future CTD. The work scope doesn't require a 10-403 per the"Sundry Matrix"so I am writing to request acceptance of a more accurate MPSP calculation for this project prior to completing the workover. Referencing: 20 AAC 25.280 (4)the maximum downhole pressure that may be encountered, criteria used to determine it, and the maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the .commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure,such as using a stabilized shut-in tubing pressure; 1 • • • Producer 31-01 has been shut in with a stabilized column of production fluids and diesel freeze protect since 4/27/2015. SBHP Recorded 9/14/2017: 3,854 psig at 6041'ND(8350' MD) Observed Surface Tubing Pressure History Since Shut In: (Source: pre-job manual recording of surface tubing gauge on site) 6/30/2015: 1750 psig 8/2/2015: 1725 psig 8/2/2017: 1725 psig 2/14/2018: 1760 psig 2/17/2018: 1775 psig 2/18/2018: 1780 psig 2/19/2018: 1780 psig 3/16/2018: 1725 psig Requested MPSP for 2018 Rig Workover=1,780 psig Jonathan Coberly Workover Engineering Team Lead ConocoPhillips Alaska, Inc. 700 G Street,ATO 1378 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 2 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning, They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) jTwo-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) o Color items: o Diskettes, No. [] Maps: [3 Grayscale items: [] Poor Quality Originals: ORGANIZED BY: Other, No/Type NOTES: BEVERLY BREN VINCENT SHERYL/~-~LOWELL V [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~si Scanned (do.e) PAGES: ~(~ (atthetimeofscanning) SCANNED BY: BEVERLY BREN VINCE~ARIA LOWELL RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: PAGES:~ (~ Quality Checked (done) RevlNOTScanned.wpd STATE OF ALASKA RECEIVED ALIA OIL AND GAS CONSERVATION COM•SION PE'JE2- • • REPORT OF SUNDRY WELL OPERATIONS 'it 1 . Operations Performed: Abandon r Repair well f Rug Perforations r Perforate r , Q (Apr I Patch Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r • Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r _ N 185 - 307 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service a) 50- 029 - 21514 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25521 - 31 - 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .. none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9030 feet Plugs (measured) none true vertical 6542 feet Junk (measured) none Effective Depth measured 8919 feet Packer (measured) 8367, 8396, 8574 true vertical 6460 feet (true vertical) 6054, 6075, 6208 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104 104 SURFACE 4315 9.625 4346 3304' "' PRODUCTION 8986 7 9010 6528 Perforation depth: Measured depth: 8734'- 8760', 8770' -8798' SCANNED MAR 1 2013' True Vertical Depth: 6326-6345', 6352' -6373' Tubing (size, grade, MD, and TVD) 2.875 x 2.375, J -55, 8651 MD, 6265 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD WIDEPACK PACKER @ 8367 MD and 6054 TVD PACKER - WEATHERFORD WIDEPACK PACKER @ 8396 MD and 6075 TVD PACKER - CAMCO HRP -1 -SP PACKER @ 8574 MD and 6208 TVD SSSV - CAMCO TRDP -1A SSSV @ 1780 MD and 1639 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation 184 613 441 -- 130 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development d. 0 Service r Stratigraphic r 16. Well Status after work: V Oil ' Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WA GINJ WI ND r • r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce t'a. 265 -6471 Email John.W.Peirce a(n.conocoDhillips.com Printed Name John Peirce Title Wells Engineer Signature W •e. Phone: 265 -6471 Date l 2 ( j$( 1.2. a it • �,l1./ Form 10 -404 Revised =' V - S DEC "' 9 20110 / �'^� Subm Or Only , t /2s/,r 31 -01 Well Work Summary DATE SUMMARY 7/21/12 Pull upper packer and tubing h @8,371' CTMD with Weatherford's moil 2.50" GSPEAR. Captured Tubing patch and upper packer in swab valve. Ready for slickline to retreive. 7/29/12 RETRIEVED ECLIPSE PACKER & TBG PATCH COIL LEFT IN TREE. PULLED LOWER ECLIPSE PACKER @ 8392' RKB. SET 1.81" CA -2 PLUG @ 8615' RKB. CMIT Tx1A TO 2500 PSI ( PASS ). 7/31/12 RIH WITH 24 ARM MIT CALIPER AND LOG THE 2 7/8" TUBING FROM 8574' 8/1/12 RUN IN HOLE WITH THE GYRO DATA 4 AXIS GYRO AND SURVEY THE WELL FROM 8200' TO SURFACE 11/20/12 SET CATCHER SUB © 8532' SLM. PULLED GLVS @ 6225', 4975', AND 2710' RKB AND SET DV'S @ SAME. PULLED CATCHER SUB @ 8532' SLM; DRIFTED TBG W/ 2.24 BARBELL DMY PATCH DRIFT. IN PROGRESS. 11/21/12 PULLED CA -2 PRONG © 8615' RKB. BAIL SCALE OFF OFF PLUG BODY. MADE SEVERAL ATTEMPT TO PULL PLUG BODY SHEARING ( UP) PULLING TOOLS. IN PROGRESS. 11/22/12 PULLED PLUG BODY @ 8615' RKB. BRUSH & FLUSH TBG FROM 8300' - 8450' SLM. READY FOR E /L. 11/23/12 RIH W/ WEATHERFORD 2.24" WIDEPAK PACKER AND CCL (OAL: 30.94'x2.24 "). SET PACKER AT 8396'. LOG CORRELATED TO SLB LEAK DETECTION LOG DATED 06 MAR 2008. 11/24/12 RAN ER TEST TOOL TO LOWER ER PACKER @ 8396' RKB MIT LOWER PACKER TO 2500 PASS, SET WEATHERFORD ER UPPER PATCH ASSEMBLY @ 8367; RKB ( OAL 27.31' / 1.75" ID ), MIT TBG PASS. ( RETURN TO MITIA WHEN READY ). WILL RETURN FOR GAS LIFT INSTALLATION PENDING MITIA. 11/27/12 MITIA TO 3000 PSI - PASSED. RE- ENERGIZE IC PO. KUP 31 -01 ConocoPhillips Well Attributes M ax Angle & MD TD 1 , Alaska I11 Wellbore APIIUWI Field Name Well Status Inel (°) MD (ftKB) Act Btm (KB) - , - -. 500292151400 KUPARUK RIVER UNIT PROD 50.75 3,000.00 9,030.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: TRDP 100 12/16/2011 Last WO: 37.40 1/9/1986 Well Confip' - 31 -01, 11/30/2012 7:23'16 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,812.0 3/28/2012 Rev Reason: GLV C /O, Pull Plug, Set Patch Assy ninam 11/30/2012 Casing Strings HANGER, 24 Casing Description String o... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd -- CONDUCTOR 16 15.062 31.0 104.0 104.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 30.6 4,346.0 3,304.3 36.00 J - BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd I j PRODUCTION 7 6.276 24.0 9,010.1 6,527.8 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String .. String Top Thrd CONDU TUBING 2.875x2.375 27/8 2.441 Completion Details 24.0 8,651.2 6,265.4 6.50 J -55 EUE8rdABMOD 31 - toa SAFETY VLV, r Top Depth 7,779 4)=. Top (ftKB) ( KB) Top Item Description Comment ID (in) 24.0 24.0 0.09 HANGER CAMERON TUBING HANGER 2.875 GAS LIFT, 1,779.5 1,639.0 43.49 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE 2.312 2,711', 8,556.1 6,194.9 41.90 PBR CAMCO OEJ PBR 2.313 8,573.7 6,208.0 42.00 PACKER CAMCO HRP -1 -SP PACKER 2.347 8,581.4 6,213.8 42.04 XO Reducing CROSSOVER 2.875 x 2.375 2.375 8,615.2 6,239.0 42.85 NIPPLE CAMCO'D' NIPPLE NO GO 1.810 8,649.1 6,264.0 42.92 XO Enlarging CROSSOVER 2.375 x 2.875 2.441 SURFACE,_ ' 8,650.5 6,264.9 42.92 SOS CAMCO SHEAR OUT SUB 2.441 31 -4,346 t 1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 4,975 (ND) Top Inc! Top (ftKB) (ftKB) F Description Comment Run Date ID (in) 8,367 6,053.9 41.87 PACKER WEATHERFORD WIDEPACK PACKER 11/24/2012 1.460 GAS LIFT, _ _ _ 8,371 6,056.7 41.86 PATCH SPACER PIPE 8 SNAP LATCH SEAL STINGER 11/24/2012 1.310 6,225 8,396 6,075.5 41.81 PACKER WEATHERFORD WIDEPACK PACKER 11/23/2012 1.465 GAS LIFT, Perforations & Slots 6,908 Shot Efi.1 Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh.. Type Comment GAS LIFT, 8,734 8,754 6,326.0 6,340.6 A -2, 31 -01 1/6/1991 4.0 RPERF 1 11/16 Dyna Strip. Zero deg. 7,313 phasing 8,740 8,760 6,330.4 6,345.0 A - 31 - 5/28/1986 1.0 IPERF 4" Hyper Jet 11, 90 deg. phasing GAS LIFT, 8,754 8,7 6,340.6 6,345.0 A - 31 -01 31 -01 5/28/1986 1.0 IPERF 7751 _ 8,770 8,798 6,352.3 6 ,372.7 A -1, 5/28/1986 4.0 IPERF 4" HyperJet II, 90 deg. phasing Notes: General & Safety GAS LIFT, End Date Annotation 8.192 5 /28/2005 NOTE: CORKSCREWED TUBING SUSPECTED @ 5800' �-----_ IF 4/42008 NOTE: CALIPER LOG 3615' TO SURFACE PACKER, 8,387 6/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PATCH, 8,371 PACKER, 8,398 -• GAS LIFT, 8,511 PBR, 8,556 / PACKER. 8.574 ii ■ NIPPLE, 8,615 - -- i SOS. 8.650 �' Mandrel Details Top Depth Top Port 8,7344!,754 (ND) Inc! OD Valve Latch Size TRO Run 8,740-8,760 53.0 50.37 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/20/2012 Stn Top (ftKB) ( ( °) Ma Model (in) Sery Type Type ( in) (psi) Run Corn.- IPERF, 1 2 2, 20.3MCO K / 8,7544L700 2 4, 975.0 3 ,7 19 .9 48.18 CA MCO KBMG 1 GAS LIFT DMY BK 0 .000 0.0 11 Date 3 6,224.7 4,573.4 45.80 CAMCO KBMG 1 GAS LIFT DMU BK 0.000 0.0 11/20/2012 IPERF, 4 6,908.2 5,051.9 45.69 CAMCO KBMG 1 GAS LIFT DMY BK -2 0.000 0.0 2/19/2008 8,770 -8,798 5 7,312.8 5,331.5 47.20 CAMCO KBMG 1 GAS LIFT DMY BK -2 0.000 0.0 2/9/2006 . 6 7,750.7 5,621.6 49.21 CAMCO KBMG 1 GAS LIFT DMY BK -2 0.000 0.0 223/2008 I 7 8,192.0 5,924.3 43.26 CAMCO KBMG 1 GAS LIFT DMY BK -2 0.000 0.0 5/14/2000 8 8,510.5 6,161.0 41.64 MMH FM1.5 1 12 GAS LIFT DMY RK 0.000 0.0 2/192008 PRODUCTION, 1 ' 24-9,010 TD, 9,030 • • I • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ie December 1, 2012 / WE BEr n 11.1 Mr. Dan Seamount CC Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 BAR 2013 Anchorage, AK 99501 SCANNED Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3I -01 (PTD 185 -307) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659 -7224 if you have any questions. Sincerely, /7) r- Kelly Lyon)/ ConocoPhillips Problem Wells Supervisor Enclosures • STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMI ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Fbrf orations r Perforate r Other F7 Reset tbg patch Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' Exploratory r - 185 -307 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50 -029- 21514 -00 -- 03 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25521 31 - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9030 feet Plugs (measured) None true vertical 6542 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8367, 8371, 8396, 8574 true vertical 0 feet (true vertical) 6054, 6057, 6075, 6208 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104 104 SURFACE 4315 9 5/8 4346 3304 PRODUCTION 8986 7 9010 6528 "94.. D , Perforation depth: Measured depth: 8734 -8754, 8740 -8760, 8770 -8798 C 01 ?' True Vertical Depth: 6326 -6341, 6330 -6345, 6352 -6373 0/2 4S Tubing (size, grade, MD, and TVD) 2.875, J - 55, 8650 MD, 6265 TVD Packers & SSSV (type, MD, and ND) PACKER - WEATHERFORD WIDEPACK PACKER @ 8367 MD and 6054 TVD PATCH - SPACER PIPE & SNAP LATCH SEAL STINGER @ 8371 MD and 6057 TVD PACKER - WEATHERFORD WIDEPACK PACKER @ 8396 MD and 6075 TVD PACKER - CAMCO HRP -1 -SP PACKER @ 8574 MD and 6208 ND 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r ...Service r Stratigraphic r 16. Well Status after work: , Oil P' Gas r WDSPL r Daily Report of Well Operations x GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Kelly Lyons / Brent Roger, Email n1617i'D,conocophillips.com Printed Name Kelly.L -sons ,, Title Problem Wells Supervisor Signature ( /_ Phone: 659 -7224 Date 12 -1 -12 Form 10 -404 Reviseti1012012 $� L 20::: � � (Z 113•i z. Submit Original Only • 31 -01 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/21/12 Pull upper packer and tubing patch @8,371' CTI�AD with Weatherford's modified 2.50" GSPEAR. ✓✓ 07 /29 /12IPULLED LOWER ECLIPSE PACKER © 8392' RKB./ 11/23/12 RIH W/ WEATHERFORD 2.24" WIDEPAK PACKER AND CCL (OAL: 30.94'x2.24 "). SET PACKER AT 8396'. LOG CORRELATED TO SLB LEAK DETECTION LOG DATED 06 MAR 2008. 11/24/12 RAN ER TEST TOOL TO LOWER ER PACKER @ 8396' RKB MIT LOWER PACKER TO 2500 PASS, SET WEATHERFORD ER UPPER PATCH ASSEMBLY @ 8367' RKB ( OAL 27.31' / 1.75" ID ), MIT TBG PASS. ( RETURN TO MITIA WHEN READY ). MITT passed on lower ER packer, IA didn't communicate while attempting CMIT. Initial T /I /0= 1925/1400/580. Start MITT T /I /0= 2525/1400/580, 15 min T /I /0= 2450/1000/580, 30 min T /I /0= 2425/1000/580. MITT on upper ER packer passed. Initial T /I /0= 1900/1700/580. Start MITT T /I /0= 2540/1700/580, 15 min T /I /0= 2520/1700/580, 30 min T /I /0= 2510/1700/580, 45 min T /I /0= 2500/1700/580, 60 min T /I /0= 2490/1700/580. Bumped back up due to small linear leak. Restart MITT T /I /0= 2625/1700/580, 15 min T /I /0= 2600/1700/580, 30 min T /I /0= 2600/1700/580. 11/27/12 MITIA passed. Initial T /I /O= SI 1900/1700/580. IA FL @270'. Rigged up sealant gun to energize port (both sides). Pressured up with 4000 psi (hydraulic side of gun) until held treatment pressure for 30 mins. Used moderate amount of sealant. Bled IA, all gas, 35 mins until received energized fluid at 450psi. TWO= 1900/450/580. Pressured up IA to 3000 psi with 9.8 bbls diesel. T /I /O= 1920/3000/580. 