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186-026
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-05 KUPARUK RIV UNIT 3N-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 3N-05 50-029-21537-00-00 186-026-0 W SPT 6040 1860260 1510 2606 2607 2608 2608 126 130 130 130 4YRTST P Sully Sullivan 11/28/2025 no issues 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-05 Inspection Date: Tubing OA Packer Depth 615 1830 1780 1775IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS251129164453 BBL Pumped:1 BBL Returned:0.8 Friday, January 16, 2026 Page 1 of 1 &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRW FOLFNOLQNVRURSHQDWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQW LVVDIH )URP 16.'+')LHOG6XSHUYLVRU 7R 5HJJ-DPHV% 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ :DOODFH&KULV' 2*& &F :HOO,QWHJULW\6SHFLDOLVW&3) &3) 6XEMHFW 1DQGIRUPVIURP 'DWH 6XQGD\$XJXVW $0 $WWDFKPHQWV LPDJHSQJ 0,7.581DQG6,7(676[OV[ Please see the attached 10-426 form for the shut in MITIA’s from 3N-03,04,05 and 10 that were conducted on 8-17-24. If you have any questions please let me know. Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .581 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: :HOO Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860160 Type Inj N Tubing 1050 1250 1275 1275 Type Test P Packer TVD 6146 BBL Pump 2.0 IA 400 2100 2010 1990 Interval 4 Test psi 1537 BBL Return 2.0 OA 100 110 105 105 5HVXOW 3 :HOO Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860170 Type Inj N Tubing 2000 2010 2010 2010 Type Test P Packer TVD 6157 BBL Pump 2.0 IA 120 2700 2610 2600 Interval 4 Test psi 1539 BBL Return 2.0 OA 100 100 100 100 5HVXOW 3 :HOO Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860260 Type Inj N Tubing 2060 2080 2080 2080 Type Test P Packer TVD 6041 BBL Pump 2.0 IA 320 2830 2770 2760 Interval 4 Test psi 1510 BBL Return 2.0 OA 60 60 60 60 5HVXOW 3 :HOO Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860720 Type Inj N Tubing 1860 1875 1875 1875 Type Test P Packer TVD 6303 BBL Pump 3.2 IA 210 2700 2580 2550 Interval 4 Test psi 1576 BBL Return 3.2 OA 35 45 40 40 5HVXOW 3 :HOO Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA 5HVXOW 7<3(,1-&RGHV 7<3(7(67&RGHV ,17(59$/&RGHV 5HVXOW&RGHV W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3N Pad Arend / Richwine 08/17/24 1RWHV 1RWHV 1 1 1 1RWHV 1 1RWHV 1RWHV 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2024-0817_MIT_KRU_3N-pad_4wells 9 9999 9 9 - 5HJJ 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2j( DATE: Monday,August 08,2016 P.I.Supervisor \ "1 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-05 FROM: Bob Noble KUPARUK RIV UNIT 3N-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.T — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-05 API Well Number 50-029-21537-00-00 Inspector Name: Bob Noble Permit Number: 186-026-0 Inspection Date: 8/1/2016 Insp Num: mitRCN160801172328 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-05 ;Type Inj W TVD 6040 , Tubing 2850 2850 - 2825 - 2860 -T PTD 1860260 Type Test SPT!Test psi 1510 IA 450 2000 . 1940 - 1940 Interval 4YRTST 'P/F ✓ OA 10 10 20 _ 20 Notes: SCAMED Monday,August 08,2016 Page 1 of 1 0 0 0C , � _;) 1 _ - - aur p x f0 Q t Wt9W O Q , y O te 'Q a a 0 h C0Nz0 ~ a Y c H >- D W J Z � � � OD .� ' Ja_n 0z o II!gp Q U Eh u j E O W QJ� - v .O "O ik 0 @ as Q 0 --1 W (0 (0 CO O a) E m Y J H U, U U a"' a O Y , IA Q F.- O y d N v1 = C C c0 J <L CD 0E }' c0 •i N Z a N M M Cl.) Q N Z Q O 0 'o E O T K u L L TD F 4-, U C C a in O 0 c0 WI J J J b o u `O > w w w ao •-+ F- W LLL L_ of O E -0 N O < -J _1 _1fl O N l Q Q Q C = 0) 0 Q Z Z Z_ u ° -0 0 u j �.._�-.�. LL LL LL N L cc y0-_ U i1 — u N -c O 4O O O au N E 0 b1 ra' Q y a+ � t. > > c d' a F- tli• O ' V F- Y -SG Q a L croOU > 'ter P W U U Yl O 1 0 N N V o 0 `�' Q c.> 3 � ID til ID cc U `'° w J a `P > M'' 0 b g G a0 ' c, TM 1-1.11 ed M C > a. £ J J W C C E0• D D D 111 < > >> E cici 1 O ci d Y Y U w7 u ti >D 0. N U Y Y 0 Ca ort M M T 0. xN 0 LLI :p r, a u > 2 V 0 0 o f6 cc uj V 6J N• Q Q 0 0 azo tm po O o N as o 0 0 Cr Nd> v r c T m co f0 M OD o N O o N N N N 0 F•••7 M O T L O O N N N v O O O O O N N a+ O Q _ CO C_ a u = LI) trl 01 E N f6 a E v > Y CO W " — Q N • r o +•• E y = n 0 0 2 E co a d Q N U M en C Z N `° .� . c c m C f. a a Q /r STATE OF ALASKA ALAIDA OIL AND GAS CONSERVATION COMSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate E Pull Tubing r Operations shutdow n r Performed: Suspend r Perforate r Other Stimulate Casing 9 r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Prod to WINJ. r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r _ 186-0260 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-029-21537-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 025521 KRU 3N-05 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 7601 feet Plugs(measured) None true vertical 6408 feet Junk(measured) None Effective Depth measured 7482 feet Packer(measured) 7106 true vertical 6318 feet (true vertical) 6041 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 115' 115' SURFACE 3727' 9 5/8 3764' 3599' PRODUCTION 7534' 7 7569' 6384' sCANNE,0 JAN :2 6 L017 RECEIVED Perforation depth: Measured depth: 7299-7314, 7324-7342, 7364-7392 True Vertical Depth: 6183-6194,6201-6215, 6231-6252 MAY 17 2016 / C Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7238 MD,6138 TVD Packers&SSSV(type,MD,and ND) TRDP=BAKER'FVL'@ 1792 MD and 1792 TVD PACKER=BAKER F PACKER @ 7106 MD and 6041 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 201 2691 1100 353 Subsequent to operation 0 0 3714 400 2826 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service F Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ F 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: 316-217 Contact Darrell Humphrey/Bob Christensen Email: n1139(C7conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature A Phone:659-7535 Date c.`Li. 1 tp vTL eJzl1I, Form 10-404 Revised 5/2015 4e 404Submit Original Only RBDMS Vv MAY 1 7 2016 • 3N-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/20/16 Convert well to Seawater Injection-open well return to service 04/30/16 (ISW) : STATE WITNESSED (CHUCK SCHEVE) MIT-IA(PASSED)TO 2000 PSI. • 4 `, KUP PROD • 3N-05 ConocoPhillips 414 Well Attributes Max Angle&MD TD Alaska,Inc. Pr • Wellbore API/UWI Field Name Wellbore Status nil 7) MD(ftKB) Act Btm(ftKB) , opree),41 500292153700 KUPARUK RIVER UNIT PROD 44.90 6,400.00 7,601.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 3N-05,3/14/2016 3:43:56 PM SSSV:NONE 110 12/11/2015 Last WO: 10/17/2015 38.49 2/22/1986 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..__._...... Last Tag:SLM 7,452.0 10/25/2015 Rev Reason:GLV C/O pproven 3/14/2016 HANGER;32.7- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 16 CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED .. - .. .,. 44-/102,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I. Grade Top Thread SURFACE 9 5/8 8.765 37.0 3,764.3 3,598.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)...Wt/Len(I. Grade Top Thread s PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J-55 BTC .A.A.,t-A.A.A./1/4".A.WsAAA L Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;38.0-115.0 TUBING-WO 2015 31/2 2.992 32.7 7,120.0 6.050.9 9.30 L-80 EUE 8rd UPPER COMPLETION GAS LIFT;2,505.7Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Tap Intl(") Item Des Corn (in) 32.7 32.7 0.06 HANGER Tubing hanger 3.500 4,509.6 4,150.8 42.50 OT Safety Baker Orbit valve 2.890 I Valve 4500 SURFACE;37.0-3,764.3- 7,097.8 6,034.6 42.84 XO Enlarging 3.5 EUE Box X 4.5 IBT pin 2.960 - 7,098.3 6,034.9 42.84 Locator Locater sub 2.960 GAS LIFT;4,039.8 E 7,099.0 6,035.5 42.83 SEAL ASSY Baker 80/40 seal assembly 21 ft 2.960 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2015- 31/2 2.992 7,106.1 7,327.2 6,203.9 9.30 L-80 EUE 8rd LOWER PACKER COMPLETION QT Safety Valve;4,509.6 A Completion Details Nominal ID - Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) 7,106.1 6,040.7 42.81 PACKER Baker F packer 5.380 - 7,109.4 6,043.1 42.79'SBE Seal bore ext.80-40 4.000 GAS LIFT;5,318.6 7,226.4 6,129.3 42.38 NIPPLE 3.5 X 2.812 X nipple,PXX PLUG PULLED 1025 15 2.812 7,239.2 6,138.7 42.35 Liner 5.5 X 14#J-55 W 6"wear soxs 5.000 7,282.9 1 6,171.0 42.24 Liner 5.5 X 149 J-55 W 6"wear soxs mule shoe 5.000 GAS LIFT;6,353.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) 7) Des Corn Run Date ID(in) 7,319.0 6,197.8 42.14 WHIPSTOCK 2 5/8"X 5 1/2"Baker Gen II WHIPSTOCK 2.2 DEG 12/31/2015 LEFT OF HIGHSIDE LOOKING OH WITH SLB GAS LIFT;7,042.0 F WPPT AT 7319'ftKB REFERENCING HALLIBURTON JEWELRY LOG DATED 27-OCT-15 Perforations&Slots SO Enlarging;7,097.8 Shot Locator;7,098.3 Dens Top(ND) Bim(ND) (shots f Top(ftKB) Bile(ftKB) (ftKB) (BOB) Zone Date t) Type Com PACKER;7,106.1, 7,299.0 7,314.0 6,183.0 6,194.1 A-3,3N-05 6/28/1987 8.0 RPERF 2 1/8"EnerJet;60 deg. SEAL ASSY;7,099.0 ph SBE;7,109.4 7,309.0 7,310.0 6,190.4 6,191.1 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ if 90 deg.ph xo Reducing(Tubing);7,128.8 7,324.0 7,342.0 6,201.5 6,214.8 A-2,3N-05 6/28/1987 8.0 RPERF 21/8"EnerJet;60 deg. ph 7,334.0 7,335.0 6,208.9 6,209.7 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph 7,337.0 7,342.0 6,211.1 6,214.8 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ 11'90 deg.ph 7,364.0 7,392.0 6,2312 6,252.0 A-1,3N-05 4/21/1986 4.0 IPERF 4"Csg Gun HJ II;90 NIPPLE;7,226.4 deg.phase Mandrel Inserts XO Enlarging(Tutting);7,238.2 St ati Liner;7,239.2 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 1 2,505.7 2,502.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 Liner;7,262.8-� 2 4,039.6 3,804.8 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 RPERF;7,309.0-7,310.0 3 5,318.6 4,748.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 (PERF;7,309.0-7,310.0 4 6,353.6 5,499.8 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 - - 5 7,042.0 5,993.8 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/4/2016 - Notes:General&Safety - • End Date Annotation SLOTS;7,322.0-9,649.0, 11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/17/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. L1-03 LINER;7,312.6-8.050.0 10/17/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. WHIPSTOCK;7,319.0 it RPERF;7,324.0-7,342.0- IPERF;7,334.0-7,335.0 (PERF;7,337.0-7,342.0- IPERF;7,364.0-7,392.0 PRODUCTION;35.0-7,589.1 • 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 04,2016 TO: Jim Regg 1SIC 5(i'511(0 P.I.Supervisor ( t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-05 FROM: Chuck Scheve KUPARUK RIV UNIT 3N-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .P— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-05 API Well Number 50-029-21537-00-00 Inspector Name: Chuck Scheve Permit Number: 186-026-0 Inspection Date: 4/30/2016 Insp Num: mitCS160502071227 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N os IType Inl w 'TVD 6040 ' 'Tubing 2750 2750- 2750. 1 2750 • PTD 1 1860260 Type Test SPT Test psi 1510 " IA 660 2000 • 1950 . 1940 • 7 Interval ;INITALP/F P y l OA 1 0 0 0 0 - Notes: Initial test post rig workover SCANNED SEP 2 7 2016 Wednesday,May 04,2016 Page 1 of 1 • • '\\\�//77 49 THE STATE Alaska Oil and Gas pi�44> "1�.-diva� Ofj\ As A Conservation Commission ,:0114=---7;-=4::- 333 West Seventh Avenue 'J7° GOVERNOR BILL WALKER Anchorage, Alaska 95001.1572 V ' 0.0, °" 1f;e' Fax: 907.276.7542 www.aogcc.alaska.gov Keith Herring CTD Engineer ConocoPhillips Alaska, Inc. riti r , , P.O. Box 100360 Sa1111 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3N-05 Permit to Drill Number: 186-026 Sundry Number: 316-217 Dear Mr. Herring: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,4.e-t54-. Cathy . Foerster Chair DATED this /3'clay of April, 2016. RBDMS 1'' APR 1 4 2016 • RECEIVED • STATE OF ALASKA APR 0 4 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION j7S fit 3 06 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Oil to WINJ ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc, Exploratory ❑ Development E% 186-026 • 3.Address: El6.API Number: Stratigraphic ❑ Service P.O. Box 100360 Anchorage,AK 99510-0360 50-029-21537-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO432D. KRU 3N-05 • 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): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7601' 6408' 7317' 6197' 3957 None None Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 115' 115' 1640 670 Surface 3727' 9-5/8" 3764' 3599' 3520 2220 Production 7534' 7" 7569' 6384' 4980 4320 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7299'-7314' 6183'-6194' 7324'-7342' 6201'-6215' 3.5"x 5.5" L-80/J-55 7327' 7364'-7392' 6231'-6252' Packers and SSSV Type: Packer-Baker F Packer Packers and SSSV MD(ft)and TVD(ft): 7106'MD/6041'TVD SSSV-Baker Orbit Valve 4510'MD/4151'TVD 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q 14.Estimated Date for 15.Well Status after proposed work: 4/19/2016 Commencing Operations: OIL ❑ WINJ 0 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. Contact Keith Herring @ 263-4321 Email Keith.E.Herrinq(a�cop.com Printed Name Keith Herring Title CTD Engineer ...—.._ .9/AA 9& SignaturePhone:263-4321 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \tiL,— 2\--t Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Testgma Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes'' No ❑ Spacing Exception Required? Yes ❑ No Rif. Subsequent Form Required: /0 4 a 4 RDDMS 'V V APR 1 4 2016 APPROVED BY Approved by: 0 ' COMMISSIONER THE COMMISSION Date: 1--,..-/3—.% O Form 10-403''evised 11/2015 pI oV f tASubmit Form and i valid for 12 mon hs fro to ate of approval. Attachments in Duplicate //TL 4/1211 b 1�/6 • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 APR 0 4 2016 April 4, 2016 AOGCC 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 for the Kuparuk Well 3N-05 (PTD# 186- 026). Prior to the arrival of the coiled tubing drilling rig, Nabors CDR2-AC, an application for sundry to convert the KRU 3N-05 well from injection to production was submitted on December 10, 2015. The well was placed on production to lower the bottom hole pressure to allow for CTD operations. Upon completion of the CTD laterals, completion reports were submitted designating the laterals as being placed on water injection. However, an application for sundry for the KRU 3N-05 parent wellbore was never submitted to return the well to water injection. Attached to this application are the following documents: — Application for Permit to Drill Document for CTD Laterals which includes Quarter Mile Injection Review — Spider Plot — Current parent wellbore schematic CTD final wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer (0"W. A q/c/i� • • Kuparuk CTD Laterals NABORS ALASKA 3N-05L1, L1-01, L1-02, & L1-03 `.I), CortocoPhilltpsApplication for Permit to Drill Document .RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AA C 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AA C 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 8 Attachment 1: Directional Plans for 3N-05L1, 3N-05L1-01, 3N-05L1-02, &3N-05L1-03 8 Attachment 2: Current Well Schematic for 3N-05 8 Attachment 3: Proposed Well Schematic for 3N-05L1, 3N-05L1-01,3N-05L1-02, &3N-05L1-03 8 Page 1 of 8 December 18, 2015 • • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3N-05L1, L1-01, L1-02, & L1-03. All laterals will be classified as"Service—WAG"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3N-05L1, L1-01, L1-02, & L1-03. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4300 psi. Using the maximum formation pressure in the area of 4577 psi in 3M-13 (i.e. 14.2 ppg EMW), the maximum potential surface pressure in 3N-05, assuming a gas gradient of 0.1 psi/ft, would be 3957 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3N-05 was measured to be 4041 psi (12.5 ppg EMW) on 11/09/2015. However the pressure is expected to decline to 11.5 ppg by the spud date. The maximum downhole pressure in the 3N- 05 vicinity is to the northwest in the 3M-13 producer at 4577 psi (14.2 ppg EMW) measured in November 2015. The lowest downhole pressure in the 3N-05 vicinity is to the north in the 3Q-22 producer at 2063 psi (6.4 ppg EMW) measure in February 2015. Due to the 3M-13 and 3Q-22 wells' being offset that high pressure is not expected during operations of drilling the 3N-05 laterals. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) None of the offset injection wells to 3N-05 have ever injected gas, so there is a low probability of encountering free gas while drilling the 3N-05 laterals. If significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems in the 3N-05 laterals will be shale instability at large fault crossings. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3N-05 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 8 December 18, 2015 • • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2%', 4.7#, L-80, ST-L slotted liner; 3N-05L1 10070' 11600' 6180' 6245' openhole anchored aluminum billet on top 2%', 4.7#, L-80, ST-L slotted liner; 3N-05L1-01 9925' 11585' 6174' 6252' openhole anchored aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 3N-05L1-02 7600' 11095' 6159' 6172' openhole anchored aluminum billet on top 3N-05L1-03 7314' 9160' 6127' 6172' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 38' 115' 0' 115' 1640 630 Surface 9-5/8" _ 36.0 J-55 BTC 37' 3764' 0' 3599' 3520 2020 Production 7" 26.0 J-55 BTC 35' 7569' 0' 6384' 4980 4330 Tubing 3-1/2" 9.3 L-80 EUE 8rd 33' 7239' 0' 6138' 10160 10530 Tubing Tail 5-1/2" 14.0 J-55 STC 7239' 7327' 6138' 6204' 4270 3120 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based PowerVis mud (9.5 ppg) — Drilling operations: Chloride-based FloVis mud (9.3 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The 3N-05 contains a downhole deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud Page 3 of 8 December 18, 2015 • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3N-05 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3N-05 Window(7319' MD, 6198' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.5ppg) 3706 psi 3706 psi Mud Hydrostatic (9.3 ppg) 2997 psi 2997 psi Annular friction (i.e. ECD, 0.080 psi/ft) 586 psi 0 psi Mud + ECD Combined 3583 psi 2997 psi (no choke pressure) (underbalanced (underbalanced -124 psi) -709 psi) Target BHP at Window(11.8 ppg) 3803 psi 3803 psi Choke Pressure Required to Maintain 220 psi 806 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is fora land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3N-05 is a Kuparuk A-sand injection well equipped with 3'/2"tubing and 5 '/2"big tail pipe completion. Four laterals will be drilled to the northwest of the parent well with the laterals targeting the A l,A2 and A3 sands. A thru-tubing whip-stock will be set pre-rig inside the 51/2"tail pipe at the planned kickoff point of 7319' MD to drill all four laterals. Page 4 of 8 December 18, 2015 • • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. The 3N-05L1 lateral will exit through the 5'/2"tail pipe and 7"casing at 7319' MD and TD at 11600' MD, targeting the A2 sand. It will be completed with 23/8"slotted liner from TD up to 10070' MD with an openhole anchored aluminum billet for kicking off the 3N-05L 1-01 lateral. The 3N-05L1-01 lateral will drill northwest to a TD of 11585' MD targeting the Al sand. It will be completed with 2%" slotted liner from TD up to 9925' MD with an openhole anchored aluminum billet for kicking off the 3N-05L 1-02 lateral. The 3N-05L1-02 lateral will drill northwest to a TD of 11095' MD targeting the A3 sand. It will be completed with 2%"slotted liner from TD up to 7600' MD with an openhole anchored aluminum billet for kicking off the 3N-05L1-03 lateral. The 3N-05L1-03 lateral will drill northwest to a TD of 9160' MD targeting the Al sand. It will be completed with 2%" slotted liner from TD up to 7314' MD with a deployment sleeve back into the 5 'h"tail pipe. Pre-CTD Work 1. RU Slickline: Dummy all gas lift valves and obtain an A-sand SBHP, drift a dummy whip-stock to TD. 2. RU E-line: Set Baker Hughes 31/4"x 5'/2"thru-tubing whip-stock at 7319' MD 3. Perform injection test 4. Pump degradable plug for temporary parent bore isolation 5. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16"BOPE,test. 2. 3N-05L1 Lateral(A2 sand northwest) a. Mill 2.80"window at 7319' MD. b. Drill 3"bi-center lateral to TD of 11600' MD. c. Run 2%" slotted liner with an openhole anchored aluminum billet from TD up to 10070' MD. 3. 3N-05L1-01 Lateral(Al sand northwest) a. Kick off of the openhole anchored aluminum billet at 10070' MD. b. Drill 3"bi-center lateral to TD of 11585' MD. c. Run 2%" slotted liner from TD up to 9925' MD. 4. 3N-05L1-02 Lateral(A3 sand northwest) a. Kick off of the openhole anchored aluminum billet at 9925' MD. b. Drill 3"bi-center lateral to TD of 11095' MD. c. Run 2%" slotted liner from TD up to 7600' MD. 5. 3N-05L1-03 Lateral(Al sand northwest) a. Kick off of the openhole anchored aluminum billet at 7600' MD. b. Drill 3"bi-center lateral to TD of 9160' MD. c. Run 2%" slotted liner from TD back into the 5 '/2"tail pipe at 7314' MD. 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Page 5 of 8 December 18, 2015 • • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. Post-Rig Work 1. Pull BPV. 2. Pre-produce for less than 30 days 3. Return to injection. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse Liner Running — The 3N-05 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 8 December 18, 2015 PTD Application:-3N-05L1, L1-01, L1-02 & L1-03. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name .Dista6Vz 3N 05L1 9863' 3N-05L1-01 9870' 3N-05L1-02 10355' 3N-05L1-03 12072' — Distance to Nearest Well within Pool Latet Na 'e`. bisfal ; etlr ` R 3N-05L1 3N-04 932' 3N-05L1-01 3N-04 1000' 3N-05L1-02 3N-04 993' 3N-05L1-03 3N-04 1556' 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There is one well within 1/4-mile of the 3N-05L1, L1-01, L1-02, and L1-03 laterals 3N-05 (mother bore) Injector • Classified as a "Normal Well" • The well is completed with 3.5" 9.3# L-80 tubing and 7" 26#J-55 production casing. • Packer located at 7106' MD which is located less than 200' from the top of the perforations. • A-sand perforations: A3: 7299' -7314' MD, A2: 7309' - 7342' MD, and Al: 7364' - 7392' MD • Well was recently worked over on 10-18-15, new tubing was run and a down hole deployment valve was installed. • Production casing was cemented with 300 sx of Class "G" cement. The proposed kick off point for the CTD sidetrack is in the A-sand perforations and should not compromise existing conformance. 3N-04(Injector), —932' away from 3N-05L1, L1-01, L1-02, & L1-03 lateral to the east • 3N-04 is currently injecting water into the Kuparuk A, C, and Unit B sand intervals. • Classified as a "Normal Well" • Well is completed with 2.875" 6.5# L-80 tubing and 7" 26#J-55 production casing. • Packers located at 7383' and 7439' MD the lowest most which is located less than 200' from the top of the perforations. • A, C, Unit B perforations: C4/Unit B: 7574' - 7584' MD, A3: 7612' -7622' MD, A2: 7625' -7632' MD, and Al: 7639' - 7645' MD • Production casing was cemented with 350 sx Class `G' and 175 sx PF 'C' Page 7 of 8 December 18, 2015 •• PTD Application:'"3N-05L1, L1-01, L1-02 & L1-03. 17. Attachments Attachment 1: Directional Plans for 3N-05L1, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03 Attachment 2: Current Well Schematic for 3N-05 Attachment 3: Proposed Well Schematic for 3N-05L1, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03 Page 8 of 8 December 18, 2015 • • • w �kiIW0 Immo ,fib 01 "mg, ,iffirspi_., ••• . it.. , . , :7111w,„in „ A .:.• ',meg . .::. „....-- . - --,--,7--- --,r, .-----17.4.,,,-'--- - :.:.' ..immika r: ,,,:„:4-0117' tAntimilFil :. :. ::_il 4 ,..1-,-itii := - = , - �ya. a � v w w, 11th ���� . 7454 ,5. 7 ,S. - - .. z <'''' x'`152 0 . 0 • O '1:;.,,,,;.,'ra {{ ari , ��e z7X- v u 1"_�_ J `. 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Last Tag:SLM 7,452.0 10/25/2015 Rev Reason:GLV C/O pproven 3/14/2016 HANGER;32.7- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread x...................u...i. CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED - Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.765 37.0 3,764.3 3596.8 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 ns..v-; .7�PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ibdt) Grade Top Connection CONDUCTOR;38.0-115.0- „ TUBING-WO 2015 3 1/2 2.992 32.7 7,120.0 6,050.9 9.30 L-80 EUE 8rd �.--y UPPER �{-:.�f � COMPLETION GAS LIFT;2,50s.7- i Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Ham Des Com (in) 327 32.7 0.06 HANGER Tubing hanger 3.500 4,509.6 4,150.8 42.50 OT Safety 'Baker Orbit valve 2.890 Valve 4500 SURFACE;37.0-3,784.3-,, 7,097.8 6,034.6- 42.84 XO Enlarging 3.5 EUE Box X4.5 BT pin 2.960 7,098.3 6,034.9 42.84 Locator Locater sub 2.960 GAS LIFT;4,039.8- , 7,099.0 6,035.5 42.83 SEAL ASSY Baker 80/40 seal assembly 21 ft 2.960 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TOD)(...Wt(lb/ft) Grade Top Connection - TUBING WO 2015- 31/2 2.992 7,106.1 7,327.2 6,203.9 9.30 L-80 EUE 8rd LOWER PACKER COMPLETION OT Safety Valve;4,5096 ,,,'.71.1e, Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,106.1' 6,040.7 42.81'PACKER Baker F packer 5.380 :. 7,109.4 6,043.1 42.79 SBE Seal bore ext.80-40 4.000 GAS LIFT;5,318.6 7,226.4 6,129.3 42.38 NIPPLE 3.5 X 2.812 X nipple,PXX PLUG PULLED 10 25 15 2.812 7,239.2 6,138.7 42.35 Liner 5.5X 14#J-55 W 6"wear soxs 5.000 7,282.9 6,171.0- 42.24 Liner 5.5 X 146 J-55 W 6"wear soxs mule shoe 5.000 GAS LIFT;6,353.6 [. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(NO) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) - 7,319.0 6,197.8 42.14 WHIPSTOCK 2 5/8"X 5 1/2"Baker Gen II WHIPSTOCK 2.2 DEG '12/31/2015 LEFT OF HIGHSIDE LOOKING DH WITH SLB GAS LIFT;7,042.0 WPPT AT 7319'RKB REFERENCING HALLIBURTON JEWELRY LOG DATED 27-OCT-15 Perforations&Slots XO Entarging;7,097.8 Y 8 I I I SD en Locator,7,098.3 Dens Top(TVD) Btm (TVD) fshotsJf Top(ftKB) Btm(ftKB) - (ftKB) MUM Zone Dale tf t) Type Com PACKER;7,108.1 -: 7,299.0 7,314.0 6,183.0 6,194.1'A-3,3N-05 "6/28/1987 8.0 RPERF 2 1/8"EnerJet;60 deg. SEAL ASSY;7,099.0 ' - 1' ph SBE;7,109.4 sm 7,309.0 7,310.0 6,190.4 6,191.1 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ ll'90 deg.ph XO Reducing(Turing);7,128.8 IF 7,324.0 7,342.0 6,201.5 6,214.8 A-2,3N-05 '6/26/1987 8.0 RPERF 2 1/8"EnerJet;60 deg. ph • 7,334.0 7,335.0 6,208.9 6,209.7 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph 7,337.0 7,342.0' 6,211.1 6,214.8 A-2,3N-05 '4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph 7,364.0 7,392.0 6,231.2 6,252.0 A-1,3N-05 4/21/1986 4.0 IPERF 4"Csg Gun HJ II;90 NIPPLE;7,226.4 (! deg.phase Mandrel Inserts 00 Enlarging(Turing);7,238.2 6 St ati Liner;7,239.2 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 1 2,505.7 2,502.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 Liner;7,282.8, I- 2 4,039.6 3,804.8 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 0 RPERF;7,299.0-7,314. IPERF;7,309.0-7,310.0- I 3 5,318.6 4,748.9 Cameo MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 4 6,353.6 5,499.8 Cameo MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/3/2016 I 5 7,042.0 5,993.8 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/4/2016 Notes:General&Safety End Date Annotation 11/5/2010 NOTE.View Schematic w/Alaska Schematic9.0 10/17/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. SLOTS;7,322.0-9,649.0 11-03 LINER;7,312.6-9,650.0 -- : I 10/17/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. WHIPSTOCK;7,319.0 I' I RPERF;7,324.0-7,342.0- (PERF;7,334.0-7,335.0 (PERF;7,337.0-7,342.0 (PERF;7,384.0-7,392.0 PRODUCTION;35.0-7,569.1 . • 0 \ ƒ E. ® • §_ II / : R \ { _ • 2 2 I - %^ E c o m \ s E2 \\ G� cr \ E c ^2 e \t ± _\ 7 - \j « �t* 7 c § §/ t $ 2§ ) %7 : - % / g f 4 ƒ 3 (R 7co /} /\j ° \« ® i = \ E c2+em ? { 2 \ \ /6 \\ SS k ) \w SP , oyf < « e !� _ \ 0 ^( 0 k CO a ? CO \/j\_! » / e ` \ iS g S % 9}62-6 \ \ = Ea \ n Lo - co s = R , p2 (. ]2 \ E \ -\ \ > / %.cc, k%/ \ .- \ 9 CO/ G k I- CO _\ " %{ o -2{ \- - ± \ 2 /$ \\)$•) = 3& o G_ $ 7 & N. § k \ .\ /_ ®k Z. \ \\ / / ® \CG k \ 2 ) \ / '} // j 3 b "61r b/ \ / n » _ \ / / @ i as ... E iiii @ . . C : R R G .r..§ a 1 I I , . 4 g. ! . . U - — ............ _ . O g e n J ■ c 7 I0 $ 9 Cn /- \\ «\ § @O �_ $% - # - [E G2 ®© /§ p / e � ƒ) k \\ I- &N- STATE OF ALASKA AL.OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter CasingChangeApprovedProgramr r Rug for Redrill r Perforate New Pool rRepair Well r Re-enter Susp Well r Other:WINJ to OIL 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-026 3.Address: 6.API Number: Stratigraphic r Service F P. O. Box 100360,Anchorage,Alaska 99510 50-029-21537-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025521 KRU 3N-05 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 7601 feet Plugs(measured) None true vertical 6408 feet Junk(measured) None Effective Depth measured 7482 feet Packer(measured) 7106 true vertical 6318 feet (true vertical) 6041 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3727 12 3764 3599 PRODUCTION 7534 7 7569 6384 iv,,,,, 2'^7 ECEIVED Perforation depth: Measured depth: 7299-7314; 7324-7342; 7364-7392 DEC 15 2015 True Vertical Depth: 6183-6194;6201-6215;6231-6252 AOGCC Tubing(size,grade, MD,and TVD) 3.5 x 5.5, L-80/J-55, 7238 MD,6138 TVD Packers&SSSV(type, MD,and TVD) PACKER-BAKER F PACKER @ 7106 MD and 6041 TVD SSSV-QT SAFETY VALVE-BAKER ORBIT VALVE 4500 @ 4510 MD and 4151 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 0 0 2370 1363 215 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r7 Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ 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 Darrell Humphrey/Bob Christensen Email n1139(a conocophillips.com Printed Name Robert D. Christensen Title NSK Production Engineering Specialist Signature 0.1)/�cr --�2ho__ n"ne 659-7535 Date/a//V/J Vn- //s/ih Form 10-404 Revised 5/2015 0.0 !f/.6/ Ll- RBDMS DEC 2 1 2015 Submit Original Only • • 3N-05 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/11/15 SET BAITED HOLEFINDER @ 7026' SLM; PULLED DV'S &SET GLV'S @ 6361', 5326', 4047' &2513' RKB; PULLED HOLEFINDER @ 7026' SLM; PULLED DV& SET OV @ 7949' RKB. 11/16/15 Well brought on to production KUP INJ • 3N-05 ConocoPhillips e ® Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status nal(1 MD(ftKB) Act Btm(969) ,_ ,,.;mve.