15 min reading: 1920/2950/580. 30 min reading: 1920/2950/580. Bled IA to 1000 psi. Final T /I /O= SI 1920/1000/580. Summary Tubing patch was pulled and replaced. Patch integrity demonstrated with passing MITIA � I I � I I I � I I - 3D7 • Ge, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 3, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 0 3 2013, RE: Multifinger Imaging Tool (MIT) : 31 -01 Run Date: 8/1/2012 The technical data listed below is being submitted herewith. Please address any - problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3I -01 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21514 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: / I 2 Signed: al."44 6 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ~. operations Performed: Abandon ^ Repairwell ~ Rug Ft?rforations ~ Stimulate [j Other Q Install Patch ARer Casing ~ Pull Tubing G FZ'rforate New Pbol ^ Waiver ^ Time Extension [j Change Approved Program ~ Operat. Shutdown [J Perforate (~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory [j ~ 185-307 3. Address: Stratigraphic ^ Service r 6. ARC Number: ~` P. O. Box 100360, Anchorage, Alaska 99510 50-029-21514-00 7. Property Designation: 8. Well Name and Number: ADL0025521 ~ 31-01 9. Field/Pool(s): L Kuparuk River Field /Kuparuk Oil Pc 10. Present Well Condition Summary: Total Depth measured 9030 feet Plugs (measured) None true vertical 6542 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8574 true vertical 0 feet (true vertucal) 6208 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104 104 1640 630 SURFACE 4315 9.625 4346 3304 3520 2020 PRODUCTION 8986 7 9010 6528 4980 4330 , 1 ~ ,'_ ~~ ` ~ ' ~~ ` ~ ~~ ` ` ~ a ~~` . Perforation depth: Measured depth: 8734'-8754', 8740'-8760', 8754'-8760', 8770'-8798' ` ` ` `~"''" `" ` True Vertical Depth: 6326'-6341', 6330'-6345', 6341'-6345', 6352'-6373' Tubing (size, grade, MD, and TVD) 2.875, J-55, 8650 MD, 6265 TVD 1.310" WEATHERFORD PATCH FROM 8371'-8392' Packers & SSSV (type, MD, and TVD) PACKER - CAMCO HRP-1-SP PACKER @ 8574 MD and 6208 TVD ~~~~y /~~ SAFETY VLV - CAMCO TRDP-1A-SSA @ 1779 MD and 1639 TVD 1/ 11. Stimulation or cement squeeze summary: ~ ~ ~ ~~' Intervals treated (measured): NA ~~8Sk8 ~ ~ ~~ fv~~ {.4~111SSIOn Treatment descriptions including volumes used and final pressure: NA ~i;icn:~rage 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory ~,j Development ~ Service 15. Well Status after work: Oil ~; .Gas ~ WDSPL Daily Report of Well Operations X GSTOR ~ WAG ~ GASINJ ~ WINJ ^ SPLUG ~ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/a if C.O. Exempt: NA contact Martin Walters / Brent Roaers ters n Title Problem Wells Supervisor Printed Name Martin l W a Signature ~ c~~~~J/~'v 1 G/ ' ' / Phone: 659-7224 Date: 07/25/10 w ,. / / nr3UlygS AUG 0 2 Z0~ %~ g^Z ^'o Form 10-404 Revised 7/2009 Submit Original Only 31-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/24/10 05/25/10 BRUSHED & FLUSHED TBG. TESTED TBG f/ TOP OF PATCH @ 8372' RKB, GOOD TEST. IN PROGRESS. TEST UPPER ER PACKER @ 8372' RKB TO SURFACE, FAILED. ATTEMPT TO PULL ER PACKER/PATCH @ 8372' RKB. iN PROGRESS 05/26/10 PULLED UPPER ER PACKER /SPACER PIPE & LOWER ER PACKER 8372' RKB 05/27/10 BRUSH & FLUSH PATCH AREA. SET 1.81" PLUG 8615' RKB. COMPLETE 06/27/10 06/28/10 06/30/10 07/04/10 PULLED OV @ 6224' RKB. CIRCULATED 200 BBL DSL DOWN TBG UP IA TO F/L. COMBO MIT TBG & IA TO 2500 PSI, PASSED. SET NEW OV @ 6224' RKB. IN PROGRESS PULLED 1.81" CA-2 PLUG @ 8615' RKB. DRIFTED TBG WITH 2.25" x 76" BARBELL DRIFT TO 8450' SLM, NO RESTRICTIONS. READY FOR E-LINE. RIH WITH A WEATHERFORD ECLIPSE PACKER (2.24 OD) AND SET AT DEPTH OF 8395' TO THE MID ELEMENTS OF PACKER. THE PACKER WAS SET BELOW THE COLLAR THAT IS LEAKING (8384'). WELL IS NOW READY FOR S/L TO SET PATCH AND UPPER ECLIPSE PACKER. CMIT ON LOWER ER PKR @ 8395' RKB PASSED.SET WEATHERFORD PATCH (OAL=22' 1",MIN ID=1.31") FROM 8395' RKB TO 8374' RKB.MITT PASS RE-TIFL- passed; Initial T/I/0= 160/1250/720; Shut in WH and shot IA FL @ 6224ft. #3 OV. 07/14/10 Stacked out T with liftgas T/I/0= 1190/1175/710; Bled down IA. T/I/0= 1125/560800; Shot IA FL same location. Final T/I/0= 1125/560/700 STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~"" Repair well j""` Plug Fhrforations ~ Stimulate Other Patch Alter Casing j•-` Pull Tubing F~rforate New Fbol ]"'" Waiver ]~ Time Extension "` Change Approved Program ~ Operat. Shutdow n ~ F~rforate ~ Re-enter Suspended Well "`" 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory 185-307 3. Address: Stratigraphic '"` Service "' API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21514-00 7. Property Designalti~n: 8. Well Name and Number: ADL 25521 31-01 9. Field/Pool(s): ,~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9030 feet Plugs (measured) None true vertical 6542 feet Junk (measured) None Effective Depth measured 8919 feet Packer (measured) 8574 true vertical 6460 feet (true vertucal) 6208 Casing Length Size MD ND Burst Collapse CONDUCTOR 73 16 104 104' SURFACE 4315 9.625 4346 3304 PRODUCTION 8986 7" 9010 6528 ~L~E~VED ~~u~._ ~ ~ za firi Perforation depth: Measured depth: 8734'-8760', 8770'-8798' ~~~~' ~ ~~ ( qZS C , , +AE1rH11jSSI0il True Vertical Depth: 6326'-6345', 6352'-6373' ~iffCji~t1'~(~~ Tubing (size, grade, MD, and TVD) 2.875, J-55, 8650 MD, 6265 TVD Packers & SSSV (type, MD, and TVD) PACKER - CAMCO HRP-1-SP PACKER @ 8574 MD and 6208 TVD SAFETY VLV - CAMCO TRDP-1A-SSA @ 1779 MD and 1639 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable r, ~ ~} fi, ~f; ` ~ ` Treatment descriptions including volumes used and final pressure: ~, ~ " ~~~ ~ ~ ^' `' /` ~ ~ ' 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 54 710 168 -- 131 Subsequent to operation 49 541 156 -- 148 13. Attachments 1~Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service 1 .Well Status after work: Oil Gas ~ WDSPL "` Daily Report of Well Operations XXX GSTOR WAG ~` GASINJ WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce Cad 265-6471 Printed Name John Peirce Title Wells Engineer ' / rJ~~~Q 1 Signature ~ ,~ „! Phone: 265-6471 Date • ~- v Form 10-404 Revised 7/2009 RBDMS JUL 2 ~ ~ 7-z ZSubmit Original Only - 0 31-01 Well Events Summary DATE SUMMARY ~ 5/24/10 BRUSHED & FLUSHED TBG. TED TBG f/ TOP OF PATCH @ 8372' RK6~000D TEST. IN PROGRESS. 5/25/10 TEST UPPER ER PACKER 8372' RKB TO SURFACE FAILED. ATTEMPT TO PULL ER PACKER/PATCH @ 8372' RKB. IN PROGRESS. 5/26/10 PULLED UPPER ER PACKER /SPACER PIPE & LOWER ER PACKER @ 8372' RKB. IN PROGRESS. 5/27/10 BRUSH & FLUSH PATCH AREA. SET 1.81" PLUG @ 8615' RKB. COMPLETE 6/27/10 PULLED OV @ 6224' RKB. CIRCULATED 200 BBL DSL DOWN TBG UP IA TO F/L. C 9MBQ MIT TBG & IA TO_2500 PSI, PASSED._SET NEW OV @ 6224' RKB. IN PROGRESS. 6/28/10 PULLED 1.81" CA-2 PLUG @ 8615' RKB. DRIFTED TBG WITH 2.25" x 76" BARBELL DRIFT TO 8450' SLM, NO RESTRICTIONS. READY FOR E-LINE. 6/30/10 RIH WITH A WEATHERFORD Eclipse PACKER (2.24 OD). THE PACKER WAS SET BELOW THE COLLAR THAT IS LEAKING (8384'). WELL IS NOW READY FOR S/L TO SET PATCH AND UPPER ECLIPSE PACKER. 7/4/10 CMIT ON LOWER ER PKR PASSED.SET WEATHERFORD PATCH (OAL=22' 1",MIN ID=1.31"). MITT PASS 7/14/10 RE-TIFL- PASSED • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3I-O1 Run Date: 6/30/2010 July 3, 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 3I-O1 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21514-00 ~~1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING 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.barre ; ~b ,- • ~~~ .: J r~ Date: i ~5 -3 c~ ~ tS~s~~F Signed: °ae~, • • Page 1 of 1 Regg, James 6 (DOA) ~ iP,S-3~ ~ From: NSK Problem Well Supv [n1617@conocophillips.comJ ~ ` ,~irz~i© Sent: Friday, May 07, 2010 11:23 AM ~~ ~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 31-01 (PTD 185-307) Report of failed TIFL Attachments: 31-01 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 31-01 (PTD 185-307) failes~ a dia~TIFL. The TIO prior to the test was 220/1150/700. A leaking GLV is suspected. Slickline will troubleshoot the leak and repair if possible. Attached is a 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 ~ G~ ~;~ _ ~ ~ BEN ~.~..~~ti~~~~ 5/12/2010 KRU 3I-O1 PTD 185-307 5/7/2010 Till Preccnrec Plnt 500. 3000 5c . 3000 200. 3000. 3000. 2700 3000. ,Oily) _ 2400 0. 0. 0. 0. 0. 0. 0. 2100 1800 1500 120D 900 600 300 0 --- - - PLUT START' TIME 06-FEB-10 11:25 MINOR TIME MAJOR TIME WEER Si. TAG NINE WL3I-OI-CHORE SCRATCH 53 SCRATCH_53 AI-P3I5002-01 SCRATCH_53 SCRATCH_53 DESCRIPTION FLOW TUBING CHORE FLOW TUBING PRESSURE FLOW TUBING TEMP GL CASING PRESSURE INNER ANNULUS; PRE:; OUTER ANNULUS PRES PICK TIKE 4~MAY-10'-:11:20:15 ~?~~~'~; ?')77777 ???77?? 777???? ??????? ??????? ??77777 777?777 Ph0'.I' !l[s t, i"' ON PLU'I' ~~- 7 ! 1•^3 +02160-:00:00 HRS02'~-NAY-10 113E ~~~~~ DRILLSITE WELL PREV WELL 3i 01 NEXT WELL F.t+T?'':", ' ,~ i'Ii OPERATOR ~ OPERATOR VERIFIED ~ SYSTEM AUTO ENTRY ~ BOTH u • ANNULUS PRESSURE TRENQS WELL NAME WLRRU3I-O1 ~; ~'~~ KUP • 31-01 t COt")OCOP~"lf~ClpS ~ Well Attributes --- - Max Angle & MD __ _ __ TD ~ W Ilbore APIIUWI Field Name Well Status Ind (°) MD (ftK8) Acl Btm (ftK8) 500292151400 KUPARUK RIVER UNIT PROD 50.75 3,000.00 9,0100 C ment H23 (ppm) Date Annotatlon End Date KB-Grd (R) Rig Release Date ° _ ll C fi W ....__. zlis 3s 31-01 6/11/2009 PM SSSV: TRDP 160 7/1/2008 Last WO: 37.40 1/9/1986 . on - e scbemalw. nauai Annotatlon Depth (TlKB) Entl Date Annotatlon Laat Mod By End Date Last TaO: 8 ,794.0 2/28/2006 Rev Reason: UPDATE PATCH ID. PULL PLUG Imosbor 6/112009 Casing Strin s j `7 t String OD String ID ' Sel Doprn Set Depth (ND) String Wt a'tnn g [I '1 ~ Casing Description (in) Un) Top (}tl(B) (RK0) (RKB) (lba/(t) Orade String Top Thrd corvoucroR. too ~ ~ CONDUCTOR 16 15.062 0.0 104.0 104.0 62.50 H-40 k `~ SURFACE 9 5/8 8.765 0.0 4,346.0 3,304.3 36.00 J-55 4 11 (; PRODUCTION 7 6.151 0.0 9,010.0 6,527.7 26.00 J-55 VALVE,1779 ° Tubing Strings ~ { String OD String ID __ _ Sat Depth Set Depth (ND) String Wf Stin g Tubing Descri Ron 0^1 IiN To RKB (RKB) (RKB) (IbslR) Gratle String Top Thrd TUBING 27/8 2.441 0.0 8,581.0 6,213.5 6.SO J-55 EUE8RDAB MOD GASZI FT, ~, c~ti 7 _ ~, TUBING 23/8 1.995 8,581.0 8,651.0 6,265.3 ', Other In Hole Ail Jewel : Tubin rievable, Fish, etc.) ____ Run & R et SURFACE, ~ ~ Top Depth' _ _ x,346 (ND) Top Intl Top (RKB) (ftK8) (°) Deatalptlon Comment Run Date ID (In) ,. ,_,; ~ 1 779 1 638.6 43.47 SAFETY CAMCO TRDP (1A-SSA) 529/1986 2.312 casuFr, 4 975 . ., „ r^~ , , VALVE , ~:-ti ~ 2,711 2,253.1 50.37 GAS LIFT CAMCO/KBMG/1/GLV/BK-2/.125/1320/ Comment: STA 1 7/7/2008 2.347 ~. ~ 4,975 3,720.0 48.18 GAS LIFT CAMCO/KBMG/1/GLV/BK-2/.156/1327/Comment: STA2 7/7/2008 2.347 GAS LIFT 6,225 4,573.6 45.80 GAS LIFT CAMCO/KBMG/1/OVBK-2/.156/0/ Comment: STA 3 7!7/2008 2.347 , 6,225 1.-.~ ~ 6,908 5,051.7 45.69 GAS LIFT CAMCOMBMG/1/DMY/BK-2///Comment: STA4 2/19/2008 2.347 ~e 7,313 5,331.6 47.20 GAS LIFT CAMCO/KBMG/1/DMYBK-2///Comment: STA 5 2/92006 2.347 7,751 5,621.8 4921 GAS LIFT CAMCO/KBMG/1/DMYBK-2///Comment: STA6 2@3/2008 2.347 cns61~ ^;!~~ 8,192 5,924.3 4326 GAS LIFT CAMCO/KBMG/1/DMY/BK-2///CommenCSTA7 5/14/2000 2.347 8,372 6,057.6 41.86 PATCH ETD ASSY (19'-0") TUBING PATCH - WEATHFORD ER 7/5/2008 1.310 PACKER (2.61') SPACER PIPE (1623') SNAP LATCH ~ SEAL STINGER (73') 20.8' TOTAL PATCH LENGTH , ~ GAS LIFT 8,510 6,160.6 41.64 GAS LIFT MCMURRAY2.875 x 1.5/1.5/DMY/RK///Comment: STA 8 2/19/2008 2.347 , 7,313 ~'' ~ 8,556 6,194.8 41.90 PBR Camco'OEJ' 5/29/1986 2.313 f ~ 8,574 6,208.3 42.00 PACKER Camco'HRP-1-$P' 5/29/1986 2.347 .f:..~ 8,615 6,238.9 42.85 NIPPLE Camco'D' Nipple NO GO 5/29/1986 1.810 Gns uFT, 51 ~ ~ 8,650 6,264.6 42.92 SOS Camco 5/29/1986 1.995 77 ~ . 8,651 6,265.3 42.92 TTL _____. 5/29/1986 1.995 ~ ~ 1 Perforations & Siots -- _„.,__ -- -- Shot GAS LIFT, ~ Top (ND) Btm (ND) Dens 8,192 } To RKB Btm (RKB iRKB) IRKB) Zone Date (ah... Type Comment 8,734 8,754 6,326.0 6,340.6 A -2, 31-01 1/6/1991 4.0 REPE... 1 11/16 Dyna Svip. Zero deg. j phasing 8,740 8,760 6,330.4 6,345.0 A -2, 31-01 528/1986 1.0 IPERF 4" Hyper Jet II, 90 deg. phasing pgrcN, e.372 8,754 8,760 6,340.6 6,345.0 A -2, 31-01 5/28/1986 1.0 IPERF 8,770 8,798 6,352.3 6,372.7 A-1, 31-Ot 528/1986 4.0 IPERF 4" HyperJet II, 90 deg. phasing I ~ Notes: General --- - - - & Safety -_ - - __ _______ -- - ___.___,_ GAS LIFT _ Entl Date i~nnotatlon , e.s1o ~ ~ ; 5282005 NOTE: CORKSCREWED TUBING SUSPECTED @ 5800' ~ 4/42008 NOTE: CALIPER LOG 361 5' TO SURFACE PBR. 9,556 [[ E,;--. j ACKER, 9.574 {I J r r 3. ~... y, r t NIPPLE, 9,615 SOS, 9,650 I 1 J. i ~ ' TTL, 8,651 { REPERF, 9,7348,754 IPERF, 9,7A0-9,760 __ 3 IPERF, _ 9.7548,760 -- - '~, IPERF, 8,770A,798 , PRODUCTION, 9.010 To, s.o1n ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • ~' ~~. ,~~ April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: A~~~ ~~ ~~r? ~"4 ° ~~ ~~~ 4 ~~ I ~5/ ~ `- ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped April 7th , 2009. The corrosion inhibitor/sealant was pumped April 15th and 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 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 31-01 185-307 58' 10.10 4' 1" 4/7!2009 4.40 4/15/2009 31-03 185-309 69 '8" 10.20 4' 3" 4/7!2009 8.50 4/15/2009 3i-04 185-310 26' 4" 4.10 2' 4/7/2009 3.40 4/15/2009 31-05 186-036 76' 12.70 3' 6" 4/7/2009 8.50 4/15/2009 31-08 186-040 8' 6" 1.20 1' 9" 4/7/2009 3.40 4/15/2009 31-09 186-055 40' 5.10 1' 9" 4/7/2009 3.40 4/15/2009 31-11 189-035 1' 9" N/A N/A N/A 2.60 4/16/2009 31-12 186-060 44' 6.80 1' 11" 4/7/2009 2.60 4/16/2009 31-13 189-025 SF N/A N/A N/A 2.50 4/16/2009 31-14 186-062 77' 11.30 2' 11" 4/7/2009 8.50 4/16/2009 31-16 189-022 24' 3.54 1' 7" 4/7/2009 2.30 4/16/2009 31-17 189-024 37' 3.64 1' 7" 4/7/2009 2.00 4/16/2009 • ConocoPhiilips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 11, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~ 4: -, ,. --, t -~ :J .> ,, ~~c~~~~ AU ~ a ..2DQ8 Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 3I-O1 (PTD 1853070). The report records the successful Tubing patch set to repair the TxIA communication. Please call myself or Martin Walters at 659-7224 or MJ Loveland/Perry Klein at 659- 7043 if you have any questions. Sincerely, :/ Brent Rogers ~~ Problem Well Supervisor • • 1 :iUl, STATE OF ALASKA ~ ~ ZQ~$ ALASKA OIL AND GAS CONSERVATION COMMISSION ~;~~'°~ REPORT OF SUNDRY WELL 1. Operations Performed: Abandon ^ Repair Well /^ - Plug Perforations ^ Stimulate ^ Other ~/ "'1'~~ patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhlllips Alaska, InC. Development /^ ` Exploratory ^ 185-307' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21514-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 71' I 3l-01 8. Property Designation: 10. Field/Pool(s): ~ ADL 25521 AKL 2557 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9030' - feet true vertical 6542' . feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 104' 16" 104' 104' SURFACE 4275' 9-5/8" 4346' 3305' PRODUCTION 8939' 7" 9010' 6528' Perforation depth: Measured depth: 8734-8760', 8770-8798' true vertical depth: 6326-6345', 6352-6373' Tubing (size, grade, and measured depth) 2 7/8" , J-55, 8651' MD. 2 3/8" tail frm 8581-8651' Packers &SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 8574' SSSV= Camco TRDP -1A-SSA SSSV= 1779' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/q Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development /^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^/ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well SupefVisor - Signature / Phone 659-7224 Date 7/11/2008 C ,/ ,,;,~ ~0~ ~ ~~~ r~, OPERATIONS _ ~~...4 ~~,~,~.- ,~~~ ~ ~ ~ ~~~ ~~I~ ~) ~ 2QOB Form 10-404 Revised 04/2004 ~ n~ Submit Original Only 31-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/06/08 RAN LEAK DETECTION LOG. IDENTIFIED LEAK AT 8384' IN TUBING COLLAR. Notified AOGCC 3/8/8 04/05/08 LOGGED CALIPER SURVEY FROM 8615' RKB TO SURFACE 06/14/08 06/20/08 CMITIA TO 2500#. PASS. SET 2.31" CA-2 PLUG @ 1779' RKB. MITT TO 2650#. ***PASS. PERFORMED NEG TEST ON TBG. (***PASS"'"`). CMIT TxIA -passed. Pre-MIT T/I/0= 0/50/100, Initial T/I/0= 2450/2500/100, 15 min. T/I/0= 2300/2400/100, 30min. T/I/0= 2275/2350/100. 46.7 bbls MITT -passed. Pre-MIT T/I/0= 2250/200/100, Initial T/I/0= 2650/200/100, 15 min. T/I/0= 2550/200/100, 30min. T/I/0= 2525/200/100..3 bbls TBG DD -passed. Pre- IA DD T/I/0= 2525/200/100, Initial T/1/0= 0/200/100, 15 min. T/I/0= 0/200/100, 30 min. T/I/0= 0/200/100. ..PULL CA2 PLUGS @ 1779' RKB & 8615' RKB, BRUSH & FLUSH FOR PATCH BETWEEN j8369' & 8399' RKB. WELL READY FOR E-LINE TO SET LWR PKR FOR PATCH 06/26/08 SET WEATHERFORD 2-7/8" ER PACKER WITH MID-ELEMENT AT 8394' (10' BELOW LEAKING COLLAR). :OMBO MIT TBG & I/A, PASSED,PT TO 2500#, Initial T/I/0=1500/1500/100. Sta /I/0=2500/2425/100, 15 min T/I/0=2375/2400/100, 30 min T/I/0=2350/2375/100. RIH W/ ETD ASSY (19'-0") WEATHFORD ER PACKER (2.61') SPACER PIPE (16.23') SNAP LATCH SEAL STINGER (.73') 20.8' TOTAL PATCH LENGTH 07/07/08 PT I/A TO 2500# (TESTED PATCH) Post Patch TIFL -passed. Initial T/I/0= 110/1240/120. Shut in the WH and GL upon arrival. Shot the initial IA FL @ 6225' sta. # 3 OV. Stacked out the TBG with LG. Bled down the IA and shot the 2nd IA FL @ the same location. Final T/I/0= 1120/600/100 07/10/08 Summary Installed Retrivable tubing patch from 8372-8394' To: AOGGC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 ] Caliper Report 03-Ap-~08 3G16A ~~~ APR ~ ~ ~~~~ 1 Report / EDE 50-029-21502-01 2] Caliper Report 04Apr'OS 31-01 1 Report/ EDe .~ Signed Print Name: .~~~~~ - 50-029-2151400 Date . - _ _ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~ ,~~ - ^-~ , ~ _ - WEBSITE e. ~' C:~ocumenis and SettingslOwner`.Desktop~Transmit_Conoco.doc • Memory Multi-Finger Caliper Log Results Suml~nary Company: ConocoPhillips Alaska, Inc. Well: 31-01 Log Date: April 4, 2008 Field: Kuparuk Log No.: 7223 State: Alaska Run No.: 1 API No.: 50-029-21514-00 Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD AB Mod Top Log Intvl1.: Surtace Pipet Use: Tubing Bot. Log Intvl1.: 8,581 Ft. (MD) Pipet Desc.: 2.375 Top Log Intvt2.: 8,581 Ft (MD) Pipet Use: Tubing Bot. Log Intvl1.: 8,600 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS w This caliper data is tied into the X Over @ 8,58t' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of tubing logged is in good condition. No significant Wall Penetrations, areas of Cross Sectional Wall loss or I.D. restrictions recorded throughout the interval of 2-7/8" and 2-3/8 tubing logged. ' The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (>18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (>13%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. ~~~ APR ~ ~ 2008 !~~ -~o~ ~ ~~ 09 ~ Field Engineer: Wm McCrossan Analyst: J. Thompson Witness: C. Fritzpatrick P~oActive Diagnostic Services, Inc. J P.O. Box 1559, Stafford, TX 77497 Phone: (281} 431-7100 or {888} 565-9085 Fax: (281} 431-7125 E-mail: PDSfcumemorylog.com P-udhoe Bay Field Office Phone: {907} 659-2307 Fax: {907} 659-2314 ~ a Correlation of Reco rded Damage to Borehole Profile ~' 4- Pipe 1 2.875 in (-0.9' - 8581.2') Well: 31-01 Pipe 2 2.375 in (8581.2' - 8581.2') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 4, 2008 A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 5 25 V " . 742 50 1516 75 2300 GLM 1 1* 100 3075 D 125 v 3832 ~ ;_ ~ ~ ._ Z 150 4601 a c ~ GLM 2 ° ~ 175 5380 GLM 3 6159 GLM 4 225 6944 GLM 5 GLM 6 7720 GLM 7 GLM 8 8520 .1 8581 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = .1 • • PDS Report Overview ~ S* Body Region Analysis Well: 31-01 Survey Date: April 4, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: J. Thorn son Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 EUE 8RD AB Mod 2.441 ins 2.875 ins 6.0 ins 0.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal sed rotal = 278 pene. 1 122 155 0 0 0 loss 86 189 3 0 0 0 Damage Configuration (body ) 40 30 ,~ ZO 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 36 30 6 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM 8 Bottom of Survey = 275.4 Analysis Overview page 2 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf )-55 EUE 8RD AB Mod Well: 31-01 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 4, 2008 Joint No. Jt. Depth (Ft.) Pc~n. Ul~,~~t Iln~.) Pen. Body (Ins.) Pc~n. % ,Metal I oss "~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 -1 (~ 0.00 1 I 2.42 PUP 1 5 (~ 0.03 15 1~~ 2.39 Shallow ittin . 2 42 t) 0.03 15 ~ 2.37 Shallow ittin . 3 70 t~ 0.02 ~i ' 2.40 4 101 U 0.04 1 t3 t3 2.36 Shallow corrosion. 5 131 l) 0.02 ~~ 3 2.40 6 162 t) 0.02 I I l U 2.36 7 193 (1 0.01 t ? 2.41 8 223 U 0.02 ~) 3 2.41 9 254 ~ 0.03 14 4 2.38 Shallow ittin . 10 285 O 0.03 12 4 2.37 11 312 11 0.02 10 5 2.38 12 343 l) 0.03 L5 9 2.37 Shallow ittin . 13 372 ~) 0.03 1 t~ I 1 2.39 Shallow ittin Lt. De sits. 14 402 U 0.01 4 ; 2.41 15 433 U 0.02 '~ 4 2.39 16 464 l ~ 0.01 8 2.40 17 495 l ~ 0.01 4 ; 2.40 18 526 U 0.01 4 ~~ 2.40 19 557 U 0.02 8 4 2.41 20 588 U 0.02 8 4 2.39 21 618 t) 0.01 4 -4 2.39 22 649 U 0.02 1 U (, 2.40 23 680 U 0.02 9 5 2.40 24 711 a 0.02 1 U 5 2.39 2 5 742 U 0.02 9 8 2.40 26 774 U 0.01 6 6 2.40 27 805 t) 0.01 4 ~ 2.39 28 836 O 0.02 ~) ; 2.40 29 867 l) 0.02 t3 2.41 30 898 O 0.01 ~i 7 2.41 31 929 t) 0.01 6 5 2.41 32 960 U 0.02 1 U ~7 2.40 33 992 U 0.01 4 (> 2.39 34 102 3 U 0.0 t3 (> 2.40 35 1054 c) 0.01 7 _' 2.39 36 1085 U 0.02 t3 a 2.40 37 1 1 16 U 0.02 l U 2.40 38 1148 U 0.02 1t) 2.40 39 1177 ~ ~ 0.02 t3 5 2.39 40 1205 ~) 0.01 b `~ 2.42 41 1237 t) 0.01 4 t, 2.40 42 1268 ~~ 0.02 `) 1 2.41 43 1300 (t 0.01 ~ ) 2.41 44 1331 ~) 0.02 ti ; 2.40 45 1360 U 0.02 t ll 3 2.40 46 1392 U 0.02 t3 8 2.41 47 142 3 U 0.01 b u 2.40 48 1454 ~~ 0.02 9 1 2.39 49 1486 ti 0.02 ~~ 1 2.39 _ Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB Mod Well: 31-01 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 4, 2008 Joint No. Jt. Depth (Ft) I'~~n. Ulric~t (Ins-) Pen. Body (Ins.) Pen. `%> ~~t~~t.il I~,s~ ~, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1516 a 0.03 12 I 2.38 51 1549 U 0.02 9 I 2.39 52 1580 a 0.02 ~) a 2.39 53 1611 l) 0.02 8 1 2.39 54 1642 U 0.01 ~ 1 2.39 55 1674 a 0.02 ~) ~ 2.38 56 1701 t ~ 0.02 I t) b 2.40 57 1736 t~ 0.03 14 (~ 2.39 Q 57.1 1766 U 0 U u 2.31 TRDP-1 A-SSA 58 1775 (1 0.02 9 2.40 59 1806 t) 0.01 6 1 2.42 60 1838 i) 0.01 (> 2.41 61 1868 a 0.02 8 _' 2.39 62 1900 t) 0.02 ~) 2.40 63 1931 U 0.02 11 -l 2.40 64 1962 i ~ 0.01 4 t 2.41 65 1991 t) 0.01 6 I 2.41 66 2023 U 0.01 6 -1 2.40 67 2054 t) 0.01 6 ti 2.41 68 2085 t) 0.03 14 ~ 2.41 69 2115 t) 0.02 1 1 ~ 2.40 70 2143 (1 0.01 4 =1 2.40 71 2174 U 0.02 ~) t, 2.39 72 2206 l) 0.02 ~) t3 2.40 73 2237 l) 0.01 (i ~ 2.38 74 2268 O 0.01 4 2.38 75 2300 U 0.02 ~> 2.41 76 2331 a 0.03 12 I 2.41 77 2362 i) 0.02 9 t 2.40 78 2392 1) 0.01 (~ i 2.39 79 2423 O 0.01 ~ I 2.40 80 2454 t? 0.02 1(1 a 2.38 81 2485 O 0.02 1 1 (~ 2.38 82 2516 U 0.04 I t3 I t) 2.39 Shallow corrosion. 83 2547 t) 0.04 I £~ c, 2.36 Shallow corrosion. 84 2578 t) 0.02 10 b 2.37 85 2608 U 0.02 11 i 2.41 86 2639 U 0.02 1O I 2.38 87 2669 U 0.01 i i 2.39 87.1 2699 t) 0 0 t) N A GLM 1 Latch ®3:00 88 2707 t) 0.02 1~) I S 2.39 89 2736 U 0.02 11 2.41 90 2768 a 0.02 1 u I 2.41 91 2800 t) 0.01 7 8 2.38 92 2830 U 0.02 ~) t 2.39 93 2861 ! ~ 0.03 12 !, 2.38 94 2892 t) 0.03 IZ tf 2.38 95 2924 ~> 0.02 8 (, 2.38 96 2955 a 0.03 14 ~-, 2.36 Lt. De osits. 97 2984 t i 0.03 I ~' 2.38 _ Penetration Body Metal Loss Body Page 2 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB Mod Well: 31-01 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, tnc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 4, 2008 Joint No. Jt. Depth (Ft.) Pc~n. lll„et (Irn.) Pen. Body (Ins.) Pen. % Metal loss °i~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3015 U 0.02 11 ~ 2.37 99 3044 O 0.03 14 4 2.34 100 3075 t ~ 0.0 1< 1 1 2.38 101 3105 t~ 0.03 1 ; ~ 2.38 102 3135 t ~ 0.03 11 l t t 2.35 Lt De osi ts. 103 3166 i ~ 0.04 1 Y3 2.37 Shallow corrosion. 104 3195 t ~ 0.03 l d I 2.38 105 3226 t) 0.02 11 ~ 2.37 106 3255 U 0.02 11 4 2.38 107 3283 U 0.03 14 ? 2.37 108 3313 (~ 0.03 14 E~ 2.39 109 3343 U 0.04 17 ~~ 2.37 Shallow corrosion. Lt De osits. 110 3372 tt 0.01 7 t> 2.37 111 3403 t> 0.03 14 ti 2.36 Lt. De osits. 112 3434 U 0.02 11 ~~ 2.39 113 3463 tl 0.01 S 3 2.39 114 3493 It 0.02 £3 2 2.39 115 3524 l) 0.03 13 6 2.38 116 3556 tt 0.02 11 2.40 117 3586 tt 0.02 ~~ _' 2.39 118 3617 ! ~ 0.02 ti 2.41 119 3649 U 0.01 t~ -1 2.40 120 3679 (1 0.01 6 -1 2.41 121 3709 t) 0.01 6 3 2.39 122 3740 a 0.01 4 .' 2.39 123 3771 (1 0.01 i ~ 2.39 124 3801 t t 0.01 V I 2.41 125 3832 t~ 0.02 1l) 3 2.40 126 3864 tl 0.02 11 5 2.40 127 3895 (~ 0.01 4 2.41 128 3925 t1 0.02 9 1 2.39 129 3956 U 0.02 11 Z 2.40 130 3987 i) 0.03 14 3 2.37 131 4018 U 0.02 11 8 2.39 132 4049 U 0.01 4 2 2.39 133 4080 t ~ 0.01 6 _' 2.40 134 4110 a 0.01 6 I 2.40 135 4140 t~ 0.02 11 2.40 136 4171 U 0.02 `) _' 2.40 137 4202 U 0.01 ~~ t~ 2.40 138 4233 tt 0.01 G b 2.40 139 4265 O 0.03 14 1 2.38 140 4294 U 0.01 7 2 2.40 141 4325 U 0.01 4 3 2.41 142 4355 O 0.02 9 1 2.38 143 4383 t~ 0.03 15 5 2.40 Shallow ittin . 