„ 500292153700 KUPARUK RIVER UNIT INJ 44.90 6,400.00 7,601.0 --. ° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 3N-05.11/22/2015 3 36 27 PM SSSV:NONE Last WO: 10/17/2015 38.49 2/22/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _._Last Tag:SLM 7,452.0 10/25/2015 Rev Reason:GLV C/O pproven 11/22/2015 HAN CER.327- , ,.f,- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED I 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread ,' SURFACE 95/8 8.765 37.0 3,764.3 3,598.8 36.00 J-55 BTC ItI - II II1 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J-55 BTC Tubing Strings CONDUCTOR;38.0-115.0 II Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-W02015 31/2 2.992 32.7 7,1200 6,050.9 9.30 L-80 EUE Brd UPPER COMPLETION Completion Details Nominal ID GAS LIFT;2,505.7 - Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 32.7 32.7 0.06 HANGER Tubing hanger 3.500 g. 4,509.6 4,150.8 42.50 QT Safety Baker Orbit valve 2.890 i , Valve 4500 7,097.8 6,034.6 42.84 XO Enlarging 3.5 EUE Box X 4.5)BT pin 2.960 7,098.3 6,034.9 42.84 Locator Locater sub 2.960 SURFACE;37.0-3,784.3- 7,099.0 6,035.5 42.83 SEAL ASSY Baker 80/40 seal assembly 21 ft 2.960 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2015- 31/2 2.992 7,106.1 7,327.2 6,203.9 9.30 L-80 EUE Bed GAS LIFT:4,039.6 - LOWER PACKER COMPLETION Completion Details Nominal ID IRTop(ftKB) Tap(ND)(ftKB) Top Ind(°) Item Des Com (in) OT Safety Valve;4,509.6 =Trj,_ 7,106.1 6,040.7 42.81 PACKER Baker F packer 5.380 di7,109.4 6,043.180-40 4.000 PULLED11 7,226.4 6,129.3 42.38 NIPPLE 3.5 X 2.812 X nipple,PXX PLUG 10 25 15 2.812 5.000 GAS LIFT;5,318.6 5.000 U Perforations&Slots Dens GAS LIFT;6,353.6 . Top(f1KB) Bbn(MB) (ftKB) (ftKB) Zone Date t) Type Com IIIIIIIIIIIIII7,324.0 r ph 1 GAS LIFT;7,042.0 ph deg.ph II1XO Enbrging;7,097.8 Alli deg.phLocator;7,098.3El 13PACKER;7,106.1- I °SEALASSY;7,099.0St 4- rSBE;7,109.4R m Top(TVD) Valve Latch Port Size TRO Run D(in) Sery Type Type (in) (psi) Run Date Com %O Ro cr10g(Tudng)17,128.0 * 1 2,505.7 2,502.3 Camco MMG 11/2 GAS LIFT GLV RK 0.168 1,348.0 10/10/2015 a 2 4,039.6 3,804.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,307.0 10/10/2015 I3 5,318.6 4,748.9 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,284.0 10/10/2015 III 4 6,353.6 5,499.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,264.0 10/10/2015 NIPPLE 7,226.4 8. 5 7,042.0 5,993.8 Camco MMG 11/2 GAS LIFT OV RK 0.250 0.0 10/25/2015 Notes:General&Safety 00 Enlarging(Tubing);7,238.2 End Date Annotation - 11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 Liner;7,239.2 10/17/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. 10/17/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. Liner;7,282.8, RPERF;7,299.0-7,314.0 IPERF;7,309.0-7,310.0- I I RPERF;7,324.0-7,342.0 IPERF;7,334.0-7,335.0 IPERF;7,337.0-7,342.0 IPERF;7,364.0-7,392.0 PRODUCTION;35.0-7.569.1 • Z(0525 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 4, 2015 Attn.: Makana Bender ?"> 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 7 Ar 4 �Z/2-°i/2015 +4.K.BENDER RE: Static Bottom Hole Pressure/Jewelry Record: 3N-05 Run Date: 10/27/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3N-05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21537-00 Static Bottom Hole Pressure/Jewelry Record (Field Print) 1 Color Log 50-029-21537-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton SCANNED Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAtizaduk., eiglgzait STATE OF ALASKA APKA OIL AND GAS CONSERVATION COM l SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I Plug Perforations r Fracture Stimulate 1 Pull F Operations Shutdown Performed: Suspend I Perforate I..... Other Stimulate r Alter Casing r ChangP pprnvari Program 1— Plug for Redrill P Perforate New Pool P Repair Well it Re-enter Susp Well p Other r- 2. 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development(' Exploratory I ......, 186-026 3.Address: 6.API Number: Stratigraphic P Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-21537-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25521 KRU 3N-05 9. Logs(List logs 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 7601 feet Plugs(measured) None true vertical 6408 feet Junk(measured) None Effective Depth measured 7482' feet Packer(measured) 7106 true vertical 6318' feet (true vertical) 6041 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 0 0 SURFACE 3727 12 3764 3598 0 0 PRODUCTION 7534 7 7569 6383 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7299-7314', 7324-7342', 7364-7392' True Vertical Depth: 6183-6194', 6201-6215'. 6231-6252' EC R EI Tubing(size,grade, MD,and TVD) 3.5, L-80, 7120 MD NOV 17 2015 Packers&SSSV(type, MD,and TVD) PACKER-BAKER F PACKER @ 7106 MD and 6041 TVD AOGCC. SSSV_NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable SCANNED APR 0 8 2016 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations . Exploratory is Development I-_ Service Iv Stratigraphic Copies of Logs and Surveys Run fl 16.Well Status after work: Oil P Gas P WDSPL Printed and Electronic Fracture Stimulation Data T GSTOR I WINJ F WAG P GINJ 1— SUSP F SPLUG P 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: els'--��5- Irew^ N/A or Sundry Number required here Contact Diana Guzman(a�265-6318 Email Diana.Guzman(a�conocophillips.com Printed Name {{ Title Sr. Wells Engineer Signature ' ...4:1,0 1/11, /1/l 265-6318 Date I / 7 I S Form 10-404 Revised 5/2115 VEL 3 RBDMS IVUV 1 8 2015 Submit Original Only • • DrilOperations Summary (with Timelog Depths) nig &Wellls 3N-05 C000coPhiliips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/7/2015 10/7/2015 13.00 MIRU MOVE MOB P MIRU:Seperate the pit module from 0.0 09:00 22:00 Rig, Move the Rig off of 3N-06 and over 3N-05. Connect the pit module to the Rig. R/U all utilities and berming. R/U flowlines,choke house and flow tank. Rig move distance= 30 feet. Accept rig 22:00 10/7/2015 10/7/2015 10/8/2015 2.00 MIRU WELCTL RURD P Take on mud in the pits and ready 0.0 22:00 00:00 cellar to kill well. 10/8/2015 10/8/2015 1.00 MIRU WELCTL MPSP P N/U lubricator,test to 3000 psi and 00:00 01:00 pull the BPV. 10/8/2015 10/8/2015 5.50 MIRU WELCTL KLWL P Bleed casing pressure and tubing 01:00 06:30 pressure through choke to flow tank. CSG=50 psi TBG=50 psi. Pump263 bbls of15.0 ppg kill weight mud. (Well Static) 10/8/2015 10/8/2015 0.50 MIRU WELCTL OWFF P Observe well flow for 30 minutes. 06:30 07:00 (Well Static) 10/8/2015 10/8/2015 3.50 MIRU WHDBOP NUND P N/D Tree and adaptor flange. Tree 07:00 10:30 pulled free at 8K. Inspect the Hanger threads and install test plug. 10/8/2015 10/8/2015 1.50 MIRU WHDBOP RURD P R/U BOP test equipment. P/U test 10:30 12:00 joints and ready TIW and fill-up lines. 10/8/2015 10/8/2015 8.50 MIRU WHDBOP BOPE P Perform shell test;good. Witness of 12:00 20:30 test waived by Johnnie Hill,AOGCC Rep. Perform BOPE test 250/3000 psi to chart for 5 minutes each. Test Annular Preventer,blinds and VBR's with 2 7/8"and 3 1/2"pipe. Test Choke manifold, Upper and Lower IBOP's,Spool valves, HCR kill, Choke,DEMCO kill,TIW and Safety valve.Test Super choke and Manual choke to 1500 psi. Perform AOGCC Koomey test and CPAI Koomey draw down test. Choke valve 11 had a fail/pass. Greased valve and passed test. All other equipment passed test. 10/8/2015 10/8/2015 1.50 MIRU WHDBOP RURD P R/D test equipment and ready cellar to 20:30 22:00 pull BPV and Hanger. 10/8/2015 10/9/2015 2.00 MIRU WHDBOP MPSP T Trouble shoot pulling ISA 2 9/16" 22:00 00:00 BPV. After multiple attempts to pull the BPV, FMC had to replace the setting tool. 10/9/2015 10/9/2015 1.00 MIRU RPCOMP RURD P R/U GBR tongs and SLB Spooler. 7,108.0 7,108.0 00:00 01:00 Install landing joint and BOLDS. 10/9/2015 10/9/2015 0.50 COMPZN RPCOMP PULL P Pull Hanger to the floor. Pulled free at 7,108.0 7,108.0 01:00 01:30 65K 10/9/2015 10/9/2015 1.50 COMPZN RPCOMP CIRC P Pump 1 hole volume of 15 ppm: ICP 7,108.0 7,108.0 01:30 03:00 @ 3 bpm= 1000 psi,FCP @ 3 bpm =860 psi. 10/9/2015 10/9/2015 1.50 COMPZN RPCOMP RURD P Change out elevators, B/O TD,L/D 7,108.0 7,108.0 03:00 04:30 landing joint and hanger. Blow down TD. 10/9/2015 10/9/2015 1.50 COMPZN RPCOMP PULL P Pull 2 7/8"tubing from 7008'.to 6640'. 7,108.0 6,640.0 04:30 06:00 10/9/2015 10/9/2015 2.00 COMPZN RPCOMP PULL P Pull 2 7/8"completion string and 6,640.0 5,348.0 06:00 08:00 control line from 7108'to 5348'. Recovered 28 SS bands. Page 1/6 Report Printed: 11/17/2015 . • • ;; Drilling Operations Summary (with Timelog Depths) &Wells 3N-05 ConocoPhillips i wka Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/9/2015 10/9/2015 0.25 COMPZN RPCOMP SFTY P BOP drill: Kick while tripping. Well 5,348.0 5,348.0 08:00 08:15 secured 51 sec's,CRT 102 sec's. 10/9/2015 10/9/2015 4.75 COMPZN RPCOMP PULL P Pull 2 7/8"completion string from 5,348.0 3,360.0 08:15 13:00 5348'to 3360'. PUW/SOW=45K. 10/9/2015 10/9/2015 0.25 COMPZN RPCOMP OTHR P Clean and clear floor of excess mud 3,360.0 3,360.0 13:00 13:15 from wet trip. 10/9/2015 10/9/2015 0.25 COMPZN RPCOMP SFTY P PJSM:Setting Storm Packer with crew 3,360.0 3,360.0 13:15 13:30 and Baker hand. 10/9/2015 10/9/2015 1.50 COMPZN WELLPR MPSP P Set Storm Packer 136'. PUW/SOW 3,360.0 3,496.0 13:30 15:00 =45K. Release from packer and test to 1000 psi for 10 minutes. Monitor well for 10 minutes,well static. 10/9/2015 10/9/2015 1.00 COMPZN WELLPR WWWH P M/U Jetting tool and Jet stack, R/D 3,496.0 3,496.0 15:00 16:00 TD 10/9/2015 10/9/2015 2.00 COMPZN WELLPR NUND P N/D stack and DSA and rack back on 3,496.0 3,496.0 16:00 18:00 stump. 10/9/2015 10/9/2015 1.50 COMPZN WELLPR NUND P N/D BOP's and AUX IA valve. 3,496.0 3,496.0 18:00 19:30 10/9/2015 10/9/2015 2.00 COMPZN WELLPR NUND P Remove tubing head per PESI and 3,496.0 3,496.0 19:30 21:30 FMC Reps. No growth,tubing head pulled free at 3K using load cell. 10/9/2015 10/10/2015 2.50 COMPZN WELLPR WWSP P Install new pack-off and tubing head. 3,496.0 3,496.0 21:30 00:00 Test to 250/3000 psi for 10 minutes. No problems,good test. 10/10/2015 10/10/2015 2.50 COMPZN WELLPR NUND P N/U BOP's and install DSA. 3,496.0 3,496.0 00:00 02:30 10/10/2015 10/10/2015 0.50 COMPZN WELLPR NUND P Set test plug and fill stack. 3,496.0 3,496.0 02:30 03:00 10/10/2015 10/10/2015 0.75 COMPZN WELLPR BOPE P Test break/spool on stack and new 3,496.0 3,496.0 03:00 03:45 FMC tubing head 250/3000psi. Control line valve on tubing head leak. 10/10/2015 10/10/2015 0.75 COMPZN WELLPR BOPE T Control line valve on tubing head leak. 3,496.0 3,496.0 03:45 04:30 FMC installed plug in port. Re-test 250/3000 psi,good test. 10/10/2015 10/10/2015 0.50 COMPZN WELLPR RURD P Install 7"ID wear bushing. 3,496.0 3,496.0 04:30 05:00 10/10/2015 10/10/2015 1.50 COMPZN WELLPR MPSP P Engage packer.pressure equalize. 3,496.0 3,496.0 05:00 06:30 No pressure,rotate 1 turn,slack off past set depth, PUW=45K-SOW= 45 K,pull packer. Set depth 136' 10/10/2015 10/10/2015 2.00 COMPZN RPCOMP CIRC P Circulate 267 bbls 15.0 ppg mud,5 3,360.0 3,360.0 06:30 08:30 bpm,925 psi. 10/10/2015 10/10/2015 6.50 COMPZN RPCOMP PULL P Pull 2 7/8"tubing from 3360'to rig 3,360.0 0.0 08:30 15:00 floor. 10/10/2015 10/10/2015 1.00 COMPZN RPCOMP RURD P R/D GBR and ready rig floor to P/U 0.0 0.0 15:00 16:00 fishing BHA 10/10/2015 10/10/2015 2.50 COMPZN RPCOMP BHAH P P/U BHA#1:Overshot Assembly with 0.0 240.0 16:00 18:30 a 2 7/8"Grapple. RIH 240', PUW/SOW=37K 10/10/2015 10/11/2015 5.50 COMPZN RPCOMP PULD P Single in the hole with 3 1/2"DP from 240.0 6,406.0 18:30 00:00 240'to 6406'. 10/11/2015 10/11/2015 1.50 COMPZN RPCOMP PULD P P/U 3 1/2" 15.50# HT-38 DP to 6,406.0 7,021.0 00:00 01:30 7021'. PUW= 135K-SOW=95K. 10/11/2015 10/11/2015 2.00 COMPZN RPCOMP CIRC P Condition mud,circulate 1.75 hole 7,021.0 7,021.0 01:30 03:30 volume,mud weight 15 ppg all the way around. Page 2/6 Report Printed: 11/17/2015 • 0 w Drilling Operations Summary (with Timelog Depths) :4 &Wells 3N-05 C:ortocorhialips ALvi Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/11/2015 10/11/2015 0.50 COMPZN RPCOMP FISH P P/U DP to 7084',above tubing cut at 7,021.0 7,101.0 03:30 04:00 7108'. PUW=138K SOW=96K RWT = 110K. Tag Fish/tubing cut at 7095', NO GO at 7101'. Set 25K down and engage fish. Worked pipe until Seal assembly tagged the top of the PBR when slacking off to verify fish on. 10/11/2015 10/11/2015 1.00 COMPZN RPCOMP CIRC P Circulate B/U and monitor well for 10 7,101.0 7,101.0 04:00 05:00 minutes. 10/11/2015 10/11/2015 0.50 COMPZN RPCOMP TRIP P POOH with fish from 7084'to 6454'. 7,101.0 6,454.0 05:00 05:30 PUW= 128K SOW 93K. 10/11/2015 10/11/2015 0.50 COMPZN RPCOMP SVRG P Service Rig and pump dry job. 6,454.0 6,454.0 05:30 06:00 10/11/2015 10/11/2015 3.50 COMPZN RPCOMP TRIP P POOH with fish from from 6454'to 6,454.0 303.0 06:00 09:30 303'. 10/11/2015 10/11/2015 1.50 COMPZN RPCOMP BHAH P L/D BHA#1,Overshot assembly and 303.0 0.0 09:30 11:00 fish(Seal assembly). 10/11/2015 10/11/2015 0.50 COMPZN RPCOMP SVRG P Service TP/Daily inspection. 0.0 0.0 11:00 11:30 10/11/2015 10/11/2015 0.50 COMPZN RPCOMP BHAH P P/U BHA#2,Spear fishing assembly. 0.0 304.0 11:30 12:00 10/11/2015 10/11/2015 3.00 COMPZN RPCOMP TRIP P RIH from 304'to 7106'. 304.0 7,106.0 12:00 15:00 10/11/2015 10/11/2015 1.50 COMPZN RPCOMP FISH P Tag fish at 7106'and engage fish at 7,106.0 7,112.0 15:00 16:30 7112'. PUW= 135K SOW=98K. Drop dart,sheared out at 1300 psi. Circulate 298 bbls,5 bpm, 1800psi. P/U 185K,Jar Packer 2X, release Packer with 285K straight pull. 10/11/2015 10/11/2015 1.00 COMPZN RPCOMP CIRC P Circulate 86 bbls B/U at 5 bpm, 1800 7,112.0 7,112.0 16:30 17:30 psi. Pump 130 bbls at 3 bpm 915 psi. Monitor well(static). 10/11/2015 10/11/2015 4.50 COMPZN RPCOMP TRIP P POOH from 7112'to 500'and monitor 7,112.0 500.0 17:30 22:00 well for 10 minutes(static). 10/11/2015 10/12/2015 2.00 COMPZN RPCOMP BHAH P POOH and L/D BHA#2 and 500.0 0.0 22:00 00:00 fish/Packer. 10/12/2015 10/12/2015 1.00 COMPZN WELLPR BHAH P P/U BHA#3 Clean out assembly to 0.0 344.0 00:00 01:00 344'. 10/12/2015 10/12/2015 3.00 COMPZN WELLPR TRIP P RIH from 344'to 1210'. 304.0 6,967.0 01:00 04:00 10/12/2015 10/12/2015 0.25 COMPZN WELLPR SFTY P Kick while tripping drill;SSI-31 sec, 6,967.0 6,967.0 04:00 04:15 CRT=91 sec. Perform AAR 10/12/2015 10/12/2015 1.25 COMPZN WELLPR CIRC P 'Circulate and condition mud to insure 6,967.0 6,967.0 04:15 05:30 15.0 ppg in and out 10/12/2015 10/12/2015 3.50 COMPZN WELLPR DRLG P Wash and ream from 7157'to 7192', 6,967.0 7,294.0 05:30 09:00 tag cement at 7192'. RWT=105K, PUW= 135K,SOW=95K,rotate at 60 RPM,7 bpm=3450 psi, 10K WOB. Continue washing and reaming from 7192'to 7294'. Lost circulation at 7294',shut down pumps and monitor well. 10/12/2015 10/12/2015 1.50 COMPZN WELLPR WAIT T Monitor well with pumps off,well 7,294.0 7,245.0 09:00 10:30 static. Circulate at 1 bpm 275 psi,lost returns. Shut pumps off and monitor well for losses,well static. Wait on orders from CPAI engineer. 