144 4415 U 0.01 4 ~ 2.39 145 4446 U 0.02 8 3 2.39 146 4477 t ~ 0.01 6 2.38 147 4508 U 0.01 6 2.38 _ Penetration Body Metal Loss Body Page 3 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB Mod Well: 31-01 Body Wall: 0.217 in Eield: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 4, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ut~s~~t (Ins.i Pen. Body (Ins.) Nc~n. `%~ ~tc~t.~l I ~ », ~> Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 148 4540 ~ ~ 0.01 4 I 2.40 149 4570 U 0.01 b ', 2.38 150 4601 ~ ~ 0.01 ~ 1 2.39 151 4632 t~ 0.01 ~ ~~ 2.40 152 4662 ~ ~ 0.02 1 I 2.36 153 4693 a 0.02 '~ 2.37 154 4723 ~ ~ 0.03 I . 2.36 155 4754 0 0.01 ~~ 2.38 156 4786 U 0.03 I ~' ~' 2.38 157 4816 U 0.03 11 ; 2.39 158 4847 (~ 0.02 £~ 5 2.37 159 4878 0 0.02 11 -1 2.38 160 4909 0 0.03 1 _' 2.38 161 4941 ~ ~ 0.03 1 -l 2.37 161.1 4971 ~ ~ 0 i ~ ~ ! N A GLM 2 Latch @ 3:00 162 4977 ~ ~ 0.02 1 I 2.38 163 5010 0 0. 3 1 ~ 5 2.37 164 5038 0.(15 0.03 1 ~ 2.37 165 5068 0 0.02 11 ~ 2.36 166 5099 ~ ~ 0.03 11 2.38 167 5129 a 0.03 15 2.34 Shallow ittin . 168 5160 ~~ 0.02 1 1 I 2.36 Lt. De osits. 169 5190 0 0.03 1.1 2.35 Shallow ittin . 170 5223 0 0.03 13 _' 2.37 Lt. De osits. 171 5255 U 0.03 1 ~~ 2.36 172 5286 0 0.02 11 2 2.34 Lt. De osits. 173 5317 U 0.02 8 2 2.36 174 5348 U 0.03 13 I 2.35 Lt. De osits. 175 5380 i I 0.03 14 ~) 2.35 Lt. De osits. 176 5411 ~~ 0.02 10 _' 2.35 177 5442 U 0.02 11 ~ 2.36 178 5474 ~) 0.02 l u I 2.37 179 5504 I~ 0.04 16 1 .34 Shallow ittin Lt. De sits. 180 5535 ~~ 0.03 15 ~' 2.36 Shallow ittin . 181 5567 ~) 0.04 1 £3 I 2.35 Shallow ittin . 182 5599 l) 0.03 16 2.35 Shallow ittin . 183 5629 ~) 0.03 15 I 2.34 Shallow ittin Lt. De sits. 184 5661 ~~ 0.03 I-1 I 2.34 Lt. De osits. 185 5691 i~ 0.03 15 2.35 Shallow ittin Lt. De osits. 186 5723 ~! 0.04 I ~ I 2.36 Shallow ittin Lt. De sits. 187 5754 U 0.03 16 ~) 2.35 Shallow ittin Lt. De sits. 188 5785 0 0.04 17 ~' 2.37 Shallow ittin . 189 5816 U 0.02 11 t) 2.36 190 5847 U 0.03 13 I 2.36 Lt De osi ts. 191 5879 0 0.03 1 3 I 2.36 Lt De osits. 192 5910 i ~ 0.03 1 < 1 2.36 193 5941 ~1 0.03 15 ~:i 2.35 Shallow ittin Lt. De osits. 194 5973 ~ ~ 0.03 1-1 I 2.35 Lt. Ue osi ts. 195 6003 ~ 0.03 13 ~' 2.35 Lt. De osits. 196 603 5 U.02 1 U ( 2.35 _ Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB Mod Well: 31-01 Body Wall: 0.217 in field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 4, 2008 Joint No. Jt. Depth (Ft) I'c~n. 11t~sc~t (Ins.l Pen. Body (Ins.) Pc~n. °4> 'vlc~t.~l I ~~ss °/, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 197 6066 l) 0.03 14 I 2.36 Lt. De osits. 198 6098 O 0.03 12 3 2.36 Lt. De osits. 199 6128 U 0.03 15 I 2.37 Shallow ittin Lt. De sits. 200 6159 O 0.02 II I 2.35 201 6190 U 0.03 14 O 2.35 Lt. De osits. 201.1 6221 t) 0 U U N A GLM 3 Latch @ 8:00 202 6227 Q 0.03 1Z t) 2.35 203 6258 t) 0.03 l1 ~' 2.37 204 6288 l? 0.03 12 I 2.34 I_t. De osits. 205 6320 t) 0.03 14 ~ 2.38 206 6351 U 0.03 I? I 2.37 207 6380 U 0.02 I I I 2.35 Lt. De osits. 208 6412 O.t1~; 0.02 1(1 I 2.35 Lt. De osits. 209 6443 t) 0.03 I _' I 2.36 210 6472 t) 0.03 I ' 2.37 211 6504 U 0.02 11 I 2.35 212 6536 I) 0.03 I s I 2.35 213 6567 i) 0.03 13 2 2.38 214 6597 t) 0.03 14 2 2.37 215 662 7 !) 0.02 1 1 _' 2.36 21 6659 t) 0.02 11 _' 2.37 217 6689 l).U6 0.03 12 I 2.36 218 721 0 0.03 13 I 2.35 219 6752 t1 0.03 13 4 2.36 220 6781 t) 0.02 1 1 I 2.36 Lt. De osits. 221 6814 U 0.02 11 , 2.38 222 6844 U 0.02 10 1 2.35 223 6877 U 0.02 10 ~' 2.36 223.1 6906 U 0 l1 U N A GLM 4 Latch ~ 12:00 224 6913 a 0.02 11 I 2.36 225 6944 tl 0.02 1 U I 2.38 226 6976 U 0.02 11 I 2.36 227 7007 0 0.02 1 'I I 2.36 228 7038 U 0.02 11 I 2.37 Lt. De osits. 229 7068 tl 0.02 11 3 2.36 230 7099 U 0.03 12 I 2.36 Lt. De osits. 231 7131 t) 0.03 1 Z _' 2.35 232 7162 t~ 0.02 1l I 2.37 233 7193 t) 0.03 11 ~) 2.36 Lt. De osits. 234 7224 t) 0.03 13 I 2.35 235 7253 t) 0.03 12 2 2.35 236 7282 (? 0.03 13 ~ 2.36 236.1 731 1 t) 0 O U N A GLM 5 Latch @ 3:00 237 7319 U 0.03 1(~ i 2.37 Shallow ittin . 238 7349 U 0.03 1 ~ I 2.35 239 7379 a 0.02 11 ? 2.37 240 7410 t; 0.03 13 I 2.33 Lt. De osits. 241 7442 ~ ~ 0.02 I 1 I 2.35 242 7470 0.02 1 t) 2.37 243 7502 0.03 I ~ 2.37 Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf )-55 EUE 8RD AB Mod Well: 31-01 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 4, 2008 Joint No. Jt. Depth (Ft.) I'c~n. Ul~se~t (lns.) Pen. Body (Ins.) I'~~n. °4, Mc~t,~) L~,~, ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 244 7533 U 0.02 11 2.36 245 7562 () 0.04 17 ' 2.36 Shallow ittin . 246 7594 a 0.02 It) 2.35 247 7625 U 0.02 ~~ _' 2.38 248 7657 t) 0.03 13 2.36 Lt. De osits. 249 7689 a 0.02 11 2.36 250 7720 U 0.04 I tS I 2.35 Shallow ittin LL De osits. 250.1 7751 t) 0 U i) N A GLM 6 Latch @ 11:00 251 7758 t) 0.03 I :> 235 Shallow ittin . Lt. De osits. 252 7789 t) 0.03 15 I 2.33 Shallow ittin . 253 7819 t) 0.03 I Z > 2.35 254 7850 t) 0.03 12 2.36 255 7880 U 0.03 15 I 2.36 Shallow ittin Lt. De sits. 256 791 1 U 0.03 1 Z ~' 2.36 257 7942 a 0.03 14 1 2.33 Lt. De osits. 258 7973 U 0.03 1(, 2.36 Shallow ittin . 259 8006 t) 0.02 1 ~) ~ 2.37 260 8036 t) 0.04 1' U 2.32 Shallow ittin LL De osits. 261 8066 t) 0.03 15 1 2.35 Shallow ittin Lt. De osits. 262 8099 U 0.03 I < i) 2.33 L.t. De osits. 263 8131 O 0.03 13 I 2.37 Lt. De osits. 264 8161 a 0.03 12 0 2.34 Lt. De osits. 264.1 8192 U 0 l) t) N A GLM 7 Latch @ 3:00 265 8197 0 0.03 15 _' 2.35 Shallow ittin Lt. De osits. 266 8230 0 0.03 1 Z u 2.31 Lt De osits. 267 8260 U 0.03 15 U 2.33 Shallow ittin Lt. De osits. 268 8291 t) 0.04 17 I 2.33 Shallow corrosion. Lt. De osits. 269 8324 U 0.03 14 a 2.34 Lt. De osits. 270 8354 U 0.04 1 7 _' 2.35 Lt. De osits. 271 8385 11 0.03 14 I 2.30 Lt. De osits. 272 8416 t) 0.03 14 l) 2.33 Lt De osits. 273 8450 t) 0.02 1 l 1 2.35 Lt. De osits. 274 8480 U 0.02 11 O 2.34 Lt. De osits. 274.1 8510 t) 0 O t) N A GLM 8 Latch C 3:00 275 8520 a 0.03 11 t) 2.31 275.1 8551 t) 0.02 1U 4 2.34 PUP 275.2 8556 u 0 U U N A PBR 275.3 8575 t) 0 U 0 N A Packer .1 8581 t) 0.02 12 t) 1.66 PUP 1st t.2-3 8 __ Penetration Body Metal Loss Body Page 6 t f I • KRU 31-01 ['_nnncePhillins Alaska. Inc. 3I-OI (PTD 185-307} tubing leak ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, March 08, 2008 6:00 PM 3~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~ Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 31-01(PTD 185-307) tubing leak Attachments: 31-01 TIO.jpg; 31-01.pdf :/ Jim & Tom Kuparuk gas lifted producer 31-01(PTD 185-307) was discovered to have a tubin leak on 3/6/08 at 8384' while being secured for inner casing packoff maintenance and has been added to the weekly SCP report. The TIO prior to shut in for securing was 600/1150/375. A leaking tubing joint is suspected. A caliper log is scheduled and will follow with a patch after which a 10-404 will be submitted. The well will remain SI until the patch is installed. W/ Attached is a 90 day TIO plot and a schematic. «31-01 TIO.jpg» «31-01.pdf» Please let me know if you have any questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~ APR ~ ~ 2na~ 3/19/2008 C7 • ~- KRU 3I-O1 PTD 185-307 ~~-~ • Gon~ccaphlips Alaska, #nc 3z=o ;; • KRU 31-01 - - --- -- API: ~ 500292151400 ~ Well Type: ~ PROD I Angle C~ TS:142 deg (07 8631 I '+, 03/12/08 ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 1 ~. _- r ~ Log Description NO. 4624 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~/ ~ `~'~ O ~~ Date BL Color CD 1 A-12 11964583 LDL ~°~ (_- (~- 02/28/08 1 1E-1126 SAND LATERAL 11978443 MEM INJECTION PROFILE 03/03/08 1 iR-04 11964585 USIT ~. - 03/02!08 1 2L-330 11837544 OH EDIT (SONIC SCANNER) ''}~ ~' 11/27/07 1 1 31-01 11994626 LDL 03/06/08 1 2N-327 11994628 PRODUCTION PROFILE ~~--. 03/08/08 1 1Y-28 11994629 PRODUCTION PROFILE .~ ~ 03/10/08 1 3S-08C 40016310 OH MWD EDIT VISION SERVICE '~" L( 01/17/08 1 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ARCO Alaska, Inc. Post Office B~.. ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 24, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL ACTDN 31-01 Stimulate If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer J. R. Brandstetter ATO 1120 S. M. Renke ATO 1126 KOE1.4-9 w/o attachments RECEIVED MAY AJaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc ~s a Subsidiary of AtlanhcR~chheldCompany /\1{'~[~ ~007, C STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed' Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc, 3. Address 5. Type of Well: Development X Exploratory _ Stratigraphic _ Plugging Perforate _ Other 6. Datum elevation (DF or KB) 71' RKB 7. Unit or Property name feet P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 345' FSL, 179' FWL, Sec. 31, T13N, R9E, UM At top of productive interval 1545' FNL, 4571' FWL, Sec. 31, T13N, At effective depth 1525' FNL, 4768' FWL, Sec. 31, T13N, At total depth 1517' FNL, 4843' FWL, Sec. 31, T13N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 9 0 3 0' true vertical 6541 ' feet Plugs (measured) feet Kuparuk River Unit 8. Well numbe~r 31-01 9. Permit number/approval number prior aporoval not reauired 10. APl number 50-029-21514 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 8 91 9' true vertical 6460' Casing Length Size Structural Conductor 8 0' 1 6" Surface 431 5' 9 - 5 / 8" Intermediate Production 8986' 7" Liner Perforation depth: measured feet Junk (measured) feet Cemented Measured depth True vertical depth 274 Sx CS II 104' 104' 1650 Sx AS III & 4346' 3304' 320 Sx Class G 300 Sx Class G & 9 01 0' 65 2 6' 175 Sx AS I 8734'-8754' @ 6 SPF, 8740'-8760' @ I SPF, 8770'-8798' @ 4 SPF true vertical 6326'-6341', 6330'-6345', 6352'-6373' Tubing (size, grade, and measured depth) 2 7/8" 6.5# J-55 AB modified tubing set @ 8651' Packers and SSSV (type and measured depth) Camco TRDP-1A-SSA SSSV @ 1779', Camco HRP-1-SP or cement squeeze summary Hydraulically refractured the A sand Intervals treated (measured) 8734'-8798' Treatment description including volumes used and final pressure See attached well service report i74' RECEIVED MA'( 5 0 t99 Alaska 0ii & Gas Oons. Anchorage 14. Prior to well operation Subseq,uent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Re_oresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 61 45 0 1100 338~'~ 340.-~-~ 16 ' 1100 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service Tubing Pressure 138 162 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE IFIELD- DISTRICT- S~ OPERATION AT REPORT TIJ~E WELL SERVICE REPORT / -?/ (D 7,.~o- 4e7o ~,c6 . ~ 7177 ~/. ' " ' Ri::_C EIxt t:u Alaska Oil & 6as Cons. E:] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor I Visibility I Wlnd Vel. Report °F °FI' '::! miles ARCO Alaska, inc. Date' February 23, 1989 Transmittal #: 7432 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F-15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 12-18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 12-04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-2O-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' Amerada Casing Casing Casing Casing Tubing Tubin 3 H- 01 Kupaurk Fluid Level Report 2-15-89 Casing 3B-1 3 Kupaurk Fluid Level Report 2-1 7-89 Casing I E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3 M - 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged' . .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron - "" L~,r,,., - 'Ur4g8 '/z/$$zo~ ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7225 RETURN TO: ARCO Alaska, Inc. Attn' Brenda K. Miernyk Kuparuk Records Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return ,30-15 Kuparuk · 3 O- 10 Kuparuk e 2 D- 1 5 Kuparuk * 2 A- 06 Kuparuk ,, 1 G - 07 Kuparuk ,' 1 G - 08 Kuparuk ~ 1 G- 15 Kuparuk ' 31 - 01 Kuparuk ~ 31-1 2 Kuparuk ~2A-03 ~ 3H-1 4 ~ 2B-16 ~, 3J-10 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-lO PBU Amerad Receipt Acknowledged: --'- ........................ Date: ............ ~ISTRIBUTION: D&M State of Alaska SAPC Mobil Unocal Chevron ARCO Alaska, Inr~ Posl Office ...,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 22, 1987 Transmittal #: 6062 RETURN TO: ARCO Alaska, inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-1 3I-1 IR-4 1R-6 3C-14 3I-5 3M-16 3M-18 3M-19 · PBU Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey Static BHP Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey 'A' Sand PBU Bottomhole Pressure Survey Kuparuk Well Pressure Report(Otis) 8-20-87 Kuparuk Well Pressure Report(Otis) Static 'C' Sand Kuparuk Well Pressure Report (Otis) Static Kuparuk Well Pressure Report (Otis) 8-15-87 8-27-87 8-20-87 8-21-87 8-16-87 50-029-21413 50-029-21407 50-029-21331 50-029-21425 9-7-87 9-14-87 9-14-87 Receipt Acknowledged: DISTRIBUTION: / .... Anchm~age .... Date: D&M State of Alaska BPAE Chevron Mob il SAPC Unocal ARCO Alaska, Inc, is a Subsidiary ol AllanllcRichfteldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal # 5933 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-16 2T-12A 2A-11 3A-9 lA-1 3A-9 1H-3 3K-13 3K-14 3I-1 3F-15 CET/CEL 9-15-86 8181-8720 CET/CEL 9-27-86 4595-6644 CET/CEL 3-14-86 5800-6564 CET 7-26-86 2000-6299 CEL/CET 8-29-86 2708-7255 CET/CEL (After Squeeze) 7-31-86 2128-6039 CET 7-16-86 6891-7617 CET/CEL 8-17-86 6849-8455 CET/CEL 8-18-86 7215-8844 CET/CEL 1-24-86 7588-8887 CET/CEL 1-13-86 6600-7384 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC BPAE Chevron Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfleldCompany ' ' STATE OF ALASKA ~-~ ~ ALASKA u~L AND GAS CONSERVATION CO,,~,,MISSION WV~ W =L__L COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILX~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2~eAOlfaOsl~eara~tO~.nc' 7. Permit Number 85-307 8. APl Number 3,,Adc]rest, r'. u. ~ox 100360, Anchorage, AK 99510 50- 029-21514 9. Unit or Lease Name 43~c~at~sri_°~f~v~"t~lfa~Cesec.31, T13N, R9E, UM Kuparuk River Unit 10. Well Number 11. Field and Pool l~st1~°'ta~IeP, t~843' FWL, Sec.31, T13N, R9E, UM Kuparuk River Field 57El~evati°nT RKB in feet (indicate KB, DF, etc.) I 6.ADLLease25521DesignationALK 2557and Ser,al No. Kuparuk River 0i 1 Pool 1 la2r~/qnudded~[ 7~0~ .~r~ 13 Date T D. Reached 14. Date comp., Susp. or Aband. 15. Water Depth, if offshore1116' No. of Complet,ons 0~'/08/8r~ 06/21/86*' N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 1~' Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9030'MD,6541 'TVD 8919'MD,6460'TVD YEY~XI--I NO [] 1779 feet MD 1650' (approx.) I 22. Ty.p_e Electric or Other. Logs Run DILTGR/SP/SFL, FDC/CNL, Cal, CST, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD 'AMOUNT PULLED 16" ~2.5# H-40 Surf i04: z4~; 2/4 sx C5 II 9-5/~" J~.u# J-~ Surf 4346' 12-1/4" 1650 sx AS Ill & 320 sx ;lass "G" ?;; ze.u# J-55 Surf 9010' 8-1/2" 300 sx Class G & 175 sx ~S I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) 8740' - 8760'MD 6329' - 6343'TVD 2-7/8" 8651' 8574' 8770' - 8798'MD 6350' - 6371'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum (dated 6/26/86) for fracture data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor~) Press. 24-HOUR RATE 28. CORE DATA Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10~07 Rev. 7-1-80 * NOTE: Drilled RR 1/9/86. Perf'd well & ran tubing 5/29/86. CONTINUED ON REVERSE SIDE WC1/087 Submit in duplicat~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8628' ~247' N/A Base Kuparuk C 8664' ;274' Top Kuparuk A 8723' $317' Base Kuparuk A 8825' $391' 31. LIST OF ATTACHMENTS Addendum (dated 6/26/86) 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned ~~ k'/~ [~/.~ TitleAss°clare Engi neet Date--'~/~ ~(~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 1128186 6/21/86 3I-1 Arctic Pak w/175 sx AS I, followed by 59 bbls Arctic Pak. Rn CET & gyro. Frac Kuparuk "A" sand perfs 8740'-8760' & 8770'-8798' in 9 stages per 6/20/86 procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd ann to 2500 psi w/diesel. Tst ins to 9300 psi; OK. Stage #1: Pmp 20 bbls 140° diesel w/5% Musol @ 5 BPM w/3750 psi Stage #2: 72 bbls gel/diesel spacer @ 11-20 BPM w/6900-5720 psi Stage #3: 20 bbls gel/diesel pre-pad @ 20 BPM w/5600-5620 psi Stage #4: 24 bbls gel/diesel w/1 ppg 100 mesh @ 20 BPM w/5620-5570 psi Stage #5: 150 bbls gel/diesel pad @ 20 BPM w/5570-5470 psi Stage #6: 20 bbls gel/diesel w/3 ppg 20/40 @ 20 BPM w/5470-5650 psi ("on fly") Stage #7: 43 bbls gel/diesel w/6 ppg 20/40 @ 20-18 BPM w/5650-6850 psi ("batch") Stage #8: 20 bbls gel/diesel w/8 ppg 20/40 @ 18 BPM w/6850-7000 psi ("batch") Stage #9: 52 bbls gel/diesel flush @ 18-20 BPM w/7000-6000 psi Pmp'd 1000# 100 mesh & 19,800# 20/40 in formation leaving 270# 20/40 (per procedure) in csg. Load to recover 421 bbls of diesel. Job complete @ 1245 hrs, 6/21/86. Turn well over to Production. Production to rn post frac logs. Drilli~~uperinten~ Da/te STATE OF ALASKA ~- ALASKA .,,IL AND GAS CONSERVATION COMMI,_ .ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate:~( Pull tubing Alter Casing [] Other::~:: Comp'fete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchoraqe, AK 99510 4. Location of well at surface 345'FSL, 179'FWL, Sec.31, T13N, RgE, UM At top of productive interval 1545'FNL, 4571'FWL, Sec.31, T13N, RgE, UN At effective depth 1525'FNL, 4768' FWL, Sec.31, T13N, R9E, UN At total depth 1517'FNL, 4843'FWL, Sec.31, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 71 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 31-1 8. Approval number Permit #85-307 9. APl number 50-- 029-21514 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4315' 8986' Production 9 0 3 0 feet 6 5 41 feet 8 91 9 feet 6 4 6 0 feet Plugs (measured) No ne Junk (measured) No ne Size Cemented Measured depth 16" 274 sx CS 11 104'MD 9-5/8" 1650 sx AS I I I & 4346 'MD 320 sx Class G 7" 300 sx C1 ass G & 9010'MD 1 75 sx AS I True Vertical depth I 04 ' TVD 3304 'TVD 6526'TVD Perforation depth: measured 8740 ' 8770 ' true vertical 6329 ' 6350 ' Tubing (size, grade and measured depth) - 8760'MD - 8798'HD - 6343'TVD - 6371'TVD 2-7/8", J-55, tbg w/tail ~ 8651 ' Packers and 8SSV (type and, measured depth) HRP-1-SP pkr @ 8574 & TRDP-1A-SSA SSSV ~ 1779' RECEIVED JUN t 7 ]986 Alaska 011 & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations:~12~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (DAM) 5W0/053 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the hrst 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 indehmte or appreciable length of hme On workovers when an official test is not required upon completion, report completion and representatrve test data ~n blocks prowded The "Final Report" form may be used for reportmg the entire operation it space is available District Alaska Field ICounty or Parish Lease or Omt T~tle Kuparuk River Auth. or W.O no AFE AK0901 Nordic #1 Operator North Slope Borough ADL 25521 Accounting cost center code State Alaska Iweu n~i_l Completion API 50-029-21514 Total number of wells (active or ~nact~ve) on th~s i cost center prior to plugging and ~ I ARCO Alaska, Inc. Spudded or W O begun IARCo WI 56.24% IDate 5/28/86 labandonment of th~s well . [Prior Hour 1230 Hrs status if a W.O. Complete Date and depth as of 8 00 a m Old TO Released rig 5/28/86 thru 5/29/86 0600 Hrs. Class{hcations (od, gas, etc ) Oil Producmg method Flowing Potenhal test data Complete record for each day reported 7" @ 9010' 8882' WLM PBTD, RR 9.9 ppg NaCl/NaBr Accept rig @ 1230 hrs, 5/28/86. ND tree, NU & tst BOPE. RU Schl, perf 8770'-8798', w/4" gun, 4 SPF, 90° phasing, 8740'-8760' w/lspf, 90° phasing. RD Schl. Rn 275 its, 2-7/8", J-55, 6.3#, EUE 8RD AB Mod tbg w/SSSV @ 1779', HRP-i-SP Pkr @ 8574', TT @ 8651'. Set pkr, tst tbg, csg & SSSV. ND BOPE, NU & tst tree. Displ well to diesel. RR @ 0600 hrs, 5/29/86. RECEIVED JUN 1 7 1986 0il & Gas Cons. Commb~.., Anchorage TD New IPSDepth 8882 ! I Date {Kind of rig 5/29/86 I Rotary Type completion (s~ngle, dual, etc ) Single { Ofhc~al reservoir name(s) Kuparuk Sands Well no Date Reservoir Produc{ng Interval Od or gas Test time =roduchon Od on test Gas per day Pump size, SPM X length Choke s~ze T P C P Water % GOR Grawty Allowable Effective date corrected Drilling Supervisor For form preparatj~d,str,bution, ~ see Procedures ~al, Section 10, Dnlhng, Pages 86 and 87 ADDENDUM WELL: 1/28/86 31-1 Arctic Pak w/175 sx AS I, followed by 59 bbls Arctic Pak. Rn CET & gyro. Drilling fSuperintendent / I~ate STATE OF ALASKA ~- ALASKA OiL AND GAS CONSERVATION COIv, MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 0 1 Status of Well Classification of Serwce Well OIL [] GAS [] SUSPENDEDYi~ ABANDONED [] SERVICE [] 2 Name of Operator 7. Permit Number AR60 Alaska, Inc. 85-307 3. Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21514 4 Location of well at surface 9. Unit or Lease Name 345' FSL, 179' FWL, Sec.31, T13N, R9E, UN ~ Kuparuk River Unit At Top Producing IntervalI~'~'~"'-"~L' 1-1 VF-'P'H:iEE) ~ 10. Well Number 1545' FNL, 4571' FWL, Sec.31, T13N, RgE, UN 31-1 At Total Depth i 1 1. Fmld and Pool 1517' FNL, 4843' FWL, Sec.31, T13N, R9E, UN.u.-~--~---~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 71' RKBI ADL 25521 ALK 2557 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp orAband. I 15. Water Depth, .f offshore 116 No of Completions 1 2/30/85 01/08/86 01/09/86I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. D~rectionalSurvey I 20 Depth where SSSV set 21 Th~ckness of Permafrost 9030'MD,6541 'TVD 8919'MD,6460'TVD YES ~( NO []I N/A feet MD 1650' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GST, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 1 04' 24" 274 sx CS I I 9-5/8" 36.0# J-55 Surf 4346' 12-1/4" 1650 sx AS Ill & 320 sx Class "G" 7" 26.0# J-55 Surf 9010' 8-1/2" 300 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flow,ng, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~ .... 28 CORE DATA Brief description of I~thology, porosity, fractures, apparent d~ps and presence of oil, gas or water. Submit core ch~ps. None , , ~ , ,, Form 10-407 DAM/WC82 Submit in duplicate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT DEPTH 6247' 6274' 6317' 6391' 3O FORMATION TESTS 8628' 8664' 8723' 8825' Include interval tested, pressure data, all fluids recovered and gravity, IGOR, and time of each phase N/A 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Associate Engineer INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells. Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc--. Post Offi ;ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are the Well Completion Reports for the following wells' 2A-12 3 I:-1' ~ DS 16-21 The bottomhole locations, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic surveys are run and the wells completed. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L148 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldCompany .... STATE OF ALASKA ALASKA O,c AND GAS CONSERVATION CO,v, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Serwce Well OIL [] GAS [] SUSPENDED~1~ ABANDONED [] SERVICE [] 2. Name of Operator 7 Permit Number ARCO Alaska, Inc. 85-:307 3. Address 8. APl Number 029-21514 P. 0. Box 100:360, Anchorage, AK 99510 50- 4. Location of well at surface 9. Unit or Lease Name 344' FSL, 179' FWL, Sec.31, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. :31-1 At Total Depth 11. F~eld and Pool To be submitted when gyro is received, Kuparuk River Field 5. Elevation in feet (,ndicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 71' RKBI ADL 25521 ALK 2557 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, ~f offshore [16 No of Completions 1 2/:30/85 01/08/86 01/09/86 N/A feet MSL N/A I I 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. D~rectionalSurvey I 20. Depth where SSSV set 21. Th~ckness of Permafrost 9030'MD 8919'MD YES ~X NO [] N/A feet MD 1650' (approx) I 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GST, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 274 sx CS II 9-5/8" :36.0# J-55 Surf 4346' 12-1/4" 1650 sx AS Ill & :320 .~x Class "G" 7" 26.0# J-55 Surf 9010' 8-1/2" :300 sx Class G & 175 .~x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST ... Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of o~1, gas or water. Submit core chips. None Form 10-407 DAH/WC45 Submit in dupl,cate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29 NAME To be submitted wi GEOLOGIC MARKERS~ MEAS. DEPTH en gyro is recei TRUE VERT DEPTH red. 30 FORMATION TESTS Include ~nterval tested, pressure data, all fluids ~ecovered and gravity, GOR, and time of each phase N/A 31 LIST OF ATTACHMENTS Well Hi story 32 I hereby certify that the foregoing IS true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a welt is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form g~wng inclusive dates only. I County, parish or borough North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25521 Auth, or W.O. no. ~Title AFE AK0901 J Drill Parker 141 API 50-029-21514 IState District Alaska Alaska IWell no. 3I-1 Operator ARCO Alaska, Inc. ARCO W I. Prior status if a W,O. Spudded IDate 12/30/85 ]Hour Spudded or W.O. begun Date and depth as of 8:00 a.m. 12/28/85 thru 12/30/85 12/31/85 1/01/86 thru 1/02/86 1/03/86 Complete record for each day reported 0300 hrs. 56.24% 16" @ 104' Z37', (133'), Drlg Wt. 8.5, PV 8, YP 7, PH 9.5, WL NC, Sol 2 Accept ris @ 1630 hfs, 12/29/85. NU diverter sys. 0300 hfs, 12/30/85. Drl 12¼" hole to 237'. SB.ud well @ 16" @ 104' 1925', (1688'), POH f/BHA chg Wt. 9.6, PV 9, YP 14, PH 8.5, WL 18.9, Sol 7 DD & surv to 1925', POOH. 553', 7.3°, N49E, 552.68 TVD, 10.19 VS, 6.62N, 7.75E 1003', 20.4°, NS1.SE, 988.07 TVD, 119.27 VS, 78.46N, 90.65E 1460', 33.6°, N48E, 1393.98 TVD, 327.35 VS, 212.92N, 249.46E 1870', 46.5°, N48.7E, 1709.05 TVD, 588.62 VS, 386.33N, 445.02E 9-5/8" @ 4346' 4365', (2440'), Break dn 9½" turbine Cln'g pits Drl 12¼" hole to 4365', short trip, C&C, POH. RU & rn 110 its, 9-5/8", 36#, J-55 HF/ERW BTC csg w/FS @ 4346', FC @ 4266'. Cmt w/1650 sx AS III + 320 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 2100 hfs, 1/1/86. ND diverter, NU & tst BOPE. 2217', 48.4°, N50E, 1943.70 TVD, 844.23 VS, 552.86N, 638.47E 3032', 50.6°, N49.3E, 2469.38 TVD, 1466.95 VS, 958.43N, 1111.55E 4029', 49.5°, N51.1E, 3110.54 TVD, 2230.33 VS, 1441.01N, 1703.14E 4330', 48.8°, N49.SE, 3307.42 TVD, 2458.01VS, 1585.99N, 1878.70E 9-5/8" @ 4346' 6015', (1650'), Turbine drlg Wt. 9.5, PV 7, YP 4, PH 10, WL 18.6, Sol 8 PU BHA, tst csg to 2000 psi. DO flt equip & cmt + 10' new hole. Conduct formation tst to 12.5 ppg EMW. POOH, PU turbine, RIH, drl to 6015'. ~-~ 4735', 48.6°, N49.7E, 3574 72 TVD, 2762.27 VS, 1782.58N, 2110.92E 5266', 47.5°, N49.9E, 3929.68 TVD, 3157.19 VS, 2037.48N, 2412.56E 5768', 46.8°, N48.9E, 4271.08 TVD, 3525.20 VS, 2276.99N, 2692.00E The above is correct Signature Yor form preparation ~nd d~stnbution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Title Drilling Superintendent ARco Oil and Gas Companyv'~' Daily Well History--Interim Instructions: This form ~s used during dnlhng or workover operahons If testing, coring, or perforahng, show formation name in describing work performed. Number ali drill stem tests sequent;ally Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until hnal completton. Report official or representative test on "Final" form 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in whtch oH stnng ~s set Submit weekly for workovers and following setting of o~1 string unhl completion. District Field Date and depth as of 8.00 a.m. I County or Parish Alaska North Slope Borough Lease or Unit Kuparuk River ADL 25521 Complete record for each day while drdhng or workover m progress 11o4186 thru 1/06/86 1/07/86 1/08/86 1/09/86 IState Alaska IWell no. 3I-1 9-5/8" 8945', Wt. 10.1, PV Turbine drl, 6295', 45.9° 6856', 45.6° 7234', 45.9° 7734', 48.7° 8234', 42.5° 8544', 41.5° @ 4346' (2930'), Drlg 11, YP 8, PH 9.5, WL 8.2, Sol 13 drl & surv 8½" hole to 8945'. , N48.9E, 4634.84 TVD, 3906.45 VS, 2527.66N, 2979.35E , N47.7E, 5026.30 TVD, 4308.12 VS, 2794.98N, 3279.38E , N52.3E, 5290.06 TVD, 4578.88 VS, 2969.02N, 3486.80E , N56.9E, 5629.14 TVD, 4945.15 VS, 3181.85N, 3786.32E , N74.4E, 5978.97 TVD, 5289.14 VS, 3329.14N, 4111.78E , N83.1E, 6209.34 TVD, 5471.00 VS, 3369.61N, 4315.22E 9-5/8" @ 4346' 8959', (14'), Cond f/logs Wt. 10, PV 11, YP 6, PH 9.5, WL 7.4, Sol 12.5 Drl 8½" hole to 8959', 35 std short trip, circ, POH to log; stuck @ 4513', wrk'd loose, POOH. RIH to cond f/logs. 8905', 42.7°, N83.4E, 6477.19 TVD, 5673.40 VS, 3398.06N, 4555.57E 9-5/8" @ 4346' 8959', (0'), Logging w/GST Wt. 9.9, PV 10, YP 6, PH 9, WL 9.2, Sol 11.8 RIH, C&C f/logs, POOH. RU & rn DIL/GR/SP/SFL f/8914'-4340' FDC/CNL f/8914'-8550', 7100'-6800', & 4600'-4400', CAL f/8914'-4340'. Rn GST f/3500'-3050' & 3 rns f/3450'-3100'. 9-5/8" @ 4346' 9030', (71'), Rn'g 7" csg Wt. 9.8+, PV 8, YP 4, PH 8.5, WL 9.2, Sol 11.4 Fin logging w/GST, RD Schl. TIH, 20 std short trip, C&C, TOH, LD DP. Chg rams to 7" & tst. RU & begin rn'g 7" csg. The above is correct Signature For form prepa~ratlon and dl~'trlbutlon see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling 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 ~s Plugged, Abandoned, or Sold "Final Report" should be submitted also when operahons are suspended for an mdehmte or appreciable length of t~rne On workovers when an official test is not required upon completion, report completion and representative test data m blocks prowded The "Final Report" form may be used for reporting the entire operation if space is avadable. D~stnct ICounty or Parish A!_~ska I North Slope Borough Field ~Lease or Umt Kuparuk River I ADL 25521 Auth. or W.O. no. ~Title AFE AK0901 I Drill Parker 141 API 50-029-21514 I Accounting State cost center code Alaska IWell no. 31-1 Operator I A.R.Co. W.I. ARCO Alaska, Inc. ] 56.24% Spudded or W O. begun Date Spudded 12/30/85 Date and depth as of 8:00 a.m. Old TD 1/lO/86 Complete record for each day reported Iotal number of wells (active or ~nactlve) on thisl ost center prior to plugging and I bandonment of this well our I Prior status If a W.O. 0300 hrs. I 7" @ 9010' 9030' TD, 8919' PBTD, RI[ 10.0 ppg brine Rn 206 jts, + 2 mkr its, 7", 26#, J-55 BTC csg w/FS @ 9010', FC @ 8919'. Cmt w/100 sx C1 "G" w/50/50 Healey flyash & 8% D-20, .2% D-46, .5% D-65 & .5% D-112, followed by 200 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Bump plug. CIP @ 1350 hrs, 1/9/86. ND BOPE, NU & tst tree to 3000 psi. RR @ 1930 hfs, 1/9/86. INew TD Date PB Depth 9030' TD 8919' PBTD Released rig Kind of rig 1930 hrs. 1/9/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc ) Oil Single Produmng method Official reservoir name(s) Flowing Kuparuk Sands Potenhal test data Well no. Date Reservoir Producing Interval Od or gas Test hms Production Oil on test Gas per day I Pump size, SPM X length Choke s~ze T.P. C.P. Water % IGOR Gravity Allowable Effective date corrected The above is correct For form preparahon and dis~ribuhon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87 IDate Drilling Superintendent SUB-$URFACE DIRECTIONAL ~URVEY [~]UIDANCE ~]ONTINUOUS [-~'] OOL Company Well Name , Field/Location ARCO ALASKA INCORPORATED WELL 3I-1 (345' FSL, 179' FWL, S31, T13N, R9E) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71259 SA_LAZAR Date 11-FEB- 1986 Computed By: CUDNEY 'J~T]4E~ LI~TiNi ~q-] &L&SKa, Zq'. 3Z-! VI~T-t.3]S 3: S]4~'Jt":ITZD 1 V:~Ti~L q~CTr~'4: -I-'e, IZ. ~P, 3J':ST::] 3'4'r] '~ TI~ :&ST 3t-1 ~]~TH SL3~E,AL~SK4 D4Ti OF Sd~V{Y: 2~-J~-~5 <CLLY ~JS~IN$ ~L~T£]N: 1 71,30 r:T TRUE ~E&S'JRE3 VERTi' ~L V-~TIC~L O.OO O.OO -71.30 130.03 130.30 29.00 230.93 290.39 lg?.OO 330.03 330.00 223.00 ~30.03 3~.73 325.93 500.03 ~)).53 423.93 530.33 599.30 52~.00 730.33 597.~6 525.35 ~O0.'3O 794.53 7£3.35 ~30.03 33~,79 ~i5.7~ 1030,33 933,53 )1g,53 1130.33 1075,70 1035,70 1230,)3 1167.26 13~6.26 1330.93 1255.51 i!~.51 1~00.00 1341,32 1273,0Z 1530.30 la23,~2 1352,~2 1500.00 1533.~ !~32.4~ 1733.39 15BO.ZO 150),23 1~90.33 1653.55 15~i.55 1~30.33 1723.31 1552.51 2330.33 1791.22 1723.23 2130.30 1858.2~ i7'37.23 2230.33 1924.52 1933.52 23~0.33 1~90,D4 191~,9~ 2~30.33 2054,24 i9~.2~ 2500,0] 2117,57 29~o.57 2500,00 2181,~5 2113,45 2730,]3 22~5,~4 Z!7~.~4 g~20,]O 2308.~ 2g37,g4 2~]2.00 237Z.~3 3303.03 2935,75 Z35~,75 3130.33 2~)8.~4 3290.33 255Z.~7 Z491,~7 3300.33 2525.¢7 ~55~.~7 3~30.30 253~.~ ZSl~.~ 3532.00 g754.~4 25{3.4~ 3530.33 3730.33 ~8~3.16 Z{12.76 3~30.33 3013.72 294~.72 C]JPS= 3=Vi&Ti3~ &Zi'.IjTH )ES q'N 3F3 0 0 N 3 3 O 11 S 73 3 33 W ~5 43 5 15 ~ ~5 27 9 6 ~ 4~ 51 11 ~ ~ a4 57 15 ~3 N ~7 $~ -'VEN 103 ~:=T S=CTION FEET -0.05 3.~3 1,03 2,44 7.9~ ~3.52 33.a~ 57.49 ~2.37 125.33 !5~.40 295.7~+ 252.73 353. 35 55,2.33 772.35 1375,50 1153,52 12~3,35 !~37,50 1~57.26 15~7.77 1515.~9 153~.2~ 1771 ,07 I~23,~2 Z'330.05 2152.34 ] D~TH DO.q_ES RE'TiNSUL~ C33RDIWAT=S 91711. 9E~4?TUqE S:V'~ITf qJRTi/S']UTq EaST/~=ST DIST. &ZI'qJT~ O.O3 0.33 N 0.30 3.33 3.3q ~ 3.'32 J.3:] 3.3'~ 5 0.-9 3.3~ 3.33 ~ 1.37 1,8~ 1,37 N 2.~ ,3,75 ~,37 W 5.)2 3,54 13. ~ W ~ 5 06 ~,21 25,~5 N 27.~5 3.1~ 43.33 N 45.Z1 !.51 52.55 '4 53.05 2.02 3.7! 2.75 2 .a3 2.72 2.q3 I.~5 3.73 3.52 1.33 3.22 3.53 '{ {, 105 · 13'4, 155. 199, 237, 277, 31). 36~+ · '~ii, 50 q ~4,75 79 W 123,73 22 ~t 153,25 ~2 N 22~.73 ~3 ~ 271,15 53 N 315.59 ~0 N 264,79 73 N 41 5,58 ~50.53 N 524.57 50~.19 '4 580.5~ 557.54 N 637.7~ 505.33 q 695.75 ~55.72 '1 75~.1~ 735.10 ~ 812.7~ 75~,~1 N 871,1) 53b.~3 W 929.46 ~05.2~ M 1047.35 3.15 3.63 3.25 3.45 ].65 ~.60 ~.55 g55.12 '~ 1105.55 = 1335.9~ ~ 1165.g~ ~ !355.54 4 1225.35 _~ I105.3~ N 12~$.15 ~ 1232.94 ',1 1402.37 ': 115!.3~ H 14~1,73 ~ 1295.72 'I 1521.12 ': 1345,21 N 15ti,I) ~ 0.30 3.05 O.~ 1.12 7.)3 23.55 62.52 126.55 205.75 252.75 304.54 369.4~ 4S5.12 552.~7 595.03 '~7.15 1376.5.5 1153.$~ 1230.32 1307,77 1375.}3 l~SZ.~+! 1539. )I 1517.13 159~.33 1771.12 15~7.52 ~ ': ~ '3.12 2375.3~ ZlS~. 03 31 -1 KJD~RJ< ND~TH 5LOOE,aL;5<~ '3~DJF~T!DN D~TE: D~T7 3= SJRVfY: 2~-JIN-35 KfLLY 3US~iqG 7LEVaT[D~: ? 7!.09 FT 'qE~SURF_3 Z`4TSq°3L~TS3 V~LJ=S =3~ =VEN lO0 ;EET g= V=RTi'IL 4000.00 30F8,51 5307.51 4130.0P ~143.15 ~372.1{ 4230.00 320~.11 3137.11 ~3OO.O0 3273.~7 3202.47 4~00.00 3339.55 326{.55 4530.00 34JS.BO 333~.30 4530.00 ~470.83 4700.00 3536.72 4~30.0~ 3602.73 B53i.73 5ODO.D3 5100.03 3502.~t 373!.61 3230.0J 3~5).30 37~.~0 5330.00 3~37. Z7 5~55.27 5¢00.33 ~005.00 5500.09 ~072,~2 ~31.92 5530.90 ~141.1~ 407~.1~ 5700.33 ~20~.~5 5530,DD ~277.~5 ~23~.~5 5~30.PD 0,33 ~16.12 $345.1~ 0,03 $4~5.50 g41~.5~ O.OO ~555.15 O.O~ ~524.33 ~533.~5 0.90 $6~4.70 ~523.70 O.DO ~764.75 ~5J3.75 0.~ ~834.9~ O.O~ 5045.39 ~7~.39 3.33 5115.32 0.03 51B3.9) 5!ig.~ O.PO 5253.3~ 0.03 5321.~0 5255.~0 0.33 53~9.10 531~.20 0.33 5455.35 53~.3~ 3.03 55~5.~7 5515.97 O.O0 5552.55 ~53!.55 O.OO 571~.73 5647.7~ 6O0 $13 6!0 6~0 653 733 713 7ID 733 7¢3 753 750 770 733 23J~,S~ V=PTI-AL 30 3_~.G P--Vl~TlDq AZ!qJfq S ~" l'lgN St¢-'~lTf 3:$ ~41'~ 2r. 3 qlq F~iT C,~3/!0D 4.9 5d `4 5.9 ~+5 =_ P~'~3.20 3.~3 ~ 39 N 53 ~1 ~04.47 -- 4~ ZO `4 53 ~7 - 13~0.5Z 3.23 ~9 :0 N 50 5J ~ 145c ~O ~ 52 48 33 N ..~P 33 ~ _)531.~5 D.7~ 4~ ~ N 53 1~ ~_ '6)6.59 }.31 ~ 52 N 53 3 _ 2591.0~ 2757.35 'O.2J 4S 34 ~ ~') 55 - Z332.4A ~S i4 ~ ~9 55 : 2937.23 3.27 ~7 55 ~.l ~,9 +9 - ~055.17 3.25 47 53 '1 ~9 31 E 3i30.23 3.27 47 17 '~ ~) 2! : ~277.60 i7 4 ~] ~) 15 f {353.~9 0.45 47 1 ~J ~ 7 : 342~.07 4~ 50 `4 ~) 11 : ~4'9T ~ _ ~ .~! 3.59 4,5 34 N ~') 1! 35b~.97 D.23 46 15 '1 ~ 15 2 B542.40 3.23 45 .,7 N *~ P~ °'~5~ ~3 ~ 4~ .1 '4 ~ 17 = ~331.5~ 3.25 45 29 '4 ~) ~ = ~072.74 9.15 45 13 N ~5 31 =. ~215.34 3.32 4~ 4 N ~5 ~3 = ~27.64 3.51 ~o 33 `4 4) 2Z_ : ~+532.03 1.0~ 47 3 N 52 2~ - ~5~5,~1 1.~7 ~,3 13 q 5~ 53 2_ ~773.6) ]. )2 ~,B +9 `4 53 17 ~7)5,53 3.54 45 53 'J 5~ 35 d ~973.52 1.49 43 51 ~ '53 39 : 5323.51 !.7~ 4~_, 7 '~ ~i ~_ = 5'])g. 3~ ~_. =lET 14~2.1 1~)9.5 153~,5 !5B5.5 1533.~ !SJl.) 1730.~ 1775.7 1~27.$ 1375.2 1~23.10 1~F!.25 231'~.Z~ 2)o7.13 2115.13 ~1~2 ~7 ~ ~ m 2~10.75 225B.SB 2BOb.14 2353.4B ZqO3.31 1~47.37 2~94.31 25~0.55 2587.12 2533.75 2583.54 2727.~5 277,./2 2~22.Z2 2~59.,33 2~17.40 2953.5q 3393.20 3353.36 3!42.5~ 31~5.36 3!25.73 3253.37 JL~R CIJT~ CDJRnIqaTES,., q]:~TT.._. D=D~RTURE E'~ST/N=ST DIST. ~Z!'4UTH ~:~T '=fsi '3=3 q 1695.55 6 2223.24 q 17~7.~5_ 2304.50 N 1 ? 15 · $ 5 ~ 1675.10 6 2~5~.22 N 19=3. !5 = 2531. 25 '4 i')9!.,5'3 t ,1505. 51 q 2049.2) E Z5~Z.IO `4 2105.)5 : :757. 35 "I _Pl=g.~=.. ~ =.. 2S3~... ~7 '4 2221.70 227{.73 = 2~31.53 Z335.~7 5 395b.1'¢ 2391.S,-} 7 3L39.24 ~4~7, J~ ~ 320~. 35 2503. ~0 ~ 3277.52 255~.-7 5 3351.31 1.51~.75 5 3~24.0) 2573.il 5 3~7.1~ 2725.1~ = 3570.00 2730.0~ ~ 354!.44 283g.75 E 371i.50 2943.97 2 3B53.37 2J9~.i3 ~ 3)33.95 305Z.~ ~ ~301.53 3150.6~ ~ ~1~.27 3Zl~.lZ f ~215.~3 3257.32 ~ 42~6.5~ 3320.51 F ~357.J7 `4 3374..~+3 = 4~Z~.77 q 342~.00 = 45'22.13 N 3484.5~ - 4574.~I `4 3590.53 f ~72D.75 N 3559.53 = ~795.53 N 3721.32 ~ 4~7.3.S4 N 3783,37 q ~245.75 ~ 5023.51 `4 341t. !7 31-1 KJOaTJK N]~TH K~LLY 5JSqiN3 ELTVAT[]N: :~GIN~: SALAZAq 3 71.00 FT "~F':-~D"'L.~TED V~LJ=5 -'JR :VE'4 TRUE V=qTi'~L 8300.33 57~5.~4 5715.a~ 8130.33 8330.03 5002.5~ 593!.55 8530.0D 5077. 1Z 5335.12 8300.33 5131.~6 503J.75 8500.00 522~.3! 5!55.31 8700.00 6~. ~5 ~22~.~5 8~0.00 5372. J3 8~03.P~ 5~%5. B"~ 5374.99 9300.33 5519.D5 9030.03 55~1.C0 C]JPS~ V:~TICAL 03GL_=G g:V!1l'lDq aZl'qJFH 5-'CTIDN SEVERITY D--S qlN D=3 '~Iq ==~T D:-/IOO 5,3 q "~:~ 5 ' 375~.1~ 3.3~ l.l~ 1.5 2 1.5~ P.7~ 0.55 ~ 2~ ~ m 0 · 0 0 3 R:'TAY3ULAR CD 32')5. 3343. 3359. 3372. ?3~i · 33~. 3'~31. 7.5~. = 5165. 3.7'~ E 5233. 5.17 = DSS").iZ 0.55 2 5~l~.D1 5.59 ~ 557~.35 2.3~ r: 5531.S7 ,{,33 ': 5547.56 6.