10/12/2015 10/12/2015 5.00 COMPZN WELLPR WAIT T Waiting on mud from mud plant due to 7,245.0 7,245.0 10:30 15:30 unexpected losses. Page 3/6 Report Printed: 11/17/2015 • • 0 Drilling Operations Summary (with Timelog Depths) &Welts 3N-05 conoccwhinips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/12/2015 10/12/2015 4.50 COMPZN WELLPR COND T Build volume and cut weight of mud 7,245.0 7,245.0 15:30 20:00 from 15.0 to 14.0 ppg. 10/12/2015 10/13/2015 4.00 COMPZN WELLPR DISP T Close Annular Preventer and pump 14 7,245.0 7,245.0 20:00 00:00 ppg mud down the annulus to displace 15 ppg mud,bull heading mud into the Perfs. Pump annulus volume= 188 bbls of 14 ppg mud at1 bpm/663 psi. Mud Lost to Formation=95 bbls Mud Lost by Bullheading=188 bbls Total bbls Lost=283 10/13/2015 10/13/2015 3.00 COMPZN WELLPR COND T Condition mud back to 14 PPG 7,245.0 7,245.0 00:00 03:00 10/13/2015 10/13/2015 1.50 COMPZN WELLPR REAM P Continue to wash down with clean out 7,245.0 7,472.0 03:00 04:30 assembly. UWT= 140 K DWT=97K, ROW= 105K,@ 30 RPM, F/TQ=5K. Circulating @ 6BPM©2300 psi. 10/13/2015 10/13/2015 1.50 COMPZN WELLPR CIRC P Circulated reverse©6.5 BPM @ 7,472.0 7,472.0 04:30 06:00 2050 PSI.395 BBL's 10/13/2015 10/13/2015 0.50 COMPZN WELLPR OWFF P Obseved well 7,472.0 7,472.0 06:00 06:30 10/13/2015 10/13/2015 4.00 COMPZN WELLPR TRIP P POOH with BHA*3.Clean out 7,472.0 344.0 06:30 10:30 assembly 10/13/2015 10/13/2015 2.50 COMPZN WELLPR BHAH P Laid down BHA#3 and cleared floor 344.0 0.0 10:30 13:00 of tools 10/13/2015 10/13/2015 0.50 COMPZN RPCOMP SVRG P Service/inspect Top drive 0.0 0.0 13:00 13:30 10/13/2015 10/13/2015 1.00 COMPZN RPCOMP RURD P RU GBR handling equipment for 0.0 0.0 13:30 14:30 completion run 10/13/2015 10/13/2015 8.50 COMPZN RPCOMP RCST P PJSM: Make up lower completion as 0.0 7,327.0 14:30 23:00 per procedure design and RIH On Drill pipe 10/13/2015 10/14/2015 1.00 COMPZN RPCOMP RURD P RU lines to set and test F packer @ 7,327.0 7,327.0 23:00 00:00 7106 ft. 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP RURD P Continue to Rig up lines to set packer. 7,327.0 7,327.0 00:00 00:30 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP PACK P Dropped ball.and set packer as per 7,327.0 7,106.0 00:30 01:00 Baker rep. Center of elements @ 7108.0 ft. 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP PRTS P Attempted test packer to 1300 psi. 7,106.0 7,106.0 01:00 01:30 with out success.XXP plug on floor. 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP WAIT T Discuss options with town Eng. And 7,106.0 7,106.0 01:30 02:00 Camco.XXP plug not install just the seat assembly. 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP RURD T RD testing equipment. 7,077.0 7,077.0 02:00 02:30 10/14/2015 10/14/2015 3.50 COMPZN RPCOMP TRIP T POOH with drill pipe.and hyd setting 7,077.0 0.0 02:30 06:00 assembly. 10/14/2015 10/14/2015 1.00 COMPZN RPCOMP RURD T Install Dutch riser. 0.0 0.0 06:00 07:00 10/14/2015 10/14/2015 3.00 COMPZN RPCOMP SLKL T PJSM.RU HES slick line.PT lubicator 0.0 0.0 07:00 10:00 to 1600 psi.no surface leaks. 10/14/2015 10/14/2015 2.50 COMPZN RPCOMP SLKL T RIH with 2.812 PXX prong and set in 0.0 0.0 10:00 12:30 X nipple at 7226 ft 10/14/2015 10/14/2015 0.25 COMPZN RPCOMP PRTS T PT PXX plug and packer to 1350 psi 0.0 0.0 12:30 12:45 for 15 min's chart recored. Page 4/6 Report Printed: 11/17/2015 . , , . • • , „, Drilling Operations Summary (with Timelog Depths) &Wells 3N-05 ConocoPhiilips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/14/2015 10/14/2015 1.25 COMPZN RPCOMP SLKL T POOH with slick line and RD. 0.0 0.0 12:45 14:00 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP RURD T RD Dutch riser 0.0 0.0 14:00 14:30 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP SVRG P Service and inspect top drive. 0.0 0.0 14:30 15:00 10/14/2015 10/14/2015 4.00 COMPZN RPCOMP TRIP T RIH with drill pipe to 7100 ft. 0.0 7,100.0 15:00 19:00 10/14/2015 10/14/2015 4.50 COMPZN RPCOMP DISP P Circulate out 14#mud to sea water 7,100.0 7,100.0 19:00 23:30 with 100 BBL deep clean spacer, 100 BBL of 9.8 Hi-Vis sweep.follow by sea water. 10/14/2015 10/15/2015 0.50 COMPZN RPCOMP OWFF P Monitor well 7,100.0 7,100.0 23:30 00:00 10/15/2015 10/15/2015 2.00 COMPZN RPCOMP OTHR P Clean out mud from trip tank 7,100.0 7,100.0 00:00 02:00 10/15/2015 10/15/2015 8.00 COMPZN RPCOMP PULD P Lay down drill pipe 7,100.0 0.0 02:00 10:00 10/15/2015 10/15/2015 0.50 COMPZN RPCOMP RURD P Pulled wear ring 0.0 0.0 10:00 10:30 10/15/2015 10/15/2015 0.50 COMPZN RPCOMP WWWH P Wash BOPE stack and tbg spool 0.0 0.0 10:30 11:00 10/15/2015 10/15/2015 0.50 COMPZN RPCOMP SVRG P Service and inspect top drive. 0.0 0.0 11:00 11:30 10/15/2015 10/15/2015 3.00 COMPZN RPCOMP RURD P RU GBR and Camco equipment for 0.0 0.0 11:30 14:30 completion run 10/15/2015 10/16/2015 9.50 COMPZN RPCOMP PUTB P PJSM : RIH with 3.5"L-80 8rd upper 0.0 3,500.0 14:30 00:00 completion as per design 10/16/2015 10/16/2015 7.50 COMPZN RPCOMP PUTB P Continue to RIH with upper completion 3,500.0 7,070.0 00:00 07:30 as per design. Installed 3 SS bands, 147 Cannon clamps. 10/16/2015 10/16/2015 1.50 COMPZN RPCOMP PRTS P Function test Orbit valve to 3500 psi 7,070.0 7,070.0 07:30 09:00 closed.open and circulate thru it. good test. 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP PUTB P Continue to pick up Tbg. No Go seals 7,070.0 7,122.0 09:00 09:30 at 7122.5 ft.pulled seals free of PBR. 10/16/2015 10/16/2015 2.00 COMPZN RPCOMP CRIH P Circulated in 265 BBL's of CI treated 7,122.0 7,100.0 09:30 11:30 sea water. Displaced with 10 bbls of un treated down tbg. 10/16/2015 10/16/2015 2.00 COMPZN RPCOMP HOSO P Spaced out tbg.install hanger.hook 7,100.0 11:30 13:30 up control lines for orbit valve.and open. 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP SFTY P Safety stand up.review of accident. 13:30 14:00 10/16/2015 10/16/2015 1.00 COMPZN RPCOMP THGR P Engaged seal assembly.Landed 7,100.0 7,115.0 14:00 15:00 hanger. RIDS. 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP PRTS P Attempted to test tbg.to 3500 psi. 7,115.0 15:00 15:30 Returns up IA.swapped to IA with same result. 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP WAIT T Discuss options with town Eng. 15:30 16:00 10/16/2015 10/16/2015 1.50 COMPZN RPCOMP RURD T Prep for Slick line operations. 16:00 17:30 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP SVRG P Service and inspect top drive. 17:30 18:00 10/16/2015 10/16/2015 2.00 COMPZN RPCOMP SLKL T Spot and rig up HES slick line to pull 18:00 20:00 SOV and install Dummy valve in GLM Page 5/6 Report Printed: 11/17/2015 • DriIfirsog Operations Summary (with Timelog Depths) &Welts 3N-05 conota�illi�ss RS.isk.3 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 10/16/2015 10/17/2015 4.00 COMPZN RPCOMP SLKL T RIH and pulled SOV. Not sheared. 20:00 00:00 RIH and set dummy valve.able to circulate still 3 strokes fluid to surface at 90 psi. RIH with hole finder. Trouble shoot circulation point.Set in coupling above seals @ 7074 SLM. Pressure up to 1000 psi for 3 min's. No returns from IA. Released Hole finder and POOH.SEt back slick line. 10/17/2015 10/17/2015 0.50 COMPZN RPCOMP SFTY P Safety Stand up:accident review 00:00 00:30 10/17/2015 10/17/2015 0.50 COMPZN RPCOMP RURD T RU GBR tubing handling equipment. 00:30 01:00 Prep to respace tubing. 10/17/2015 10/17/2015 2.00 COMPZN RPCOMP PULD T BOLDS. Pull hanger to floor. 01:00 03:00 Disconnect control lines. Lay down hanger and pups. 10/17/2015 10/17/2015 3.00 COMPZN RPCOMP HOSO T re-space well. Land hanger. RILDS 03:00 06:00 Note splice in control lines for Orbit valve 75 ft.below hanger. 10/17/2015 10/17/2015 1.00 COMPZN RPCOMP PRTS T PT Tubging to 3500 psi.Bled down to 06:00 07:00 1000 psi. PT IA to 3000 psi for 30 min's. 10/17/2015 10/17/2015 2.00 COMPZN RPCOMP SLKL T RIH with slick line retrieve dummy 07:00 09:00 valve form 7041 ft.POOH RD slick line 10/17/2015 10/17/2015 0.50 COMPZN RPCOMP PRTS P Test Orbit valve from below to 3000 09:00 09:30 psi.good test function test back to open and pump thru it.Valve is open. 10/17/2015 10/17/2015 0.50 COMPZN WHDBOP DHEQ P Install BPV.and test from below to 09:30 10:00 1000 psi. 10/17/2015 10/17/2015 1.00 COMPZN WHDBOP RURD P RD Camco and GBR equipment 10:00 11:00 10/17/2015 10/17/2015 3.00 COMPZN WHDBOP OTHR P Clear floor and clean not floor&rotary 11:00 14:00 sumps 10/17/2015 10/17/2015 3.50 COMPZN WHDBOP NUND P ND BOPE 14:00 17:30 10/17/2015 10/17/2015 4.50 COMPZN WHDBOP NUND P Nu Tree adaptor and tree. Build 17:30 22:00 control manifold.Test to 250/5000 psi. 10/17/2015 10/17/2015 0.50 COMPZN WHDBOP MPSP P Pull BPV 22:00 22:30 10/17/2015 10/18/2015 1.50 COMPZN WHDBOP FRZP P PJSM RU LRS to freeze protect well 22:30 00:00 with 85 BBLs of Diesel. 10/18/2015 10/18/2015 1.50 COMPZN WHDBOP FRZP P Continue to Freeze protect well. Let 00:00 01:30 equalize to tubing. .0 PSI TBG,0 PSI IA,0 PSI OA 10/18/2015 10/18/2015 1.00 COMPZN WHDBOP MPSP P Pick up lubricator and set Type H 01:30 02:30 BPV. Lay down Lub. 10/18/2015 10/18/2015 1.00 COMPZN WHDBOP SISW P Secure well. 02:30 03:30 10/18/2015 10/18/2015 0.50 DEMOB MOVE DMOB P Begin RD equipment for move. Rig 03:30 04:00 Released at 04:00 hrs Page 6/6 Report Printed: 11/17/2015 KUP INJ • 3N-05 ConocoPhifli s �, Well Attributes Max Angle&MD TD � ... I/WI Field Name Wellbore Status ncl MD ftKB Act Btm ftKB ;ji Wellbore AP U () (ftKB) (ftKB) AIc1SKa`i61G' 500292153700 KUPARUK RIVER UNIT INJ 44.90 6,400.00 7,601.0 tlCma;oP+valps`a --. ....... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-05,11/17/20159.09.09 AM SSSV NONE Last WO: 10/17/2015 38.49 2/22/1986 Vertical schematic(actual) Annotation •Depth(ftKB) End Date Annotation Last Mod By End Date ..___ Last Tag SLM 7,452.0 10/25/2015 Rev Reason:WORKOVER,GLV C/O,PULLED lehallf 11/17/2015 HANGER;32.7-I III.". I PLUG,NOTE UPDATE,TAG Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread • -"'t"SURFACE 9 5/8 8.765 37.0 3,764.3 3,598.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...°WVLen(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J-55 BTC Tubing Strings • li Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibtft) Grade Top Connection TUBING-WO 2015 31/2 2.992 32.7 7,120.0 6,050.9 9.30 L-80 EUE 8rd CONDUCTOR;38.0-115.0 a UPPER COMPLETION 4 Completion Details GAS LIFT;2,505.7It Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 32.7 32.7 0.06 HANGER Tubing hanger 3.500 4,509.6 4,150.8 42.50 QT Safety Baker Orbit valve 2.890 Valve 4500 7,097.8 6,034.6 42.84 XO Enlarging 3.5 EUE Box X 4.5 IBT pin 2.960 7,098.3 6,034.9 42.84 Locator Locater sub 2.960 SURFACE;37.0-3,766..3-* 7,099.0 6,035.5 42.83 SEAL ASSY Baker 80/40 seal assembly 21 ft 2.960 is Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(IbW) Grade Top Connection TUBING WO 2015- 31/2 2.992 7,106.1 7,327.2 6,203.9 9.30 L-80 EUE 8rd GAS LIFT;4,039.6 LOWER PACKER I COMPLETION Completion Details Nominal ID 4 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) CT Safety varve;4,509 0 7,106.1 6,040.7 42.81 PACKER Baker F packer 5.380 1111 7,109.4 6,0431 42.79 SBE Seal bore ext.80-40 4.000 4 7,226.4 6,129.3 42.38 NIPPLE 3.5 X 2.812 X nipple,PXX PLUG PULLED 10 25 15 2.812 7,239.2 6,138.7 42.35 Liner 5.5 X 144J-55 W 6"wear soxs 5.000 GAS LIFT;5,318.67,282.9 6,171.01 42.24 Liner 5.5X146J-55 W 6"wear soxs mule shoe 5.000 Perforations&Slots Shot 11 Dens Top(ND) Btm(ND( (shots/f GAS LIFT;8,353.6 Top(ftKB) Btm(ftKB) (ftKB( (ftKB) Zone Date t) Type Com 7,299.0 7,314.0 6,183.0 6,194.1 A-3,3N-05 6/28/1987 8.0 RPERF 2 1/8"EnerJet;60 deg. il ph 7,309.0 7,310.0 6,190.4 6,191.1 A-2,3N-05 4/21/1986 ' 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph GAS LIFT;7,042.0 7,324.0 7,342.0 6,201.5 6,214.8 A-2,3N-05 6/28/1987 8.0 RPERF 2 1/8"EnerJet;60 deg. ph la 7,334.0 7,335.0' 6,208.9 6,209.7 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph 7,337.0 7,342.0 6,211.1 6,214.8 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ 1I'90 XO Enlarging;7,097.8 j, deg.ph Locator:7 098 7,364.0 7,392.0 6,231.2 6,252.0 A-1,3N-05 4/21/1986 4.0 IPERF 4"Csg Gun HJ II;90 AM deg.phase PACKER;7,106.1- Mandrel Inserts SEAL ASSY;7,099.0 ": ( St SBE;7,109.4 ix,, ati on Top(TVD) Valve Latch Port Size TRO Run XO Reducing(Tubing);7,128.8 r ftKB N Top( ) (ftKB) Make Model 00(in) Sen m Type Type (in) (psi) Run Date Co '`0 rF 1 2,505.7 2,502.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/10/2015 4 2 4,039.6 3,804.8 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/10/2015 3 5,318.6 4,748.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/10/2015 4 6,353.6 5,499.8 Comex MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/10/2015 t NIPPLE;7,228.4 5 7,042.0 5,993.8 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/25/2015 Notes:General&Safety XO Enlarging(Tubing);7,238.2 i End Date Annotation 11/5/2010 NOTE'View Schematic w/Alaska Schematic9.0 Liner;7,239.2 10/17/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. 10/17/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. Liner;7,282.8, RPERF;7,299.0-7,314.0 _ IPERF;7,309.0-7,310.0-- -4 RPERF;7,324.0-7,342.0-- IPERF;7,334.0-7,335.0 c IPERF;7,337.0-7,342.0- lic IPERF;7,364.0-7,392.0 PRODUCTION;35.0-7,569.1 di pT13 /6 — • • Loepp, Victoria T (DOA) From: Regg, James B (DOA) Sent: Thursday, October 15, 2015 10:10 AM To: Guzman, Diana; Loepp, Victoria T (DOA); Schwartz, Guy L(DOA) Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: RE: KRU 3N-05 - PTD# 186-026 - Sundry#315-445 - BOPE Test Waiver Request Attachments: BOP Nabors7ES 10-8-15.xlsx Follow Up Flag: Follow up Flag Status: Flagged SCANNED An 1 7 2016 As discussed this morning,your request for a waiver of the BOPE test(due today) is granted subject to confirmation that the BOPE rams and annular have been tested on the completion pipe size during the most recent test—copy of 10/8/15 report submitted to AOGCC is attached. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Guzman, Diana [mailto:Diana.GuzmanOconocophillips.com] Sent: Thursday, October 15, 2015 9:02 AM To: Regg, James B (DOA); Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: RE: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request Good morning Victoria, This is an email to follow up on my phone call earlier today. 7ES is currently getting ready to RIH with the upper completion. Based on the original BOPE inspection request timed for 7:00 pm today(please see attached email). Although, it's a good stopping point, we wouldn't be able to test now unless the witness is waived. 7ES wouldn't be able to test at 7:00 tonight since we probably won't be done running with the upper completion by then. Please review my original BOPE Test waiver request(email below) and let me know how you would like us to proceed. Thank you so much for your time, Diana Guzman Senior Wells Engineer 1 ConocoPhillips Alaska Inc. • • Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Guzman, Diana Sent: Wednesday, October 14, 2015 3:57 PM To: 'Regg, James B (DOA)'; 'Loepp, Victoria T (DOA)'; 'Schwartz, Guy L(DOA)' Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: RE: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request Victoria, As per our conversation, please see the email below. If you have any questions or require any further information, please contact me at 907 265 6318. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Guzman, Diana Sent: Wednesday, October 14, 2015 3:03 PM To: Regg, James B (DOA); 'Loepp, Victoria T(DOA)'; Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request Good Afternoon All, Nabors 7ES is currently TIH with DP to swap the mud system over to sea water(Step# 14 under the approved Sundry). After we swap the WBM to seawater,we will be POOH with DP and RIH with the upper completion. We're estimating to RIH with the upper completion (Step# 15 under the approved Sundry) before our deadline for the BOPE test(due at midnight tomorrow). Remaining work to be completed after RIH with the upper completion: 2 15. R1H with upper compition • 16. Shear the PBR. Space out, mark the pipe, and pull out of the PI3R. 17. Spot a balanced pill of corrosion inhibited brine in the Tbg&IA from up to above the new SOY. 18. Install space out pups below the hanger, MU hanger (MU control line to hanger if present). L hanger, RILDS. 19. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed tI zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 20. Pull the landing joint,install BPV or two-way check. PT BPV or two-way check to 1,000 psi from t 21. ND BOPE. 22. NU tree. If BPV is installed,pull T3PV& install tree test plug. Test tree. Pull test plugftwo-way ch( 23. Freeze protect well wI diesel. 24. Install BPV. 25. RDMO. Due to the current work scope left on 3N-05,we would like to request a BOPE Test Waiver since we should be ND our BOPE Friday and RDMO Saturday. If for any reason we have any change of scope,we will notify you and perform the BOPE test. If you have any questions or require any further information, please contact me at 907 265 6318. Thank you for your time. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 3 • 0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.reqqalaska.gov AOGCC.Inspectors(a�alaska.gov phoebe.brooks(cilalaska.oov Contractor: Nabors Rig No.: 7ES DATE: 10/8/15 Rig Rep.: B.Tiedemann/D.Guess Rig Phone: 907-659-7847 Operator: CPAI Op. Phone: 907-659-7844 Rep.: P.Smith/J. Haynes E-Mail n2364(a�conocophillips.com Well Name: KRU 3N-05 PTD# 1860260 Sundry# 315-445 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3000 Annular: 250/3000 Valves: 250/3000 MASP: 2804 MISC.INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13-5/8 GK P Pit Level Indicators P P #1 Rams 1 2-7/8"X 5" P Flow Indicator P P #2 Rams 1 Blind Rams P Meth Gas Detector P P #3 Rams 1 2-7/8"x 5" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3 1/8 gate P Inside Reel valves 0 NA HCR Valves 2 3 1/8 HCR P Kill Line Valves 2 3 1/8&2" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 2950 P CHOKE MANIFOLD: Pressure After Closure(psi) 1600 P Quantity Test Result 200 psi Attained(sec) 17 P No.Valves 16 FP Full Pressure Attained(sec) 93 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg. (#and psi): 5 @ 1945 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 1 Test Time: 6.5 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested CV 1-16,Annular,Top Pipe VBR's&Lower Pipe VBR's 250/3000 psi with 3-1/2"&2-7/8"Test Jts,Tested (2)-(2-1/16")5m valves on test spool under single gate.Witness of Test by CPAI Rep Paul Smith&John Haynes, NAD Rep Brian Tiedemann&David Guess. Choke valve#11 Fail, re-greased, re-test pass. AOGCC Inspection 24 hr Notice Yes Date/Time 10/7/15 06:15 Waived By Johnnie Hill Test Start C: 10/8/2015 14:00 (date) (time) Witness Test Finish Date/Time: 10/8/2015 20:30 Form 10-424(Revised 06/2014) BOP Nabors7ES 10-8-15.xlsx P7-6 tg,C zlev Regg, James B (DOA) From: Guzman, Diana <Diana.Guzman@conocophillips.com> �7 Sent: Thursday, October 15, 2015 10:59 AM 1` a I II ib To: Regg,James B (DOA); Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: RE: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request Attachments: 3N-05 BOP test#2 Chart 10-8-2015.pdf; 3N-05 BOP test#3 Chart 10-8-2015.pdf; 3N-05 BOP test#1 Chart 10-8-2015.pdf Good morning Jim, Thank you for your approval. Attached are the copies of the charted BOP rams and annular test on the 2 %" and 3 %" test joints. Please let me know if you have any questions or require any further information. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. SCONE Drilling&Wells ifs 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, October 15, 2015 10:10 AM To: Guzman, Diana; Loepp, Victoria T(DOA); Schwartz, Guy L (DOA) Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: [EXTERNAL]RE: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request As discussed this morning, your request for a waiver of the BOPE test (due today) is granted subject to confirmation that the BOPE rams anri annular have been tested on the completion pipe size during the most recent test—copy of 10/8/15 report submitted to AOGCC is attached. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 1 • • 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Guzman, Diana [mailto:Diana.Guzman@aiconocophillips.com] Sent: Thursday, October 15, 2015 9:02 AM To: Regg, James B (DOA); Loepp, Victoria T(DOA); Schwartz, Guy L (DOA) Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: RE: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request Good morning Victoria, This is an email to follow up on my phone call earlier today. 7ES is currently getting ready to RIM with the upper completion. Based on the original BOPE inspection request timed for 7:00 pm today(please see attached email). Although, it's a good stopping point, we wouldn't be able to test now unless the witness is waived. 7ES wouldn't be able to test at 7:00 tonight since we probably won't be done running with the upper completion by then. Please review my original BOPE Test waiver request (email below) and let me know how you would like us to proceed. Thank you so much for your time, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Guzman, Diana Sent: Wednesday, October 14, 2015 3:57 PM To: 'Regg, James B (DOA)'; 'Loepp, Victoria T(DOA)'; 'Schwartz, Guy L (DOA)' Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: RE: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request Victoria, As per our conversation, please see the email below. If you have any questions or require any further information, please contact me at 907 265 6318. Thank you, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 2 i • 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax 918-662-1893 From: Guzman, Diana Sent: Wednesday, October 14, 2015 3:03 PM To: Regg, James B (DOA); 'Loepp, Victoria T(DOA)'; Schwartz, Guy L(DOA); DOA AOGCC Prudhoe Bay Cc: Nabors 7ES Company Man; Nabors 7ES Tool Pusher; Rauchenstein, Rock D; Packer, J.Brett; Kanady, Randall B Subject: KRU 3N-05 - PTD# 186-026 - Sundry# 315-445 - BOPE Test Waiver Request Good Afternoon All, Nabors 7ES is currently TIH with DP to swap the mud system over to sea water(Step# 14 under the approved Sundry). After we swap the WBM to seawater, we will be POOH with DP and RIH with the upper completion. We're estimating to RIH with the upper completion (Step# 15 under the approved Sundry) before our deadline for the BOPE test (due at midnight tomorrow). Remaining work to be completed after RIH with the upper completion: 15. RIH withupper completion 16. Shear the PBR. Space out,mark the pipe, and pull out of the PPP.. 17. Spot a balanced pill of emrosion inhibited brine in the TE g& IA from up to above the new SOV, 18. Install space out pups below the hanger, Wil` hanger (MU control line to hanger if present). L hanger, RILDS. 19. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed tl zero, then the tubing. Ramp up the lA.pressure quickly to shear the SOV. 20. Pull the landing joint, install BPV or two-way check. PT BPV or two-way check to 1,000 psi frorn 21. ND )3OPE. 22. NU tree. If BPV is installed,pull BPV& install tree test plug. Test tree. Pull test plug/two-way cht 23. Freeze protect well wt diesel, 24. Install I3PV. 25. RDMO. Due to the current work scope left on 3N-05,we would like to request a BOPE Test Waiver since we should be ND our BOPE Friday and RDMO Saturday. If for any reason we have any change of scope, we will notify you and perform the BOPE test. If you have any questions or require any further information, please contact me at 907 265 6318. Thank you for your time. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 3 • • Cell:305-332-6332 Fax:918-662-1893 4 l 3�D> ( '%,o AP —,__ 10(665- 1. 7Pst- "W,:«.r''�� Ile-�.�� .� ��fi r . � � i�'• ..SII/� i�__ '� ' ,�J. or,/, ��s,,�� , 00. ,4,-, ::01 .„,..,•,1,1_,„,,,i,....1.. ...ANI 1111111&44‘ �` #0)* 1.1.°"0° 110r142471=Mmuw=1"...‘44S141 fie4)010°. 010111.1111114 "1.Wijr7(74, 14_441.01, -., 01.-isollreg=a4ip ilifi 4'. 'V It i441r=/7 0111.0•Nommsmo. witiMussmiessiolow Ns I aftiii'l ii rol,a_00,1mwor alivalliillir 44hti4t4 N' ,k .* * „ flifri 1,4%1 t#,A sm=mstaiftp 4.4,7-17 *A\ \‘ Mil woo r gra—ajW w-. 414# ♦ ice. eft —0100"1111"lig eV: 0111 aere se ♦ ♦ �� olil......•.� ♦ ♦ \\\. lit , ,, ' ' � � �� 01111 009 �1♦ � � ` ``���`�\` �roil*, �i � • TX � .• ��\\ 111111• i ll� iii, . 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Fax: 907 276 7542 www.aogcc alaska.gov Diana Guzman Sr. Wells Engineer 6 .... Oc-� �,ConocoPhillips Alaska, Inper`) P.O. Box 100360 I Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3N-05 Sundry Number: 315-445 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CL ,0 4.c...isz...,_ Cathy P. Foerster Chair DATED this 2`t' day of July, 2015 Encl. • STATE OF ALASKA R E EWE D i-. ..)KA OIL AND GAS CONSERVATION COM, 310N )UL 2 2 2015 APPLICATION FOR SUNDRY APPROVALS pT5 //s 20 AAC 25.280 AOGCC 1.Type of Request. Abandon r Rug Perforations r Fracture Stimulate r" Pull Tubing r s Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Frforate New Pool r Repair Well r ' Re-enter Susp Well r Other: Pre-CTD Set-Up ' I✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r186-026• I 3.Address: 6.API Number: Stratigraphic r Service rri P.O. Box 100360,Anchorage,Alaska 99510 50-029-21537-00 7.If perforating, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r No r KRU 3N-05 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): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured). Junk(measured): 7601 . 6408 - 7482'- 6318'. none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 3727 9.625 3764' 3599' PRODUCTION 7534 7 7569' 6384' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7299-7314,7324-7342,7364-7392 6183-6194,6201-6215,6231-6252 2.875 J-55 7207 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BROWN HB-1 PACKER MD=7137 TVD=6063- SAFETY VLV-BAKER FVL SAFETY VALVE MD=1792 TVD=1792 ' 12.Attachments: Description Summary of Proposal r-" 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r` Development " Service r ' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work. 8/29/2015 OIL r WINJ r 0 WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Diana Guzman @ 265-6318 Email. Diana.Guzman@conocophillips corn Printed Name Diana Guzman Title: Sr. Wells Engineer Signature �tAiia '1./ Phone:265-6318 Date 3-7U1 2.‘ ZOI5 77 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 i 5 "4 y 5 Plug Integrity r BOP Test MechanicaI Integrity Testocation Clearance r Other: g(Gp f-5 f" to 3-0 vv ps; (,vtP5/J /s 25°44-P54 1 ,lv;vi. v lir pk-CV-Z 1-7 ,fly' ft5 t 7`z, ZSG ) 1)S 1 . Spacing Exception Required? Yes ❑ No / Subsequent Form Required: 1 Q -4_G 4 / ' APPROVED BY Approved by:� .WjP COMMISSIONER THE COMMISSION Date: � -' - �� t r til 3 l/approved apple atlpp I v Id for 11 months trom the date of approval. Y ' //„ Z ! a— �1 1�1 1 i w 1 .iii )ate ��4— Submit Form and RECEIVED ]U1 2 2 2015 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 20,2015 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to workover the Kuparuk Well 3N- 05 (PTD# 186-026). Well 3N-05 was originally drilled and completed as a pre-produced injector in 1986. 3N-05 has been shut-in since 2010 when a packer leak was observed during a leak detect logging run. Another leak detect log was run in 2011 which confirmed the packer leak. The well was left shut-in and later that year the perforations were isolated with a sand plug and a cement cap.Before being shut-in,well 3N-05 injection rates had stabilized to 700 BWPD. In order to setup well 3N-05 for injection and CTD development the entire 2 '/8" completion will be pulled and replaced with a 5 V2" big tail pipe configuration and 3 '/2"tubing. This RWO set up will preserve injection into the existing perforations while setting up the well for CTD drilling. If you have any questions or require any further information,please contact me at 907-265-6318. Sincerely, Diana Guzm n Wells Engineer CPAI Drilling and Wells 3N-05 Rig Workover Pull and Replace 2 '/g" & Install 51/2"Big tail pipe and 31/2" Completion (PTD #: 186-026) Current Status: This well is currently shut in and awaiting a rig workover. Scope of Work: • Pull 2'/g"completion and replace with a 5 ''A"big tail pipe configuration and 3 '/2"tubing General Well info: Well Type: Injector MASP: 2804 psi using 0.1 psi/ft gradient(Most recent SBHP=3408 psi on 12/26/14) Reservoir Pressure/TVD: 3408 psi/6043' TVD(10.7 ppg)on 12/26/14 Wellhead type/pressure rating: FMC Gen 3/5M psi TH BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: MIT—OA passed April 30,2015 CMIT—T x IA passed May 13,2012 Earliest Estimated Start Date: August 29,2015 Production Engineer: Suzanne Short/Toon Changklungdee Workover Engineer: Diana Guzman Work:265-6318 E-mail: Diana.Guzman@conocophillips.com Pre-Rig Work 1. RU DSL: a. Dummy off all GLM's and leave GLM 5 open for circulation. b. Chem cut the 2'/a"tubing. 2. Test packoffs and LDS. 3. Set BPV and bleed down OA prior rig arrival. Proposed Procedure: 1. MIRU 2. Pull BPV. Reverse circulate KWF. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3 p0,2 3. Set BPV&blanking plug,PT to 1,000 psi from below if possible,ND tree,NU BOPE&test toi$9blpsi. 4. Pull blanking plug&BPV. 5. RU to pull tubing,MU landing joint,BOLDS's laying down tubing. 6. RIH w/overshot&grapple on drillpipe,latch onto tubing stub and jar free. 7. POOH standing back drillpipe. 8. MU packer fishing assembly and RIH to retrieve packer and tubing tail, establish circulating parameters, record up/down weights, fish packer. POOH standing back drillpipe. 9. RIH w/double string mills, magnets, and boot baskets; cleanout to PBTD. Circulate well clean. POOH standing back drillpipe. 10. RIH w/casing scraper,magnets,and boot baskets to PBTD,reverse circulate well clean. 11. POOH laying down drillpipe. 12. MU Wearsox tailpipe assembly and lower packer w/ PBR, RIH w/ new tubing to approximate setting depth. Set the tubing in the slips. 13. RU DSL: RIH with GR/CCL and positive plug. Correlate packer depth and make depth correction. Continue to RIH and set positive plug in nipple profile. 3N-05 Rig Workover Pull and Replace 2 %" & Install 5 '/2"Big tail pipe and 3 %2" Completion (PTD #: 186-026) 14. Pressure up to set the packer. PT the tubing to confirm plug integrity. MO DSL. PT the IA to confirm packer is set. Swap from 15 ppg WBM to seawater. 15. RIH with upper completion 16. Shear the PBR. Space out,mark the pipe,and pull out of the PBR. 17. Spot a balanced pill of corrosion inhibited brine in the Tbg&IA from up to above the new SOV. 18. Install space out pups below the hanger, MU hanger (MU control line to hanger if present). Land the hanger,RILDS. 19. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero,then the tubing. Ramp up the IA pressure quickly to shear the SOV. 20. Pull the landing joint,install BPV or two-way check. PT BPV or two-way check to 1,000 psi from below. 21. ND BOPE. 22. NU tree. If BPV is installed,pull BPV&install tree test plug. Test tree. Pull test plug/two-way check. 23. Freeze protect well w/diesel. 24. Install BPV. 25. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Run GLD,pull positive plug. Set up for injection. 4. Handover to Ops to put back on injection. . . .. ..____..-....... . s KUP 3N-05 . ConocoPhillips i Well Attributes Max Angle&MD TD (fl(: Wellbore APIIUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) Alaska, coel 500292153700 KUPARUK RIVER UNIT INJ 44.90 6400.00 7,601.0 1pS ""- Comment NIS(ppm) Date Annotation lEnd Date KB-Grd(k) Rig Release Date --- Wel conng:-3N-0s srzsr2Dt2 tre43e PM --SSSV:TROP iLast WO:.. _ 38.49 2/22/1986 -_ -- -- -.