~5 ~ 5705.25 w. O5 = 576~. )4 D~DARTtJq~ ~ZIWUTq DE3 u!N N 5D 21 =_ q 50 ,51 q 51 13 _ 'q 5i 30 ,- q 52 13 _ q 51 35 q 52 57 q 53 ! 9 ': 4 53 39 ~: "4 53 ~+5 'E_ 31-1 N]~TH 5LO°E,~L~S~a 2~ ]"~OUT~ Ti DN D~ITE: 1!-F=~-35 .-')aT: 3,~ SJ~'v'~-Y: 2~--J~1-'-~5 ~,;~LLY 3U3'ii'15 ELEVATIDN: Ii .OO FT TRU~ ME&SURSD V:RTI-~L 0.03 0.30 1000.93 2030.33 1791.22 3000.90 Z~35.75 4330.33 307~.51 5330.33 3735.74 6900.30 7300.03 5115.3Z 8030.03 5785.4~ ~300.00 551~.35 9030.30 $5gI.00 SJ~-S:A -3JRSS V~qT!'~ D:VZATI]~ AZI"JTq ~l,Z.~3 20 1723.22 47 35 ~36~.75 50 33J7.51 ~345.1Z 45 571 5. ~ ~6 FSET O.OO 126.33 597.90 1~52.26 222~.20 371~.56 ~4Z~.64 5165.38 ~753.14 5770.0~ F=.ET 3= S~V:RITY ?~]qTqZSS:JT5 =AST 0:3Z103 =]ET 3.00 0.03 N 2.2~ 33.59 ~ ~. ~.!6 ~56.12 '~ llO~. 'D.l~ Z~O0.51 N 3.51 2~.93 ~ 337~. ~.0~ 32~6.32 '~ 3977. ~.OD 3~15.7~ ~ OZ'~AT:-5 "]Ri~, ~.. /~ST DIST. ~ZI"IUTH 5732.53 '~ 53 46 [ 3i-1 C~PJIaTI]N DarE: 11-==3-R5 D~TE 3= SJ~VEY: 2&-J~q-35 <5LLY BUS~IN) 5LEVaTI3N: =NGiN=~: S~caZ~R 10T=q'Pi2t'~T--O VaudE$ ='DR :V=N 100 =:=T O= 3'JB-S=~ D:~TH TRU= ~EASURE3 ViRTI'-AL V=RT!~AL 3EOTM JZPTfl Pi=TH 0.03 O.}J -71.30 71.00 71.30 9.00 171.33 l?l. JO 133.00 ]71.33 271.33 203.00 371.01 371.30 300.00 %71.10 +71.,33 403.30 571.59 571.00 ..=JJ.J9 573.12 6FI.JO 5J3.00 775.75 771.,35 700.00 ~3.1~ 871.0] 433.03 9B5.31 971.00 13)3.¢2 1071.30 1033.,33 123~.21 1171.J0 llO).JO 1317.50 1271.30 1203.03 1~35.83 1371.30 l~J].30 1558.7~ 1471.00 1400.00 1557.82 1571.39 1503.00 1324.29 1671.J0 150J.OJ 1970.09 17ll. O0 17OJ.'JJ 2119.07 1871.30 2!73.75 1971.00 i~JJ.03 2~25.35 2071.00 ZJOJ.OJ 2353.59 2171.30 ZlO'J.O0 27~0.12 2271.00 1230.30 2~97.~5 2371.00 ~30J.JO 3355.7~ 2~71.00 2~03.00 3213.4~ 2371.00 2503.00 3373.~) ~571.00 263J.00 35!5.71 2771.00 Z7J].JJ 35~0.41 2871.00 2~]3.33 C~J~S~ V:RTI-&L 3~Vl~Tl]q AZIMJTq S=CTIDN S~VmRITY ~-5 4IN OcS '~I~ F2ET DES/IOJ 0 3 N O ] E 3.30 ].00 0 3 S Z5 25 W -3.37 1.47 0 19 'J '~ 3 ~ 3.18 3.~9 0 l= ~ ~I ~3 ~ 0.77 3.33 0 53 N ~2 31 ~ 1.qI 3.75 ~ t~ N ~ 9 : 5.$~ 5.75 3 6 W 4~ 31 : 1~.{0 3.53 !0 $7 ~ ~5 3~ J~ 33.17 3.43 14 57 q a5 g! -_ 55.97 3.53 lfl ]3 N ~3 ¢~ = 35.93 3.25 2J 33 'J ~i 45 ~ 121.57 1.'~5 22 53 "~ ~9 51 - 15!.0i $.31 Z5 55 ~ 4~ ~ = ~37 66 2 ~ . , : ~i.~0 ~.qO 33 3~ N ~7 '5 =. 3~.10 2.03 37 Z~ 'q ~ 39 : 393.~7 2.67 40 54 ~ ~ 35 _ ~77.03 2.73 44 ~ 'J ~ 42 : 559.~3 3.21 4{ ig N ~) 23 - 756.!7 1.07 53 13 q ~) 23 : 11~1.00 3.40 50 32 N ~9 31 - 1251.27 3.55 50 3~ N z~ ~I = 1393.1£ C.23 52 $9 N 53 3 - 1535.44 3.32 50 35 N 49 5g ~ 1627.B~ :~ 4 'q 5~ ~3 : 17+3.47 ~. 37 ~) 32 N 50 Sl 1967.17 3.32 4~ 24 ~ 51 i~ ~ I~5:.25 3.73 4) sO 'q 51 ~. : '!31.71 3.27 ~:~ 35 N 53 -~7 ~- .... ;)1~·._~7 0.31 4~ ~2 N ~3 4~ = 2337.13 J. 4~ 1 'J :'3 53 :_ 1~53.3~ '3.5~ 4~ 52 'J :3 25 : Z557.,]6 3.79 ~ 5Z N J] } ~. iSSZ.2Z J.Z3 )755.47 ~$ !~ ~ w~ 55 ~ 2909.42 3.25 ~,3 ~ N ~ 4~ - 3021.07 47 37 q ~2 33 : 3131.54 3.25 3~33.9F 2971.00 2003.00 3)3~.~0 3071.J0 5303.00 ~1%2.)~ 3171.00 3103.0) 4296.23 3271.30 3200.00 ~530.19 3471.30 4732.02 3571.33 3533.0J 4992.~] 3571.30 5052.75 3771.J0 5231.77 ~871.J0 71.03 4:'TANS'JL~ *JJRJiN~T~3 d]qli. N]qT~/S]JTq E~3T/W:ST DIST. ~:T =!~T =:UT ,_ O.O0 '~ 3.30 3.Jx S n ~7 W 9.11 S 0.~3 ~ 3.34 '3.15 q 0.~7 3.~5 '~ ~.23 ~ 5.50 11.$3 q I1.~ ~ 1(,.32 2~.73 ',1 2~.~3 ~ 33.22 ~ 9q '.J aO.Sg : 55.20 80.55 q 31.31 E 121. 51 i05.25 N 121.{4 E 161.32 135.50 q 157.39 = 207.~3 171.25 N 197.55 i ~51.53 213.1~ ~ 24+.£2 ~ 32~.15 250.72 N 2~7.49 5 393.57 314.52 N 355.30 E ~77.14 375.01 N ~2B.35 E 569. ~7 51d.~ N 5~!.37 ~ 391.77 N 573.73 56~.97 N 769.3t 743.14 N 861.70 ~ I161.I5 325.53 N 952.95 ~ I261.~4 905.17 N 1046.J1 ~ 1333.2~ 3~3.63 q I139.$~ ! 1303.33 136~.32 N 1232.99 - I$2F.32 1140.14 q 1323.77 E 174~.5D 1215.36 N 1417.61 ~ 1357.Z3 I'$3.~4 '4 150).32 ~ 13~5.27 135Z.~5 q 1600.34 e 2101.76 1635.52 q 1591.71 E 2Z13.~1 1511.25 q 1782.37 ~ 2337.20 1555.77 9 1)55.37 ~ 2357.37 1733.~2 q 20~).~3 d 25~2.2~ 1~7~.3~ "~ ~223.3~ : 2933.~3 I)~.54 '4 ~303.73 $ 3021.03 &ZZMUTH =T 31-1 KJP~R3{ ;3~PJT~Ti3~ OAT:: ll-==B-g6 ~]~ D~T: jF SJqV~Y: <:LLY 3U3qiH:3 :qjl~=Eq: 5 71.00 FT TqU' SJ~-S:& qE~SURE3 V:RTZS~L V-qTZ-~L 5349.B~ 3971.00 3903.00 5¢97.1~ $071.~0 ~O0).OO 55~3.7~ +171.30 ~103.90 5789.~ $271.00 5~34.B5 ~37i.00 ~303.00 5079.15 $471.00 5g22.73 %571.30 $530.00 6356.95 %671.]0 6651.37 %~71.00 5793.58 %971.39 6)35.55 5071.00 7381.13 5171.00 3103.09 7!~5.9~ 3271.30 7372.73 5371.00 330P.00 7523.77 5~71.3J 7575.8~ 5571.03 ~50].00 ?~18.0~ 3671.}0 5593.30 7J77.52 3771.00 5733.00 8120.gi ~571.39 5~03.0J 8!57.53 5971.30 5RO3.OO 3391.3] 5071.30 3333.30 3525.7! 5171.30 5133.30 $550.45 5271.00 5290.00 37~7.$~ 5371.30 333].00 3934.3~ 5471.00 5~j3.OO COJPS5 V:RTISAL 9OGLES 3=VI~TZOq AZI~JTq 5E'rION S:V:RiTY ~::5 4Tq ]:o ,Iq FFrT OES/lO] ,7 £1 q '~9 22 = 32<+3.73 3.22 +7 5 ,~ c~ !5 { 3]~,_~.~3 0.44 47 3 '4 ~9 9 E ~436,13 9.2~ 45 35 N 4~ 11 : 3552.62 3.2~ g5 12 N ~9 15 = 3557.53 0.17 ~5 5~ N 4~ 15 : 3771.60 45 ~7 q ~ J3 =_ ]~7~.62 3.1Z 45 +2 q 4~ 22 _ 3~77.28 3.23 45 iS ~4 ~9 3 ~'37~.30 3.13 45 Il N ~ ~3 : ~!89.74 3.43 45 27 q $:~ 17 E :~131.96 0.41 ~5 i9 '~ 51 43 ~ ~5~1.99 !.35 *T 37 q ~2 4~ ~ -733.37 !.27 ¢¢ 52 q ~5 53 : ~927.63 1.45 a~ +4 N 5~ Pl = 50~1 3~ ) 37 &4 !3 N 7! 15 : 5245.92 5332.93 2.95 5411.42 i.~I 5~5 72 5561.2t 1.21 533~.67 J.2~ 5716.07 S3'JTH E-~ ST/~-:ST DIST. T FEET ='2iT 2551. 21,5! · 2231. 2301. 2359. ~571 · 2537. "104 :. 277! · 233~. 2~05. i~Tj. 3]40. 310~. 3175. 32?6. 32~. 332?. 74 'I 33-+3.2~ E 43~.22 76 q 353~.4D ~ 35 I 3574.'~7 : 23 si 3753.23 ~ 4~17.,54 84 q 3{55.3~ E 534i. 3S ~7 'q 3~52.30 : 51¢'].1~ 54 q 4057.12 ~ 52~7.15 3353. 3371. 3353. 3391. 3~11. ~$17. 75 N 4147.52 : 5333."]1 25 N 4i35.29 E 5g13.22 22 q 4323.55 95 q 4413.45 = 5555.32 %~ N 4505.52 : ~5~5.15 13 q 45~9.52 E 5725.37 ~4~ ~ 4664.40 = 57~~c.5~ '~ZlqdT~ q 51 2 '4 51 57 E q 52 27 ',~ 53 26 ',~ 53 '.5 - 3Z -I KJPARJq N3RTH SL,3PE,~LASK~ ]~T: IF SUqVEY: <%LLY ~USq~NG ELEVATION: ?l. DO FT T3P TOP ~-3T3 K~ARd~ C £NT:qPOL~T:3 V~LJ~S =3R 3:'L34 K~ ~b23.30 255~,$0 52a7.05 5277.5~ b315.74 5391.05 545q.79 65~1.00 SJ3-5~ 5;45.7~ 5333.7~ 'E .SS~TZ3N "UTi 3i-1 KJP~1RJ< N3qTH SL3 ~ E, ,~L-~S~< & O~T~ 3= SJ~EY: 2A-J~N-~5 <ELLY 3USHI',IS EL~V6TIDN: 71.OJ =T T '3 P TOP KUP~RJ~ ~ ~723.30 5Z~+7,']5 5175,35 5277. S) 52'32. 5} 531~.7~ 5391,36 5320.)5 5459.79 55~3. 79 55~1. 30 5~73.33 S R-_'CT 33 JRF l'H/ ~-E S3UTq 9,~ l.l:~ O. 3' 5 FINAL 9933.03 JEL_ L3S~Ti]q VEqTIS~L 5541.00 VZRTi'~L 5479.30 57t2.53 ~ZlqJTq SCHLUMBEROER 0 ~ RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL FIELD KUPARUK COUNTRY USA RUN TWO DATE LOOOEO REFERENCE 0000712S9 (345' FSL, 179' FWL, S31, T13N, R9E) HORIZONTAL PROJECTION /~:IR?H 6000 SO00 4000 3000 2000 1000 - 1000 sotn'H -2000 WEST REF 0000'7!2S9 SCALE = 1/I000 IN/FT -~'000 - 1000 0 1000 gO00 3000 4000 SO00 6000 EI::~T WELL 3I-1 (345' FSL, 179' EWL, S31, T13N, R9E) VERTICAL PROJECTION g~O. SO. n i- n t- m II PROJECTION ON VERTICAL PLANE SO. - 230. SCALEO IN VERTICRL DEPTHS HORIZ SCALE = 1/1000 IN/FT · · · l~uggeeted form to be i.~etted ~n each "Active" ~ell [o~der to ehec~ io~ timely compliance with out tegu~ntion~, ' ~~-~ ~utm · ' Completion Report t/el! rectionn! Survey Drill 8tern l~e~t Eeport~ Production ~e~t Report~ Log Run Digitized Data ARCO Alaska, Inc, Post Office ~ ~,d0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 02-11-86 TRA~NSMITTAL # 5561 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Open Hole/ Schl/ One * of each ~3J-11 5" DIL/SFL-GR 12-20-85 2" DIL/SFL-GR 12-21-85 5" Den/Neu (poro) 12-20-85 2" Den/Neu (poro) 12-21-85 5" Den/Neu (raw) 12-20-85 2" Den/Neu (raw) 12-21-85 Cyberlook 12-20-85 ~3I-1 5" DIL/SFL 01-07-86 ~.~- 2" DIL/SFL 01-07-86 5" Den/Neu (poro) 01-07-86 2" Den/Neu (poro) 01-07-86 5" Den/Neu (raw) 01-07-86 2" Den/Neu (raw) 01-07-86 Cyberlook 01-07-86 '~ 3F-15 5" DIL/SFL 12-31-85 ~ 2" DIL/SFL 12-31-85 5" Den/Neu (poro) 12-31-85 2" Den/Neu (poro) 12-31-85 5" Den/Neu (raw) 12-31-85 2" Den/Neu (raw) 12-31-85 Cyberlook 12-31-85 ~ 3A-16 5" DIL/SFL-GR 12-26-85 ~ 2" DIL/SFL-GR 12-26-85 5" Den/Neu-GR (poro) 12-26-85 2" Den/Neu-GR (poro) 12-26-85 5" Den/Neu-GR (raw) 12-26-85 2" Den/Neu-GR (raw) 12-26-85 Cyberlook 12-26-85 ~4 2H-5 5" DI L/SFL-GR 01-05-86 2" DIL/SFL-GR 01-05-86 5" Den/Neu (poro) 01-05-86 2" Den/Neu (poro) 01-05-86 5" Den/Neu (raw) 01-05-86 2" Den/Neu (raw) 01-05-86 Cyberlook 01-05-86 Receipt Acknowledged sta-t~ of Alaska*bi/se Rathmell*bl Drilling*bi Run #1 2000-78~6 Run ~1 2000-7664 Run #1 6900-7830 Run #1 6900-7638 Run #! 6900-7830 Run ~1 6900-7638 Run ~1 6900-7600 Run ~1 2600-8908 Run ~1 2600-8908 Run #1 4400-8883 Run ~1 4400-8883 Run #1 4400-8883 Run #i 4400-8883 Run #1 8600-8850 Run #1 1590-7536 Run #1 1590-7536 Run #1 4084-7511 R~n #1 6805-7511 Run #1 3297-7511 Run #1 3297-7511 Run ~1 3297-7400 Run #1 1890-9142 Run #1 1890-9142 Run ~1 4390-9117 Run #1 4390-9117 Run #1 4390-9117 Run ~1 4390-9117 Run #1 8390-9100 Run ~1 0100-8078 Run #1 0100-8078 Run #1 3500-8053 Run ~1 3500-8053 Run #1 3500-8053 Run #1 3500-8053 Run #1 7400-7800 Date: D&M*bl RECEIVED NSK Clerk*bt Vault* films r 2 1 1986; Al~sk'~ Oil & Gas Cons. Commis~ ARCO Alaska, Inc. Post Office B 00360 Anchorage, Ala~a'~a 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED F E B 1 1986 Alaska 0il & bus Cons. C[}~ii~nission Anchorage _.¢ STATE OF ALASKA - ALASKA O~..-AN D GAS CONSERVATION COI~.~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !7. Drilling well Y~ Workover operation [] 2 Name of operator 7. Permit No. ARCO Alaska, Inc. 85-307 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21514 344' FSL, 179' FWL, Sec.31, T13N, R9E, UM 4. Location of Well at surface 5. Elevation ~n feet (~ndicate KB, DF, etc.) 71 ' RKB 6. Lease Designation and Serial No. ADL 25521 ALK 2557 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 31-1 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of January , 19 86 12 Depth at end of month, footage drdled, fishing jobs, d~rectional drilling problems, spud date, remarks Spudded well (~ 0300 hrs, 12/30/85. Drld 12-1/4" hole to 4365'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8959'. Ran logs. Cont'd drlg 8-1/2" hole to 9030'TD (1/8/86). Ran, cmtd, & tstd 7" csg. PBTD = 8919'. Secured well & RR ~ 1930 hrs, 1/9/86. 13 Casing or I~ner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 104'. Cmtd w/274 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4346'. Cmtd w/1650 sx AS III & 320 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 9010'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/CR/SP/SFL f/8914' - 4340' FDC/CNL f/8914' - 8550', 7100' - 6800', 4600' - 4400' Cal f/8914' - 4340' GST f/3500' - 3050' and 3450' - 3100' (3 runs) 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Associ ate Engineer ]',~/'Sb _ . NOTE--Report/n this form is required for each calendar month, regardless of the status of operations, and must be fded m duplicate with the Alaska O~1 and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP3/MR35 Submit in duplicate ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 . Anchorage AK 99510-0360 /Transmitted herewith are the following items. return one signed copy of this transmittal. DATE 01-28-86 TRANSMITTAL # 5544 Please acknowledge receipt and Open Hole LIS Tapes plus Listings/ Schl/ One copy of each 3I-1 01-07-86 Run #1 3J-13 01-12-86 Run #1 2600.0-8904.0 REF#71147 1986.5-7688.5 REF#71166 Receipt Acknowledged: Sta~e of AK--initial tapes for these wells. ARCO Alalka. Inc. ~s · Subsidiary ol AtlantlcRIchfleldCompeny ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3I Pad (Wells I- 16) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L06 Enclosure RFCFIVFD JA i', J 2 1986 Alaska Oil & (~a~ ~sons. Uu~.mJssJ0~l Anchorage If ARCO Alaska, Inc. ~s a Subsidiary of AtlanhcR~chfieldCompany ,, RVEY ~ '~ I ~ NOTES _~ ~ Il. COORDINATES ARE A.S.R ZONE4. ;2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BASEDON ON-PAD CONTROL PER L.H.D. ~ ASSOC. 4. VERTICAL POSITIONS BASEDONTB~ 3[-4 PER LHD ~ ASSOC. 5. C.G. ELEVATIONS INTERPOLATED FRO~ S/C DWG. J CED- RlXX - ~O50 rev. ~ j LOCATED IN PROTRACTED SEC.SI,TI3 N~ R9E~ U. MER. LOCATED IN PROTR~TEDSEC.~TI3 N~ RSE~ U. MER. , ~- Y= 6,007,235.50 LAT. 70°~5'5~.0592'' 9- Y= 6,007,Z2Z.00 LAT. 70°25'50.4432" X= 508,056,44 LONG, Z49°56'03.596'' X= 507,867.gZ LONG. ~49°56' 09, ~34'' ~79' FNL, 345' FSL 0G. 33.6', PAD 39.9' ~80' FSL, Z0' FEL 0G. 35.0', PAD 39.9' ~- Y= 6,007,269.06 LAT. 70°25'5~.8978'' Z0- Y= 6,007,Z04.59 LAT, 70°25'50.282~'' X= 508,037.66 LONG. ~49°56'04.Z48'' X= 507,849.