-._ -_ _. .--_ _ Scnema0c-Actual - Annotation Depth(kKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,239.0 2/25/2012 Rev Reason:GLV C/O,PULL CATCHER ninam 5/25/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,33 CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... Stang ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.765 37.0 3,764.3 3,598.8 36.00 J-55 BTC �- -- Cuing Description String 0... 'String ID...Top(11KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J-55 BTC r I Tubing Strings Tubing Description String 0... Sng ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...Sng Top Thrd TUBING 27/8 I ta2.441 32.5 I 7,206.5 6,114.8 6.50 I J-55 [EUESrdMABMOD Completion Details CONDUCTOR, Top Depth 38-115 (TVD) Top Incl NomL_ Top(RKB) (kKB) CI _1tem Description Comment ID(in) SAFETY vtv, ` 32.5 32.5 0.09 HANGER FMC TUBING HANGER 2.441 1,792 � 1,792.1 1,792.0 0.81 SAFETY VLV BAKER FVL SAFETY VALVE 2.310 _ 7,118.8 6,050.0' 42.76 PBR BROWN PBR 2.500 GASUFT, 7,136.6 6,063.1 42.69 PACKER BROWN HB-1 PACKER 2.347 2'227 ._ 7,173.8 6,090.5 42.55 NIPPLE CAMCO D NIPPLE 2.250 7,205.9 6,114.31 42.50&SOS CAMCO PE-500 SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Topincl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) SURFACE. J i l 7,197 6,107.6 42.46 CEMENT PUMP 5.5 BBBL CEMENT(15.8 PPG)CONTAMINATE w/ 3/24/2012 0.000 10 BBLS BIOZAN,TAG TOP OF SAND @ 7270' 37-3.764 Perforations&Slots GAS LIFT, Shot 4.044 Top(TVD) Btm(TVD) Dens Top(k103) Btm(ftKB) (ftKB) (BBB) Zone Date (ah... Type Comment - 7,299 7,314 6,183.0 6,193.9 A-3,3N-05 6/28/1987 8.0 RPERF 21/8"EnerJet;60 deg.ph GAS LIFT, 7,309 7,310 6,190.2 6,190.9 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph 5,402 7,324 7,342 6,201.3 6,214.8 A-2,3N-05 6/28/1987 8.0 RPERF 21/8"EnerJet;60 deg.ph 7,334 7,335 6,208.8 6,209.5 42,3N-05 4/21/1986 1.0(PERF 4"Csg Gun HJ II'90 deg.ph GASB 3 7,337 7,342 6,211.0 6,214.8 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ(I'90 deg.ph - 7,364 7,392 6,231.2 6,252.0 A-1,3N-05 4/21/1986 ' 4.0 IPERF 4"Csg Gun HJ 11;90 deg.phase 111 GAS LIFT, Notes:General&Safety 6.673 End Date Annotation II11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 LAS LIFT. 7080 I PER,7,119 PACKER,7,137 NIPPLE,7,174 Ii I SOS,7,206 \ CEMET, 7,1N97 CEMENT PLUG,7,197 RPERF, 7,299-7,314 IPERF, 7,309-7,310 RPERF, 7,3247,342 _ _-__ IPERF, _ 7.3347,335 Mandrel Details Top Depth Top Port P_ (ND) Incl OD Valve Latch Size TRO Run (PERF, , Ste Top(ftKB) (ftKB) (*) Make Model (in) Sem Type Type fn) (pail Run Data Com... 7,337-7,342 1 2,227.1 2,226.6 6.00 Mer(a TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 2 4,044.0 3,808.0 42.59 Meria TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 IPERF, ' 3 5,402.2 4,809.6 41.56 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 73647.392 4 6,236.8 5,416.8 44.69 Marla TMPD 1 GAS LIFT DMY EBK 0.000 0.0 4/21/1986 5 6,673.0 5,727.0 44.32 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 i 6 7,079.9 6,021.5 42.91 MMH 2.875x1.5 1 1/2 GAS LIFT DMY BK 0.000 0.0 5/10/2012 PRODUCTION, 35-7.569 TD,7,601 , 3N-05 Proposed CTD Schematic 3-1/2"9.3#L-80 EUE 8rd Tubing to surface ( 3-1/2"Baker Orbit deployment valve at—4500'MD .11 Note:2.835"min ID,no nipple profile \ 16"62.5#H-40 5 x 3-1/2"Camco gas lift mandrels shoe @115'MD s Packer—7100'MD 3-1/2"X-nipple(2.812"min ID) 111. 3-1/2"X 5-1/2"Big Tail Pipe configuration(see details) 9-5/8"36#J-55 shoe @ 3764'MD Mill.'r Crossover 3-1/2"to 5-1/2"liner 7250'-7330'MD CRITICAL DEPTH!! *Vented/Ported for installation 2 Jts 5-1/2",14#,H-40,Range 3 6. _" *Depth correlated to Schlumberger CET log of 3/25/86 *6"OD special clearance connections A-sand perfs *Wearsox 6"OD,every 2.5-3.0'along the pipe 7299-7392' M *Bevel/shoe on bottom *All connections Baker-Locked — j Ci 54° 3N-05L1-03,Planned TD=9160'MD 2%"slotted liner with liner top at 7240'MD __._._..... \• 7310'proposed • – -- -- TOWSdepth 7"cplgs 7270', ` i 7312',7356'MD 3N-05L1-02,Planned TD=11,095'MD \`\ /; 2%"slotted liner with billet at 7600'MD �\\ `<N 3N-05L1-01,Planned TD=11,585'MD 2%"slotted liner with billet at 9925'MD /i ii i 7"26#J-55 shoe 3N-05L1,Planned TD=11,550'MD @ 7569'MD 2%"slotted liner with billet at 10,070'MD STATE OF ALASKA AL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations RI Perforate r"' Other r Alter Casing r Rill Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program '-- Operat. Shutdown r Stimulate - Other f ' Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 186 -026 3. Address: 6. API Number: Stratigraphic r Service f;r P. O. Box 100360, Anchorage, Alaska 99510 - 50 029 - 21537 - 00 " 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25521 " - 3N - 9. Logs (List logs 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 7595 feet Plugs (measured) 7174 true vertical 6402 feet Junk (measured) None Effective Depth measured 7482 feet Packer (measured) 7137 true vertical 6318 feet (true vertucal) 6063 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3727 9.625 3764 3599 PRODUCTION 7534 7 7569 6384 WOWED APR 1 8 VJ12 RECEIVED Perforation depth: Measured depth: 7299' - 7314', 7324'- 7342', 7364' -7392' AP R 1 7 2012 True Vertical Depth: 6183' - 6194', 6201'- 6215', 6231' -6252' AOGCC Tubing (size, grade, MD, and ND) 2.875, J -55, 7206 MD, 6114 TVD Packers & SSSV (type, MD, and ND) PACKER - BROWN HB -1 PACKER @ 7137 MD and 6063 TVD SSSV - BAKER FVL SSSV @ 1792 MD and 1792 ND 12. Stimulation or cement squeeze summary: � a 0 p cc / ,..., c__-_-r - L ,.. 4 . 7 a Intervals treated (measured): not applicable /,�*" G Treatment descriptions including volumes used and final pressure: D'u - ,._. " - ( --I2 - 2 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service I' Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ - WAG r GINJ E 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: 311 -323 Contact T. Senden (a) 265 -1544 Printed Name . Senden Title Staff Wells Engineer Signature Phone: 265 -1544 Date 4 /t (it \ RBDMS APR 171011 61, ''_` 7 2,-- Form 10 - 404 Revised 11/2011 /Submit Original Only / ../e.7`7, . 1.-- KUP • 3N -05 ConocoPhillips 01 Well Attributes Max Angle & MD TD Alaska, In Wel!bore API/DWI Field Name Well Status Inc! 0) MD (ftKB) Act Btm (ft9B) 500292153700 KUPARUK RIVER UNIT INJ _ 44.90 6,400.00 7,601.0 " "°' Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date ••• Wall Confiq: - 3N - 05, 2124120121302:52 AM SSSV: TRDP Last WO: 38.49 2/22/1986 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,292.0 2/9/2012 Rev Reason: TAG ninam 2/24/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd HANGER. 33 CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 F( WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (1VD) ... String Wt... String ... String Top Thrd 1 SURFACE 95/8 8.765 37.0 3,764.3 3,598.8 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ink PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ft913) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 27/8 2.441 32.5 7,206.5 6,114.8 6.50 J -55 EUE8rdABMOD Completion Details Top Depth CONDUCTOR, (TVD) Top Incl Noml... 38-115 Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) 1 1 32.5 32.5 0.09 HANGER FMC TUBING HANGER 2.441 SAFETY VLV, sz L E a° - J I 1,792.1 1,792.0 0.81 SAFETY VLV BAKER FVL SAFETY VALVE 2.310 • • El 7,118.8 6,050.0 42.76 PBR BROWN PBR 2.500 fl 11 7,136.6 6,063.1 42.69 PACKER BROWN HB-1 PACKER 2.347 GAS LIFT, 7,173.8 6,090.5 42.55 NIPPLE CAMCO D NIPPLE 2.250 2,227 7,205.9 6,114.3 42.50 SOS CAMCO PE -500 SHEAR OUT SUB 2.441 n I Perforations & Slots Shot Top (TVD) Btm (ND) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment J 7,299 7,314 6,183.0 6,193.9 A -3, 3N -05 6/28/1987 8.0 RPERF 2 1/8" EnerJet; 60 deg. ph SURFACE. 7,309 7,310 6,190.2 6,190.9 A -2, 3N -05 4/21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph 37 - 3,764 7,324 7,342 6,201.3 6,214.8 A -2, 3N -05 6/28/1987 8.0 RPERF 2 1/8" EnerJet; 60 deg. ph 7,334 7,335 6,208.8 6,209.5A -2, 3N -05 4/21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph GAS LIFT, 044, 7,337 7,342 6,211.0 6,214.8 A -2, 3N -05 4/21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph 7,364 7, 6,231.2 6,252.0 A -1, 3N -05 4/2.1/1986 4.0 IPERF 4" Csg Gun HJ II; 90 deg. phase GAS LIFT, Notes: General 392 & Safety 5.402 End Date Annotation F 11/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, } 6,237 i` ' F allii GAS LIFT. J. 1 6,673 1 __ GAS LIFT, 6 ,060 PBR, 7,119 --. PACKER.7.137 •ar I NIPPLE, 7,174 It 1 SOS,7,206 � RPERF, , °" 7,299 -7,314 IPERF, 7,309 -7,310 "--'7-=.: RPERF, _ _ 7,324 -7,342 _ _ IPERF. 7,334 -7,335 - _ Mandrel Details z___;_._= Top Depth Top Port OD ® ( (ftKB) Inc' (*) Make Model ) Sery Type Type 00 (PM) Run Date Com... Run IPERF, Stn Top (ftKB) 7'337 - 7'342 1 2,227.1 2,226.6 6.00 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 2 4,044.0 3,808.0 42.59 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 IPERF, 3 5,402.2 4,809.6 41.56 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 7.3647,392 4 6,236.8 5,416.8 44.69 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 5 6,673.0 5,727.0 44.32 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 6 7,079.9 6,021.5 42.91 MMH 2.875x1.5 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/21/1986 PRODUCTION. 35- 7,569 A ' TD, 7,601 3N -05 Well Work Summary • DATE SUMMARY 12/31/11 RIH AND TAGGED FILL AT 0' CTMD. BEGAN PUMPING 19 BBLS OF SAND SLURRY AND CT PLUGGED OFF AFTER 9 BBLS OUT OF NZL. PUH WHILE REVERSE CIRCULATING DIESEL TO FREE OBSTRUCTION. AT SURFACE THE PLUG CAME FREE. JOB POSTPONED DUE TO DOYON 141 RIG MOVING TO 3N PAD. JOB IN PROGRESS 1/19/12 TAG FILL @ 7304' SLM, 7343 RKB, SAND 1/28/12 DUG OUT AND WARMED UP EQUIPMENT, CHANGED REEL SWIVEL, COMPLETED BOP TEST, JOB IN PROGRESS 1/29/12 RIH TAGGED SAND AT 7317' CTMD (7343 RKB), LAYED IN 10 BBLS OF SAND SLURRY, PUH WAITING FOR SAND FALLOUT, TAGGED SAND AT 7267' CTMD (7293' RKB), 33' SHORT OF TARGET SAND TOP, POOH, F/P TUBING TO 3000', ORDER MORE SAND FOR A RESTART. JOB IN PROGRESS 1/30/12 OPENED WELL AND STARTED RIH, REEL SWIVEL BLEW OUT AT 798' CTMD. ISOLATED REEL AND POOH. 2/2/12 WARM UNIT AND WAIT ON FLUIDS. ATTEMPT TO THAW COILED TUBING STRING. PUMPED .7 BBLS TOTAL. TARPED REEL AND INSTALLED ALL HEATERS ON LOCATION IN THE REEL HOUSE. 2/3/12 CONTINUED THAWING THE REEL AND INJECTOR. DISCOVERED SPLIT IN THE CT STRING ON RIGGING UP TO THE WELL.. STARTED TO CUT CT DOWN TO THE SPLIT FARTHEST FROM THE WHIP END OF THE STRING. IN PROGRESS. 2/4/12 THAWED REEL, CUT 1000' OF CT, CIRCULATED STRING VOLUME AND DRIFTED REEL WITH .865" STEEL BALL. RECOVERED BALL. JOB IN PROGRESS. 2/5/12 TESTED BOPE, REBUILD UTIM, AND MAKE SUPPORT BRACKET. 2/6/12 TAG SAND TOP AT 7260' MD. MOVE RETURN TANKS TO MITIGATE WIND BLOWING GAS AT UNIT AND CEMENT VAN. ATTEMPT TO CIRC OUT GAS HEAD FROM TBG. H2S IN RETURNS. SHUT DOWN AND HAVE ENTIRE RIG UP MOVED TO DOWN WIND SIDE OF THE UNIT. IN PROGRESS. 2/7/12 SPOTED 15.8 PPG CEMENT PLUG FROM 7260' MD TO 7211' MD. FREEZE PROTECTED WELL WHILE POOH. RECOVERED BALL FROM BALL DROP. JOB COMPLETE. 2/9/12 GAUGE TBG TO 2.29" TO D -NIP © 7174' RKB, TAG @ 7292' SLM, EST 7' OF OPEN PERFS, ABLE TO PUMP @ 1/4 BPM w/ 1950 PSI ON TBG. 2/12/12 MIRU UINIT AND PERFORM BOPE TEST. 2/13/12 LAYED IN SAND PLUG FROM (7286' CTMD), CORRECTED DEPTH OF 7306' TO 7280' MD. FREEZE PROTECTED WELL TO 2500' ND. 2/14/12 LOCATED D- NIPPLE AT 7153' CTMD CORRECTED TO 7174.8' MD. LAYED IN CEMENT PLUG FROM 7290' MD TO 7211'. MAINTAINED 1:1 RETURNS THROUGH OUT JOB. FREEZE PROTECTED TBG TO 2500 ND. JOB COMPLETE. 2/18/12 TAG HARD CEMENT @ 5789' SLM. 2/23/12 RU MOTOR & MILL, RIH TAG TOC_@ 5864 CTMD, MILLED_ CMT STRINGERS TO_ 6110' CTMD �_ ROP SLOWED TO >1FPM, 6263' RETURN RATE INC REASED SUBSTANTIALLY, PUH CLOSE CHOKE, WHP INCREASED TO 1750 PSI, TRY INJECTING INTO PERFS @ .5 BPM 2500 WHP, MILLED DOWN TO 6355' CTMD, MADE IT THROUGH CEMENT, RIH TO 7205' CTMD, DRY TAG SAND @ 7260' CTMD, F/P TUBING, JOB IN PROGRESS 2/25/12 LOCATED TBG TAIL @ 7175' SLM, 7205' RKB. TAGGED SAND TOP @ 7239' SLM, EST. 7269' RKB. READY FOR CTU. 3/20/12 LATE START DUE TO WEATHER, RU CTU, RIH 1:1 RETURNS, TAGGED CEMENT SHEATH AT 6190', WORKED PIPE DOWN TO 6205 CTMD, POOH, CALLED FOR MOTOR & MILL TO REMOVE CEMENT. JOB IN PROGRESS 3/21/12 DELAYED START DUE TO WEATHER, RIH W/ MILLING BHA, MILL CMT F/5918' T/6215' CTMD, GOOD 1:1 RETURNS THROUGH OUT JOB, 54 TOTAL STALLS, POOH FOR RESTART WITH NEW MOTOR AND DIFFERENT MILL. JOB IN PROGRESS 3/22/12 RU MILLING BHA, RIH TRY MILLING WITH 3 BLADED JUNK MILL, UNABLE TO MAKE HOLE, POOH AND CHANGE BIT TO A TURBO SCALE MILL, SLOW ROP, MILLED CMT F/6212' T/7148' CTMD, 43 TOTAL STALLS, TAGGED NPL, POOH. F/P TUBING TO 3000'. JOB IN PROGRESS 3/23/12 DELAYED START DUE TO WEATHER, RU NPL LOCATOR, RIH, LOCATED NPL @ 7161' CTMD (7174' RKB), TAGGED TOP OF SAND © 7254' CTMD (7267' RKB), POOH, F/P TUBING TO 3000'. AM RESTART FOR CEMENT. JOB IN PROGRESS 3N -05 Well Work Summary 3124/12 RU CEMENT BHA, RIH, +251ERRECTION AT FLAG 7174' RKB (D- NP.AG TOP OF SAND AT 7270' RKB, PUMP 5.5 BBLS ENT (15.8 PPG), CONTAMINATE WITH 10 BBLS BIOZAN TO 7211' RKB (TOC), HOLDING 1:1 RETURNS THROUGH OUT THE JOB. JOB COMPLETE, READY FOR S/L X- 3/26/12 TAGGED CEMENT PLUG © 7197' SLM, MIT TBG / CEMENT PLUG TO 2500 PSI, RECORDED ON CHART, PASSED. IN PROGRESS. WEATHER DELAYED START. SET 2.5" CATCHER SUB IN D NIPPLE @ 7174' RKB. PULLED DV FROM 7080' RKB. READY FOR CIRC OUT. 4/15/12 Circulated 250 bbl of 11.0 ppg CaCl2 brine down the tubing taking returns up the IA through the open GLM at 7080'. Freeze protected from 1500' to surface with diesel in the tubing and IA. • ? D ► (,o Regg, James B (DOA) From: NSK Problem Well Supv [n1617 ©conocophillips.com] Ref/ 4 c 3/ Sent: Friday, April 13, 2012 3:33 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: 3N -05 (PTD 186 -026) Charted MITT post cement Attachments: MIT KRU 3N -05 03- 26- 12.xls; 3N -05 MITT chart 03- 26- 12.pdf All, Attached is a copy of the MITT and the chart of that test that was performed on 03/26/12 after the wellbore had been secured with cement. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 APR 1 LUL il • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa ialaska.gov; doa. aoucc.prudhoe.bavCrDalaska.gov; phoebe.brooksAalaska.gov; tom.maunder(dralaska.gov OPERATOR: ConocoPhllips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 3N DATE: 03/26/12 OPERATOR REP: Ahern - HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N -05 ' Type Inj. N TVD " 6,063' Tubing 2,050 2,500 2,500 2,500 - Interval p P.T.D. 1860260 ' Type test P Test psi 1515.75 Casing 0 0 0 0 P/F P - Notes: As per Sundry# 311 -323 — OA 20 20 20 20 Tagged Cement plug 7197' SLM ' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D., Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT KRU 3N - 05 03 - 26 - 12 NW C. % +ems Vi i= � . - - `� . t rare0=4", At 0101•WIMII II Alt 01021,a".1.411011 j ...--__ , 41/111t1/ ( �/ I y 1 1 •,... .,.. ..��. X11 111111111 IIII i �► �,,..,.. K x �9 ` 11111 ,� � . �� , . � o ,v►uNUl � �' Ci tr •. Q 1111 ! C ►. X11 � '� C� CC 1�i _.uw �� p� 1 �� Iii �ir� � n� III �, ��� ��rr nm� � _ .,,�� �n� I � ���� r IIIII fi - .,, � �.N�� N�1 ��� I g o bl itli t rumniatitt �u� • •a +'+ g oins ,. i , l _ C ,Nl 1� �� u• .. �44 ,J w r, rr qq 11 ♦ �. ♦ V� �1 l�t���1 ��,.,,•ttstes �i ��! �l�l •ll�j r ,�,��„ `` `- ��►.