~Z LONG. ~49°56'09.686" Z60' F~L, 3~8' FSL 0G. 33.7', PAD 39,9' ~64' FSL, 29' FEL 0G. 35.0, PAD 40.0 3- Y= 6,007,252.70 LAT. 70°25'5~,7370'' Z~- Y= 6,007,088.~6 LAT. 70°25'50.~206'' X= 508,0~8.80 LONG, Z49°56'04.702'' X= 507,830.~3 LONG. Z49°56'Z0,240'' ~4~' FNL, 3~2' FSL 0G. 33.7', PAD 40.0' Z47' FSL, 48' FEL 0G. 35.0, PAD 40.~ 4- Y= 6,007,~36.~3 LAT. 70°~5'5~.575~'' Z2- Y= 6,007,07Z.76 LAT. 70°25'49,9595" j X= 507,999.99 LONG. Z49°56'05.~55 X= 507,8ZZ.32 LONG. Z49°56'Z0.796" ~22' FNL, ~95' FSL 0G. 33.8', PAD 40,0' Z3~' FSL, 66' FEL 0G. 35,0, PAD 5- Y= 6,007,2~9.8~ LAT, 70°25'5~.4Z39'' ~3- Y= 6,007,055,32 LAT, 70°25'49.798~" X= 507,98~.Z6 LONG. Z49°56'05.808" X= 507,79~.36 LONG, Z49°56'~Z.353'' ~04' FNL, ~79' FSL 0G. 33.9', PAD 40.0' ZZS' FSL, 85' FEL 0G. 35,0', PAD 6- Y= 6,007,203.20 LAT. 70°25'5~.2507" Z4- Y= 6,007,038.~ LAT. 70°~5'49.6359" X= 507,962,~ LONG. ~49°56'06.367'' X= 507,773.63 LONG, Z49°56'ZZ.903'' , 85' FWL, ~62' FSL 0G. 34.0', PAD 39.9' 98' FSL, ~04' FEL 0G. 35.0, PAD i Ii i i II ! 7- Y= 6,007,~86.78 LAT. 70°25 5~.0895 ZS- Y= 6,007,022.42 LAT, 70°25 49.4749 J ! i I ~ X= 507,943.27 LONG. Z49°56 06,920" X= 507,754,83 LONG. Z49°56 ~2.455" j j 66' FNL, 246' FSL OG, 34~2', PAD 39.8" 82' FSL, ~23' FEL OG. 35.0', PAD 40.2' j ~, 8- Y= 6,007,~70.37 LAT. 70°25'50.9282" Z6- Y= 6,007,006.02 LAT. 70°25'49.3Z37'' X= 507,924.40 LONG. ~49~56'07.475'' X= 507,736~04 LONG. Z49°56'Z3.007" J 47' FNL, 230' FSL 0~. 34.5', PAD 39.8' 65' FSL, Z42' FEL OG. 35.0', PAD 40.2' II ~ P~DYIFIPAT~ ~F SURVEYOR HEREBY CERTIFY THAT t AM ~ROPERLY ', SURVEYING )N THE STATE OF ALASKA ~O THAT ~ ~ ~m [ I ~H~T ~LL DIMENS IONS AND OTHER DETAILS ~ ~ '~ ~ ~ :. -' v ~ ARCO Alaska, Inc. -'~ . ~.~ , ~ $gRVE, ED FOR ~ .... ~ A;~' ~ ~ Kuparuk Project ~ - , D ' ' ~ "; ~ ( * ~ ~fl~. ~,~ ~ ~e AS-BUILT lOCATlON~ask~ - · . .... t_:~.,;~., . I .................... IlDWG' NO. NSK e5 - 3e Ai]chorag8 ~1' '~ :,ONA ~SArr't,c Boulevard, Suite 201, Anchorage, Alaska 99503 IIs~L= AS SHOWN I /IJOB ~ _ ~ ' I Il [ I I I MEMORANr UM TH RU: FROM: State of ALASKA OIL A~-,-~ GAS CONSERVATION COI-~-IISSloN C. V~~ter ton Cha~ ,, Lonnie C. Smith</' ~ Commissioner Edgar W. Sipple, Jr.~~<'' Petroleum Inspector AlaSKa DATE: January 7, 1986 FI LE NO.: TELEPHONE NO.: D, [WS, 1 SUBJECT: BOPE Test ARCO ' s KRU 3 I- 1 Permit No. 85-307 Kuparuk River Field Wednesday, January 1 1986: I traveled this date from ARCO's L3-24 ~0 ARC'O's KUparuk 3I-i t-0-Parker Rig 141, to witness a BOPE test. The drilling contractor was in the process of Nippiing up. Thursday, January 2, 1986: The BOPE test commenced at 2:30 AM and was concluded at 3:40 ~.{. There were no failures. I filled out the A.O.G.C.C. BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 3I-t, Parker Rig 141. Attachment '02-001 A (Rev 10-84) STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COPR~ISSION B.O.P.E. Inspection Report Inspector ~, ~r ~f , ~'/',~/~/~F~_ Operat6r Af'~ o ~(~l~r~ ~ Location: Sec 3/ Drilling Contractor Representative ~,~ Permit # ~$- 3.7 Casing Set @ ~3~ fto ~g~ resentative ~. Location, General ~Well Sign~(. ACCUMULATOR SYSTEM General Housekeeping 0~ Rig ~ _ Full Charge Pressure 3~o psig Reserve Pit ~ ~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE° Stack Pipe Rams Blind Ra s~ cfo~Jn~ Check Valve Test Pressure 3,~oo 3~oo Pressure After Closure /~Tg psig /f 7~'- Pump incr. clos. pres. 200 psig ~., min~~ec. ~ min~ sec° Full Cha~e Pre.re Attained: N2~~/ ~L$~/ LZO~.,(~Z~ psig - Controls: Master D ~ ~at~O ~'~A ~'(~ Remote ~ Blinds ~witch cover ~ Kelly and Floor Safety Valves Upper Kelly ~~st Pressur~ .~~O Lower Kell~ o k~est Pressure ~.~0 Ball Type ~ ~est Pressure ~foO Inside BOP ~ st Pressure ~~ Choke Manifold o~Test Pressure ~~ e No. flanges~ Adjustable Chokes /-~ -- ically operated choke ~ ~ ~- ~~ Test Results: Failures ---- O "--------- Test TJ~ne / hrs. of failed equipment to-be made within g0//~ days and Inspector/ Repair Replacement or Commission office notified. Remarks: Di~ ~ :but±o~ ori~' - AO&GCC cc - Operator cc o- Supervisor ' ' ' // d December 23, 1985 Mr. J. B. Kewin Regional Drilling Engineer A~RCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3I-1 ARCO Alaska, Inc. Permit No. 85-307 Sur. Loc. 344'.FSL, 179'FWL, Sec. 31, T13N, R9E, UM. Btmhole Loc. l185'FNL, 631'FEL, Sec. 31, T13N, RgE, UMw. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not inden~nify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, t,~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman of A!sska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office [ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 18, 1985 Mr. C. V. Chatterton Commi s s ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3I-1 Permit to Drill Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3I-1, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wel lbore A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on December 25, 1985. If you have any questions, please call me 263-4970. Sincerely, Regional Drilling Engineer JBK/tw PD2/L11 Enclosures ARCO Alaska, Inc. ~s a Subsidiary of AtlantlcR~chfieldCompany la Type of work. ~- STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.005 s..v,c. [] SINGLE ZONE [~]( 9. Unit or lease name Kuparuk River Unit lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 344' FSL, 179' FWL, Sec.31, T13N, RgE, UM At top of proposed producing ~nterval 1360' FNL, 840' FEL, Sec.31, T13N, RgE, UM At total depth 1185' FNL, 631' FEL, Sec.31, T13N, RgE, UM 5 Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71' PAD 40' I ADL 25521 ALK 2557 Federai insurance Company 12. Bond mformat~on (see 20 AAC 25.025) Statewi de Surety and/or number #8088-26-27 Type 13. Distance and d~rectlon from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse redes 631' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8016'MD, 6525' TVD fe~t 2560 19. If devmted (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 400 feet. MAXIMUM HOLE ANGLE 48 o I (see 20 AAC 25.035 (c) (2) 10. Well number 31-1 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 3J-12well 8450' ~ TD 18. Approximate spud date feet 12/25/85 2735 3143 psig@__ 80°F Surface ps,g@ 6168~ft. TD (TVD) 21 SIZE Hole '24~ LI2-1/4,, !8-1/2" Casing 9-5/8" Weight 62.5# 36.0# 7" 26.0# CASING AND LINER Grade Coupling H-40 Wel J-55/HF-,ERW BIC] J-55/HF-.ERW BTC Proposed Casing, Liner and Cementing Program SETTING DEPTH Length M D TOP TV D 80' 32' 132' 4207' 32' 132' I I 8985' 31' I 31' I I M D BOTTOM TV D 4239' II 3321 ' 9016' I 6525 ' QUANTITY OF CEMENT (includestagedata) ±200 cf 1500 sx CS III & 320 sx Class "G" 400 sx Class "G" 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9016'MD (6525'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 BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2735 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 be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 31-1 will be 8450' away from 3J-12 at 6525'TVD. 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. (continued on following sheet) 23. I hereby c_~¢'fl~ that the foregoing ~s true a.nd correct to the best of my knowledge // SIGNED / CONDITIONS OF APPROVAL Samples required Mud log required []YEs []YES Perm'- n u~-be~~ Approva 85- 307_.--~ ,/I /-'-)1~ 23J 8 ~ ~r~ ~n-~nl (JFB) PD2/PDll ~ / / DATE Directional Survey required [~ES [-1NO IAPI 5o~29-21514 SEE COVER LETTER FOR OTHER REQUIREMENTS ¢,COMM I SS I ON ER by order of the Commission DATE December 23, 1985 Submit in triplicate PERMIT TO DRILL 31-1 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After thw workover rig has moved off location~ this well will be fracture stimulated. I -T/-ZON E--~-- ;T-XROE-T--.CNTR l~O0-m ._ i · I II KUPARUK RIVER UNIT 20" .DIVEJ: TER SCHEMATIC 8 DE SCR I PT I ON I. 16' C~CTOR. 2. TAhi,(O STARTER HEAD. 5. TANKO SAVER SUB. 4. TABOO LOWER QU]CK-C~CT ASSY. 5. TANKO UPPER Q~J)CK-C(~',I~CT ASSY. G. 20' 2000 PSI DRILLING SPOOL W/I O' C)UTLETS. = '7. I0' HCR BALL VALVES W/lO' J DIVERTER LIhESo VALVES OPEN AUTON~TICALLY UPON CLOSURE OF ANNULAR PREVENTER. 8. 20' 2000 PSI AhX~IJLAR PREVENTER. MAINTENANCE & OPERATION 4 kECEIVE I. UP~t~ INITIAL INSTALLATIONb CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AI~IULAR PREVENTER AM) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE AI',I'4ULAR PREVENTER I N THE EVENT THAT AN INFLUX OF' WELLBORE ' FLUIDS OR GAS IS DETECTED, IF NECESSARY, MAh~JALLY OVERRIDE AhD CLOSE APPROPR I ATE VALVE TO ACHIEVE DO~IN~It~) DIVERSION. DO NOT SHUT IN ~LL UNDER ANY CIRCUMSTANCES. 7 6 DIAGRAM #~ t~-5/8'~5000 PSI RSRRA ~OP STACK I. 16' - 2~ ~I T~ ST~TI~ 2. I1' - ~ ~I ~I~ ~ 4. 1~8' - ~ ~I PI~ 5. 1~8' - ~ ~I ~I~I~ ~ ~~ KI~ LI~ 6. 1~8' - ~ ~I ~ ~ W~I~ ~ ~ T~. 7. 1~8' - ~ ~I ~ ' ACOJVIdLATOR CAPACITY TEST 1. CHECK AhD FILL AC~TOR F~OIR TO F~ LEVEL WITH NYI~IC FLUID. 2. A~ THAT ACCU~TOR PRESSL~ IS 3000 PSI WITH 3. C~ TIt~o ThEN CLOSE ALL UNITS SI~TA~OUSLY ALL UNITS ARE CLOSED WITH O-~ING PL~ ~FF. 4. RE~ ON NADC REPORT, 'rl-E ACCEPTABLE LOAER LIMIT IS 45 SEOSN:~ CLOSING TI~ ~ 1200 PSI REMAINING 5 4 3 2 --] 13-5/8" BOP STAC~ TEST 1. FILL BGI:' STACK AhD CNCI<E MANIFCLD WITH ~IC 2. ~ ~T ~ L~ ~ ~ IN ~~ ~Y ~RA~. ~T ~T ~ IN ~ ~I~ ~I~ ~ ~ ~ IN L~ S~. LI~ V~VES ~~ TO B~ STA~ ~ 4. ~~~TO~~~~F~ ~O~N. ~ ~ ~~ T~~~~ ~ F~ :0 ~N. BL~ ~~ TO 0 ~I. 5.~ ~ P~~ ~ ~AL KJ~ ~ ~E .LI~ VALVES. ~ T~ PIPE ~ ~ ~ V~VES 6. TEST TO 2~ PSI ~~ ~)AS IN S~ 7. ~I~ TESTI~ ALL~~S, LI~S, ~ ~ES WITH A ~ PSI L~ ~ ~ PSI HI~. TEST AS IN S~ 4. ~ ~T ~~ ~T ~ ~ ~T TEST B~ PIPE R~ TO ~ ~I ~ ~ ~I. 9. ~ B~ PIPE ~, BA~ ~ ~I~ ~ I0. ~ ~I~ ~ ~ ~ST TO 2~ ~I ~ PSI. II. ~ ~I~ R~ A~ ~RI~ ~ST ~. ~ S~E '~IF~ ~ LI~S ~ ~L ~ ~~I~ ~UID. ~ ~L VALVES IN ~I~I~ P~ITI~. 12. TEST STRIPE VALVES, ~Y, ~Y ~S, ~I~ PI~ S~Y VALVE, ~ I~I~ B~ TO ~ PSI 3~ PSI. 13. RE~ TEST I~~TI~ ~ L~ ~ TEST F~, SI~, ~ S~ TO ~I~I~ ~I~. ~Y ~~~ ~I~LLY ~~ B~ ~Y, Alaska Oil & Gas Cor~s. bu,..,,,sslor, ,AnchoFage CHECK LIST FOR NEW WELL PERMITS J ~-/ Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2thr u8) (13 thru ~1)/ (22 thr}r/26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO 1. Is the permit fee attached ......................................... - - -~ ~_ . ~" 2. Is well to be located in a defined pool ... 3. Is well located proper distance from proper;;'ii~'iii'ii[[[i[[i[[[i 4. Is well located proper distance from other wells .................... ~=~ 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .... 7. Is operator the only affected party ..................... ~- 8. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed .e....e....®®.®...®...®®...®..®.... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ..... Are necessary diagrams of dtverter ~';;~'~i;~;';~~'i~i~i~ Does BOPE have sufficient pressure rating - Test'to ~OO~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable Additional requirements ...................... ~ ...................... REI~RKS ,/st- a;XzZ ~ Additional Remarks: O H 0 ~Geo 1 o g~,.. Engin~eering: i .rev:i i. 03/13/t~5 .... 6.0!'1 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ill I iii I II I I I ! I I III ! ;~ LiS ~Eqi=iC~TI]'~i LiSTiqS SE~IC~ N~E :E~IT DATE : 35t01/2~ SRISIN :0020 SD~TINJ~Ti]N ~ :O! ~R~dISJS TI2E : ~'OqMENTS :LIBR~TY .391 SN : aR~3 ~N : 31 -I =N : KUPARU< R'~S: 9=. T34~: 13q SEZT: 31 '~JNi: N. SLg~: ST~T: ~L~S~ ~TqY: JS1 qN=q C]~TENTS J~IT J~IT TYD~ 003 ODD 032 ODD OOO 0:90 000 TyPz '~TE I III DO0 DO0 DO0 3:90 300 gO0 DOg, SIZE 015 004 33! 005 203 SiZE 001 055 JOB NUq3ER AT &SC: 711~7 RUN ti, DATE LSSGE9:07-JA~-35 LO~: M. SG]EN '~Si>:G = I'YDE ;LJIJ : DENSITY : 9.90 L513 ?iSSOSITY = 3~.0 S FLJID L3SS : ~ATRZX S&NDSTJ~E .,..,- .,- .,- ~,- THIS ~T~ 5IT SZZ= RM qM '~T SHi;TED - ~T 3~EqL&fS T3 $959.0' : 3.TZD 3 52.0 9F : g.043 ~ 52.2 DF : 2.~53 3 52.0 OF : 1.73'~ ~ 141. OF :IELD oRINTS LV? 910.HO~ VS~IClC~Ti3X L!$TIN5 P~S= 3 ]&T~ ~V~T' AB.~ _E: ~90~.0' TO 4340.3 .... .,- ~]q~&Tl3~ DE~SrTY CO~NS~TcD LDS (FDN) '" ']HP~S~TEO ~UTR3N L3~ (FDN) ]~T~ &V~ILAB.E: 8879.0' TO ~550.0' D~T~ AV~IL&6_E: 7100.0 TO 5800.~ RAY iN ~ASiqS (3R ~NL) DE~T SF~J 3ZL ZL3 OIL IL~ 3IL SP DZL SR GR NP4I !$ 8726.0300 SFLJ 2. -~0.~3~3 ~R 76. I.~321 Dqq3 O. 49.0723 NC~. 1655. ~900.0000 SFLj 3. -~5.98~3 3R 36. !.~32! ORi] O. 41,3{7~ NCq. 1655. ~803.3J03 S~' J 3. 2.3599 DR~] O. 32,5560 ~C~. 2200, a70O.OOOO S=LJ 5. 2,~345 gq~] O. 25,759~ NCN_ 22~9, 2.~56 ]qq] O. -31.9393 5q 1!7. 73 55 55 ,lin ~570 Tl~ 1221 5~75 1~55 1221 5575 7051 7145 JJ58 9023 0395 5330 2~05 7148 5~75 5792 2145 2300 ILD NR~T 3R NR&T FCN. Gq NR~T FCN' NR~T FCqL ZLD Nq~T :S~. 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