►a -r II �� fl �/ � � .4,0 t \ c"\V _ ..,...... \ 4.4260 4 . ,V, Om a . .—. ...14 , il. ,,I.,7:".■,■.1"14* 4"",..471P-2:WOO +c)4 • • SITalf[E LIEF AELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ty Senden Wells Engineer -�- co- ConocoPhillips Alaska, Inc. l P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -05 Sundry Number: 311 -323 Dear Mr. Senden:. 4. "; `' ''t Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, 410 Danie '. Seamount, Jr. Chair DATED this2 Tday of October, 2011. Encl. STATE OF ALASKA riZECEIVED J ALASKRLAND GAS CONSERVATION COMMISSION 141Z/� 1 C�- 2 4 ?fly . APPLI FOR SUNDRY APPROVALS N � , ,�1 20 AAC 25.280 tb 1. Type of Request: Abandon r Plug (or Redrill 1 Perforate New Pool r Repair w ell r Char.aa Approved ogram Suspend r Plug Perforations Perforate r Rill Tubing r Ancnorria, tension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Atter casing r Other: t 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -026 • 3. Address: 6. API Number: Stratigraphic r Service r . P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21537 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No F7 3N -05 • 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): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): „.7.691' .Fy4O8r -yOZ -' 7482' 6318' 7174' Casing A Length fi i rL /. / / Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 3727 9.625 3764' 3599' PRODUCTION 7534 7 7569' 6384' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7299 -7314, 7324 -7342, 7364 -7392 6183 -6194, 6201 -6215, 6231 -6252 2.875 J -55 7206 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN 'HB -1' PKR MD= 7137 TVD= 6063 SSSV - BAKER 'FVL' SSSV MD= 1792 TVD= 1792 12. Attachments: Description Summary of Proposal J;� 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/4/2011 Oil r / Gas r WDSPL r Suspended - 16. Verbal Approval: Date: WINJ V GINJ r WAG r Abandoned r Commission Representative: /o• z t •ee GSTOR fl SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Senden @ 265 -1544 Printed Name T Sende Title: Wells Engineer Signature Phone: 265-1544 Date 10 /2o /1.) • \ Commission Use Only Sundry Number: 311 ✓ W Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /d y l y APPROVED BY Approved by: , COMMISSIONER THE COMMISSION Date: 1 ° Iii] II Form 10 -403 10 / o • Z/ ! ORIGINAL t licate in D l OC 14' II Submi / z,p .1t .,,,,,e • 4. � KUP 3N -05 Conocof 1 fillips d °� ell Attributes Max Angle & MD TD Wei!bore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) Alaska, Inc, Corr.°Ph II . ps Comment H2S (ppm) Date Annotation End Date KBGrtl (ft) Rig Release Date "' SSSV: TRDP Last WO: 38.49 2/22/1986 Well Conha' -3N -05,2/1/2011 3 584 PM . Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,384.0 1/31/2011 Rev Reason: SET PLUG, TAG Imosbor 2/1 /2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER, 33 CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 37.0 3,764.3 3,598.8 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 35.0 7,569.1 6,383.8 26.00 J -55 BTC Tubing Strings ffubing Description String 0... String ID ... Top (KISS) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR, I I TUBING 2 7/8 2.441 32.5 7,206.5 6,114.8 6.50 J -55 EUE Srd AB MOD Completion Details Top Depth 38-115 (ND) Top loot Noml... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) SAFETY VLV, 32.5 32.5 0.09 HANGER FMC Tubing Hanger w/ Pup 2.441 1,792 1,792.1 1,792.0 0.81 SAFETY VLV Baker 'FVL' SSSV 2.310 7,118.8 6,050.0 42.76 PBR Brown 'PBR' w/ Pup (6.09 + 11.64) 2.500 GAS LIFT, 7,136.6 6,063.1 42.69 PACKER Brown'HB -1' Pkr (Pinned @ 57,400# release) 2.347 2,227 7,173.8 6,090.5 42.55 NIPPLE 2 7/8" CAMCO 'D' Nipple (2.250" ID) 2.250 7,205.9 . 6,114.3 42.50 SOS 2 7/8" CAMCO PE -500 Shear Out Sub 2.441 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Incl Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 7,173.8 6,090.5 42.55 PLUG CA - 2 PLUG SET 1/31/2011 0.000 SURFACE, . ' 37-3764 Perforations & Slots W.- Shot GAS LIFT, Top (ND) Btm (ND) Dens 4,044 , Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh -- Type Comment I 7,299.0 7,314.0 6,183.0 6,193.9 A - 3N - 6/28/1987 8.0 RPERF 21/8" EnerJet; 60 deg. ph 7,309.0 7,310.0 6,190.2 6,190.9 A -2, 3N -05 4/21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph GAS LIFT, 111. 7,324.0 7,342.0 6,201.3 6,214.8 A - 3N -05 6/28/1987 8.0 RPERF 21/8" EnerJet; 60 deg. ph 5,402 I 7,334.0 7,335.0 6,208.8 6,209.5 A -2, 3N -05 4!21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph 7,337.0 7,342.0 6,211.0 6,214.8 A -2, 3N -05 4/21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph GAS BIZ 7_ 7,364.0 7,392.0 6,231.2 6,252.0 A -1, 3N -05 4/21/1986 4.0 IPERF 4" Csg Gun HJ II; 90 deg. phase I` Notes: General & Safety End Date Annotation GAS LIFT, 11/5/2010 NOTE: VIEW SCHEMATIC w /Alaska Schem atic9.0 6.673 I GAS LIFT, 7,080 1 I P00,7,119 / PACKER, 7,137 I NIPPLE,7,174� '. // / PLUG, 7,174 I SOS, 7,208 RPERF, 7,299 -7,314 IPERF, 7,309 -7,310 RPERF, 7,3247,342 IPERF, 7,3347,335 Mandrel Details l op Depth Top Port - - (TVD ) Inc! OD Valve Latch Size TRO Run IPERF, Ste Top (ftKB (ftKB) ( °) Make Model tin) Sery Type Type 1!M (psi) Date 7,337 -7,342 1 2,227, 2,226 6.00 Merla TMPD 1 GAS LIFT DMY BK 0101.00) .000 0.0 4/21/1986 Run Com... 2 4,044.0 3,808.0 42.59 Merla TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 IPERF, ® 3 5,402.2 4,809.6 41.56 Merla TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 7,3647,392 4 6,236.8 5,416.8 44.69 Merla TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 5 6,673.0 5,727.0 44.32 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/21/1986 6 7,079.9 6,021.5 42.91 MMH 2.875x1.5 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/21/1986 PRODUCTION, 35-7,569 ' TD, 7,801 r • g SHORT PROCEDURE This procedure was written to isolate the wellbore from the high pressure reservoir until the well is either worked over or sidetracked. At that time, a new AOGCC sundry will be applied for. 1. RU slickline: Pull tubing tail plug, tag fill, and obtain static bottom hole pressure. '2. RU Coiled Tubing: Lay in 19 bbls of a 4 ppa slurry (2700 lbs of sand in 16 bbls of co'`. gel). Dress off top of sand down to 7260' ctmd. 3. Lay in 5 bbls of 15.8 ppg class G cement on top of sand plug. Contaminate cement from 6685' down to 7211' ctmd. 4. WOC 5 5. Tag cement top and pressure test to 2500 psi. -- 't C " 6 ` 4^ -1 11-€5.4.- LI 6. Pull lowermost DMY VLV and circulate in inhibited fluid with a diesel cap. 7. Replace DMY VLV and pressure test tubing and inner annulus. • 4 WELL LOG TRANSMITTAL PROACTIVE DincnosTic SERVICES, INC. To: AOGCC Christine Mahnken � ,�; MAP C 5 2 D I 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) Leak Detection - WLD 16- Jan -11 3N -05 EDE 50 -029- 21537 -00 2) u� r 06 -43( RE cEivaD Signed : Date : FEB Zi' Print Name: Of 01 tacstiCejoanQs;Cone ;IiSSi f i PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL : pdsanchoraueememorvloq.com WEBSITE : www.memorvloa.com C:\Documents and Settings\Diane Williams \Desktop \Transmit_Conoco.docx WELL LOG TItANSTNUTTAL To: Alaska Oil and Gas Conservation Comm. November 2, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3N -05 Run Date: 10/31/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029- 21537 -00 XdV#fX NOV 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 3 Fax: 907 - 273 -3535 klinton. wood hallib on.cafn . _.. Date: Signed:_ i' • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 21, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3N -05 Run Date: 10/9/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21537 -00 Vim NG= ! 2U1U 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 ®a Fax: 907- 273 -3535 c� klinton.w-zod a alliburton.com Date: Signed: • ~/ • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~g6- oa-~O ~=s 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 October 19, 2008 and the corrosion inhibitor/sealantwas pumped October 21, 2008. 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, , f~ ~~~ .~' MJ La eland ~~~~~j ~In ~' ~ ~= 2t~~ 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 n~fe 10/22/2008 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 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4" 2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21!2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 MEMORANDUM • TO: Jim Regg ~ P.I. Supervisor ~` ~~ ~b`1 `UO FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October Ol , 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-OS KUPARUK RIV UNIT 3N-OS Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv~~g~--- Comm Well Name: KUPARUK RN UNIT 3N-OS API Well Number: 50-029-21537-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080930091255 Permit Number: 186-026-0 ~ Inspection Date: 9/28/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-os ..Type Inj. w TVD 6063 IA 1100 2170 2140 2140 P.T. 1860260 TypeTest SPT ~ Test psi ~ 2 »~ OA i 240 360 ~ 360 ~ 360 Interval aYRTST p~F P ~ Tubing ~~ zsoo zsoo i zsoo ~ zsoo Notes: ,. _, ,~ ~ ~, ~ 1 Wednesday, October 01, 2008 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg "J <þ( I,,~ P.I. Supervisor f\~~ 24 uw DATE: Thursday, August 19, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-05 KUPARUK RIV UNIT 3N-O5 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv-:)ae- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3N-05 API Well Number: 50-029-21537-00-00 Inspector Name: Jeff Jones Insp Num: mitJJO40818101032 Permit Number: 186-026-0 Inspection Date: 8/15/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-05 Type Inj. S TVD 6402 IA 1100 1920 1900 1890 P.T. 1860260 TypeTest SPT Test psi 1515.75 OA 820 930 930 930 Interval 4YRTST P/F P Tubing 2720 2720 2720 2720 Notes: 1.1 BBLS diesel pumped. Thursday, August 19,2004 Page 1 of 1 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 3 O- 07 Kuparuk Well 3 F- 1 0 Kuparuk Well 3 F- 06 Kuparuk Well 3 F- 02 Kuparuk Well 3 F- 16 Kuparuk Well 3 F- 16 Kuparuk Well 3 F- 11 Kuparuk Well 3 F - 04 Kuparuk Well 3 F- 05 Kuparuk Well 3 F- 1 3 Kuparuk Well 3 N- 1 0 Kuparuk Well 3 N- 10 Kuparuk Well 3 N - 04 Kuparuk Well 3 N- 09 KuaPruk Fluid 30-14 Kuparuk Fluid 30-14 Kuparuk Fluid 3 M - 1 8 Kuparuk Fluid 3 F o I 6 Kuparuk Fluid 3 F- 13 Kuparuk Fluid 3 F- 13 Kuparuk Fluid 3 F o 13 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid 3 F- 08 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 16 Kuparuk Fluid 3 F- 13 Kuparuk Fluid 3 F- 16 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 4 Kuparuk Fluid Sub-Surface Pressure Survey Kuparuk Well Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Pressure Report Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re~ 3orr 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3orr 3oft 3ort 3oft 3oft 3oft ~ort Level Report 10-06-88 8-29-88 12-20-88 8-29-87 8-29-87 8-29-89 8-17-87 8-17-87 8-29-87 6-26-87 12-12-88 12-31 -88 6-11-87 6-11-87 9-01 -87 5-04-87 2-13-89 2-10-89 2-10-89 6-05-87 6-09-87 6-18-87 6-16-87 6-21 -87 5-O8-87 8~18-87 8-24-87 6-05-87 6-2/3-87 8-5-87 6-5-87 9-8-87 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casinc~ Casin( Casin~ Casin~j Casffti: Casing Tubing Casing Casing ~chorage 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku 3aruk Fluid Kuaaruk ,Fluid Ku )aruk Fluid Ku aaruk Fluid Ku )aruk Fluid Ku aaruk Fluid Ku 2aruk Fluid Ku 2aruk Fluid Ku aaruk Fluid Ku 3aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku 3aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku)aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Kui~aruk Fluid Acknowledged: Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Reaort Re2ort Re aort Reaort Re 2ort Re 2ort Re aort Re 2ort Re 2ort Re aort Re 2ort Report Report Report Report Report 9-11~87 12-06-86 9-11-87 10-11-87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & Gus Con:. ....... ~C~orage DISTRIBIJTION; D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. ~ Post Office Bo_ ,00360 Anchorage. Alaska 99510-0360 Telephone 907 276 12!5 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 3N-12, 3N- 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 Fractures and Stimulations 3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 3N-11, 3F-11 and 3N-8A 1 E-30 Perforation8 Failed MIT if you have any questions, please call me at 265-6840. Sincerely, G. B. Srr~llwood /~"¢~':~ Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 RECEIVED NOV 16 1988 .... ,~,~, ~oragt '. :,,.~''' . ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator .ARCO Alaska, Inc. 3o Address P. 12. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1562' FSL, 354' FEL, Sec. 29, T13N, RgE, UM At top of productive interval 1182' FSL, 1965' FWL, Sec. 29, T13N, R9E, UM At effective depth 1172' FSL, 1878' FWL, Sec. 29, T13N, RgE, UM At total depth 1157' FSL, 1739'FWL, Sec. 29, T13N, RgE, UM Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 67 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-5 9. Permit number/approval number 7-805 10. APl number 50-029-21537 11. Field/Pool Kuparuk River Oil Pool feet 7595' MD feet Plugs (measured) NONE 6402' MD feet Effective depth: measured 7482' M D feet true vertical 6318' MD feet Junk (measured) NONE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 80' 1 6" 232 Sx CSII 115' MD 3725' 9 5/8" 1070 Sx PF"E" 3764' MD & 290SX Class G 7530' 7" 300 SxClass G 7569' MD & 175 Sx ASI measured 7309', 7334', 7337', 7364'-7392' MD True vertical depth 115' TVD 3602' TVD 6382' TVD true vertical 6189', 6208', 6210', 6230'-6251' TVD 13. Tubing (size, grade, and measured depth) 2-7/8", 6.5#, 7207' MD Packers and SSSV (type and measured depth) Brown HB-1 @ 7137' MD Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure ~. he'" [)il & Gas Cons, C.o. mmis¢o~ ~d~ ,"~, - -. Representative Daily Average Production or Injection OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 529 770 0 1 2 0 0 100 Subsequent to operation 0 0 1300 I 0 7 5 1 6 0 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations.X Oil Gas Suspended Service Wi 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form ~0-404 Re~' 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc'-O Subs~iary of Atlantic Richfield Company JPBDT .-.. WELL ~/-5 IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME (2o ~,1 pca.'rE. CONTRACTOR /o~c ¢ - HEMARKS WELL SERVICE REPOR1 IDAYS DATE I-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather 1 Temp. Chill Factor I Visibility Wind Vel. Report ! °F °FI miles Signed knotsI / DEPARTMENT OF NATURAL RESOURCES / DIVISION OF OIL AND GAS / July 6, 1988 ENG ,o. BOX 70S4 SR GEOL ANCHORAGE, ALA ENG A~~ STAT John Wood, Area Landman ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-360 Dear Mr. Wood' In. your July 5, 1988 letter you requested extended confidentiality for the data from the Kuparuk River Unit development wells 3N-5, 3N-7, 3N-8 and 3N-8A. These wells are situated south of an unleased tract at Oliktok Point, U. S. Survey No. 4275, with surface reserved for the U. S. Air Force (see attached map). The 3N-7 and 3N-8A wells are scheduled to be released on JulY 7, and the 3N-5 well is scheduled for release on July 9, 1988. The 3N-8 well was released on April 14, 1988. On July 6, 1988 you and other ARCO staff members met with division staff to discuss your request. Following your written request, and after careful consideration of the discussion between our staffs, I am denying your request to extend the confidentiality of the 3N-5, 3N-7 and 3N-8A wells. Under AS 31.05.035(c). "If the commissioner of natural resources finds that the required reports and information contain significant information relating to the valuation of unleased land in the same vicinity, the commissioner shall keep the reports and information confidential for a reasonable time after the disposition of all affected unleased lands." Significant reports and information from the ARCO Oliktok Pt. No. 1 Well, as well as data from the 3N-4 and 3N-8 wells, are already available to the public. The data from the Oliktok Pt. No. 1 Well, situated directly between the unleased tract and the three wells in question, are particularly significant to the valuation of the unleased tract. There are already several wells which have been released to the public which provide a good data base for valuation; therefore, we do not think that the data from these three wells would make a significant difference to an interpretation of the geology in the valUation of the unleased land at Oliktok Point. There are several other wells in this area scheduled to be released within the next; year. So that you may evaluate any future requests for confidentiality extensions, we would like to advise you of our current leasing plans. January 1989 is the earliest month that the Oliktok Point tract could be offered for John Wood July 6~ 1988 Page 2 lease. The division is considering offering the tract in January 1989 if all manpower, noticing, ownership and other legal requirements can be met. If this timing does not prove possible, September 1989 will present the division's next practical opportunity to offer this acreage. The division received your request only one day prior to the release date of the data from the 3N-7 and 3N-8A wells. We encourage you to submit any requests for extended confidentiality not more than 90 days prior to, but at least 30 days prior to, any release date in order to provide sufficient time for request evaluation, consideration, decision and notification of Alaska Oil and Gas Conservation Commission (AOGCC). · By copy of this letter I am advising the AOGCC to proceed with' release of the ARCO Kuparuk River Unit 3N-5, 3N-7, and 3N-8A wells as previously scheduled. Sincerely, Attachment 1526E cc: C. V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR 1526E ~ "' I I PAR~ICIPA TI~ 0 0 0 I I r----'~ ~ ~ ..... 3 I I ~~o o DS-3R . ~o~ ~ o2-~ [-..: ---,' __ ~ ~. '~'~ __ - j / ~~s-~ ~r 30-02 / 3 .,.., .. o o o ~~ , ~-o, ~-' ~'~, ~~~~ .._ ~ ~~ o o ~------~m--- JM-OI JM-02 JM-04 I _ ~ 15 · ' ,r ARCO Alaska, Inr~ Post Office. x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' _. Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. The wells were both conversions and fractures as listed below. Well Action Anticipated Start Date 2A-3 Conversion 2A-6 Conversion 2A-7 Conversion October 19, 1987 October 19, 1987 October 19, 1987 3K-15 Conversion October 15, 1987 3N-4 Conversion 3N-5 Conversion 3N-11 Conversion October 15, 1987 October 15, 1987 October 15, 1987 3Q-5 Conversion 3Q-12 Conversion 3Q-15. Conversion October 15, 1987 October 15, 1987 October 15, 1987 If you have any questions, please call me at 265-6840. Sincerely, lwood Senior Operations Engineer GBS'pg'0117 Attachments RECEIVED OCT I 6 ]98l Alaska 0il & Gas Cons. Commission Anchorage cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA AL/-,,_..,A OIL AND GAS CONSERVATION COIv, MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [~ Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [/J Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 1562' FSL, 354' FEL, Sec 29 T13N RgE UM At top of productive interval ' ' ' ' 1182' FSL, 1965' FNL, Sec.29, T13N, RgE, UN At effective depth ].172' FSL, 1878' FWL, Sec.29, T13N, RgE, UN At total depth 1157' FSL, 1739' FNL, Sec.29, T13N, RgE, UN 11. Present well condition summary Total depth: measured 7595' MD feet true vertical6402, MD feet 5. Datum elevation (DF or KB) RKB 67 6. Unit or Property name Kuparuk River Unit 7. Well number 3N-5 8. Permit number Permit #86-26 9. APl number 50-- 029-21537 10. Pool KuDaruk River Oil P~l Plugs (measured;None feet Effective depth: Casing XX X;~X~XIX:X~K X X XX Conductor 80 ' Surface 3725' x xx ~rxt~'l~te Production 7530' xxx~-~xxxx Perforation depth: measured measured 7482' MD true vertical6318 ' MD Length Size feet Junk (measured)None feet Cemented Measured depth 16" 232 SX CSII 115' MD 9-5/8" 1070 SX PF"E" & 3764' MD 290 SX Class G 7" 300 SX Class G 7569' MD 7309', 7334', 7337', 7364' -7392' MD True Vertical depth 115' TVD 3602' TVD 6382' TVD true vertical6189, 6208' 6210' 6230'-6251' TVD Tubing (size, grade and measured depth) 2-7/8", 6.5#, 7207' MD Packers and SSSV (type and measured depth) Brown HB-1 fa 7137' MD 12.Attachments Description summary of proposal [] Convert a producer to a water injection well, 13. Estimated date for commencing operation October 15, 1987 Detailed operations program iS] BOP sketch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby ~certify that the foregoing is true and__correct to the best of my knowledge Signed ,/~¢~.,~ .~ '~.,~ ~'t,,tQ~/~~('') Title Sr. Operations Engineer Commission Use Only Conditions of approval Approved by so representative may witness I Approval Notify commission No. [] Plug integrity [] BOP Test [] Location clearanceI by order of DatelO/12/87 Commissioner the commission Date ,/E.~ Form 10-403 Rev 12-1-85 Submit in triplicate ...... STATE OF ALASKA AL, .(A OIL AND GAS CONSERVATION CC .... ,~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging E} Perforate ¢ Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360.. Anchorage, AK 99510 4. Location of well at surface 1562' FSL, 354' FEL, Sec. 29, T13N, RgE, UM 5. Datum elevation (DF or KB) RKB 67' 6. Unit or Property name Kuparuk Rivc_r Unit 7. Well number 3N-5 Fee~ ~¢ At top of productive interval 1182' FSL, 1965' FWL, Sec. 29, t_effective dep. th 172' FSL, 1878' FWL, Sec.29, T13N, R9E, UM T13N, R9E, UM T13N, R9E, UM 8. Approval number #86-26 9. APl number 50-- 029-21537 10. Pool Kuparuk River 0i] Pool 11. Present well condition summary..,.^., HD Total depth' measured /bgb true vertical6402' TVD feet feet Plugs (measured~lOne Effective depth: measured 7482' MD true vertical6318' TVD feet feet Junk (measured)None Casing Length Size Structural Conductor 115' 16" Surface 3725' 9-5/8" XX X X~texr~i~i;ete Production 7530' 7" x x XxL~rxeXX xx X Perforation depth: measured 7309', 7334' Cemented Measured depth True Vertical depth 232 SX CSII 115' MD 1070 SX PF-E 3764' MD & 290 SX Class G 300 SX Class G 7569' MD , 7337', 7364'-7392' MD 115' TVD 3602' TVD 6382' TVD true vertical6189, 6208' Tubing (size, grade and measured depth) ,,Packer~,~n¢ S_SS_V_ Lty_p.e and measured depth) [~ /l'5'f' MD ~rown H[~-I , 6210' 12. Stimulation or cement squeeze summary , 6230'-6251' TVD R E C E IV E D AUG 1 1987 Alaska 0it & Gas Cons. Commission Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf 344 BOPD 395 MCFPD Water-Bbl Casing Pressure 1425 psig 1350 psig 691BOPD 940 MCFPD 14. Attachments Daily Report of Well Operations 0 BWPD 0 BWPD Tubing Pressure 100 psig 100 DSia Copies of Logs and Surveys Run II 1.~. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/,~..~¢], ~85 Form 10-4-04 Rev.¢~2-1- Title Sr. Operations Engineer I Date/~//, Submit in ~uplicate ARCO Alaska, Inc~<~ Subsidiary of Atlantic Richfield Compar,. WELL NTI~CTOR REMARKS - WELL SERVICE REPORT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME J z.).5 - I?oo - 193o - 22,~o - p~ 9299- q$/4 4 '[--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALA,~ .A OIL AND GAS CONSERVATION CO~ ..... ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well L] Alter casing F1 Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order E-] Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 67 feet 3. 6. Unit or Property name Kuparuk River Unit 7. Well number 3N-5 8, Permit number Permit #86-26 9. APl number 50-- 029-21537 10. Pool Kuparuk River Oil Pnnl 11 Plugs (measuredNone . Address PO Box 100360, Anchorage, AK 99510 Location of well at surface 1562' FSL, 354' FEL, Sec. 29 T13N, RgE UM At top of productive interval ' ' 1182' FSL, 1965' FWL, Sec.29, T13N, RgE, UM At effective dep. th 1172' FSL, 1878' FWL, Sec.29, T13N, R9E, UM At total depth 1157' FSL, 1739' FWL, Sec.29, T13N, RgE, IJM · Present well condition summary Total depth: measured 7595' ND feet true vertical6402, ND feet Effective depth: measured 7482' MD feet true vertical6318, ND feet Casing Length Size XX X~Xr'/JCZO~)IK XX XX Conductor Surface Production xxxk-~xxxx Perforation depth: 115' 16" 3725' 9-5/8" Junk (measured)None Cemented Measured depth True Vertical depth 7530' 7" 232 SX CSII 115' MD 1070 SX PF"E" & 3764' MD 290 SX Class G 300 SX Class G 7569' MD measured 7309', 7334', 7337', 7364'-7392' MD 115' TVD 3602' TVD 6382' TVD true vertical6189, 6208' 6210' 6230'-6251' TVD Tubing (size, grade and measured depth) 2-7/8", 6.5#, 7207' MD Packers and SSSV (type and measured depth) Brown HB-1 @ 7137' MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Addinq perforations to currently perforated intervals. 13. Estimated date for commencing operation June 28, 1987 14. If proposal was verbally approved Name of approver L. Smith Date approved 6/29/87 15. I hereby certify that the foregoing is true and ,¢.,orrect to the best of my knowledge Signed ,/'~c?../~ ~ ~/'~/~r~?Title Sr. Operations Engineer Commission Use Only Date 7/16/87 Conditions of approval Notify commission so representative may witness I Approval No.? [] Plug integrity [] BOPTest [] Location clearanceI -~' Approved by ~turn~ Commissioner by order of / ~ ~, ~'~--l¢' cor. n ssion a,e Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, In~, Post Office uox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5936 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. 2A-12 CET. 3-8-86 6410-7007 · 3F-16 CET 1-13-86 7740-8443 2A-10 CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 3Q-7 CBL 2-15-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL '2-15-87 7843-9752 ___3Q-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-10 CET 9-4-86 4700-8118 'Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, I~. 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 DATE O'~' ~Z~ ,~D TRANSMITTAL # 5701a Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole Final Prints: Schl: One * of each 3N-5 3N-4 3N-3 5" DIL/SFL-GR 02-21-86 Run #1 0190-7593 2" DIL/SFL-GR 02-21-86 Run #1 0190-7593 5'~ Den/Neu-GR (poro) 02-21-86 Run #1 6980-7568 2" Den/Neu-GR (poro) 02-21-86 Run #1 6980-7568 5" Den/Neu-GR (raw) 02-21-86 Run #1 6980-7568 2" Den/Neu-GR (raw) 02-21-86 Run #1 6980-7568 Cyberlook 02-21-86 Run #1 6980-7568 5" DIL/SFL-GR 02-14-86 Run #1 2000-7896 2" DIL/SFL-GR 02-14-86 Run #1 2000-7896 5" Den/Neu (poro) 02-14-86 Run #1 4111-7870 2" Den/Neu (poro) 02-14-86 Run #1 4111-7870 5" Den/Neu (raw) 02-14-86 Run #1 4111-7870 2" Den/Neu (raw) 02-14-86 Run #1 4111-7870 5,, _Cyberlook 02-14-86 Run #1 7200-7840 DIL/SFL-GR 02-17-86 Run #1 1700-7986 2" DIL/SFL-GR 02-17-86 Run #1 1700-7986 5" Den/Neu (poro) 02-17-86 Run #1 7450-7960 2" Den/Neu (poro) 02-17-86 Run #1 7450-7960 5" Den/Neu (raw) 02-17-86 Run #1 7450-7960 2" Den/Neu (raw) 02-17-86 Run #1 7450-7960 02-17-86 Run #1 7450-7937 02-15-86 Run #1 4453-8718 2" DIL/SFL-GR 02-15-86 Run #1 4453-8718 5" Den/Neu (poro) 02-15-86 Run #1 8100-8695 2" Den/Neu (poro) 02-15-86 Run #1 8100-8695 5" Den/Neu (raw) 02-15-86 Run #1 8100-8695 2" Den/Neu (raw) 02-15-86 Run #1 8100-8695 Cyberlook 02-15-86 Run #1 8100-8671 Alaska 011 & Gas Cons, Gommissi,, Anchorage . Cyberlook 3J-16 5" DIL/SFL-GR Receipt Acknowledged: Date: Drilling*bi NSK Clerk*bl Ratkmell*bl D & M*bl Vault*films ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska. 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 DATE 07-14-86 TRANSMITTAL # 5701b Transmitted herewith are the following items. Please acknowledge receipt and return, one signed copy of this transmittal. Open Hole Finals Continued..., 3I-5. 5" DIL/SFL-GR 2" DIL/SFL-GR ~ ~i,??~?~' 5" Den/Neu ~.~ii .... ~ ,/../ 2" Den/Neu ~ 5" Den/Neu 2" Den/Neu .................................... ~. Cyberlook 2A-10 5" DIL/SFL-GR · '~ 2" DIL/SFL-GR ,, (poro) (poro) (raw) (raw) 5" Den/Neu-GR (poro) 2" Den/Neu-GR (poro) 5" Den/Neu-GR (raw) 2" Den/Neu-GR (raw) Cyberlook 02-09-86 Run gl '02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run gl 02-09-86 Run gl 02-09-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run gl 1500-8061 1500-8061 4950-8035 4950-8035 4950-8035 4950-8035 7350-8012 6680-7132 6680-7132 6680-7107 6680-7107 6680-7107 6680-7107 6680-7107 Receipt Acknowledged: Drilling*bi Alaska 011 & Gas Cons. C0mmlssic,: Anchorage Date: NSK Clerk*bl D & M*bl Rathmell*bl Vault*films ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ~ ..... ~ STATE OF ALASKA '-~ ALASKA L,,,L AND GAS CONSERVATION ~O,~,,MISSION ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Op. erator 7. Permit Number ARCO Alaska, Inc. 86-26 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21537 ,,, 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 354' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1182' FSL, 1965' FWL, Sec.29, T13N, R9E, UM 3N-5 At Total Depth 11. Field and Pool 1157' FSE, 1739' FWL, Sec.29, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 67' RKBI ADL 25521 ALK 2557 , 12' Date Spudded 02/16/86 13. Date T.D. Reached 02/20/86 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns 06/09/86~/, N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Diredtional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7595 'MD ,6402 'TVD 7482'MD,G318'TVD YES~ NO []I 1792 feet MD 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GCT, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, i6:: b2.5# H-40 surf 115' 24" 232 sx CS II 9-5/8" 36.0# J-55 Surf 3764' 12-1/4" 1070 sx PF "E" & 290 sx Class G 7" 26.0# J-55 Surf 7569' 8-1/2" 300 sx Class G ., 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7309 'MD 61 89 'TVD 2-7/8" 7207 ' 7137 ' 7334 'MD 6208 'TVD 7337 'MD 6210 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7364 '-7392 'MD 6230 '-6251'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached addem urn, dated 6/11/86, for fracture dat~ 27. N/A PRODUCTION TEST Date First Production j Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ · Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED J U L 10 1986 Alaska 0it & Gas Cons. Cornmission Anchorage ...... Form 10-407 * NOTE: Drilled RR 2/22/86. Well perf'd & tubing run 4/21/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/077 Submit in duplicate~ 29. ( 30. ' GEOLOGIC MARKERS FORMATION TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. ,,, Top Kuparuk C 7256' 16150' N/A Base Kuparuk C 7262' 6154' Top Kuparuk A 7287' 6173' Base Kuparuk A '7433' 6281' 31. LIST OF ATTACHMENTS Addendum (dated 6/11/86) 32. I hereby Certify that the foregoing is true and correct to the best of my knowledge (~ (/~/~/~ ~ Associ ate Engineer Signed ~ . ~t/,j~/ Title Date '7' 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: 6/09/86 3N-5 Frac'd Kuparuk "A" sand perfs 7309', 7334', 7337' & 7364'-7392' in 9 stages per 6/5/86 procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd annulus to 1900 psi w/diesel. Tst lns to 8300 psi; OK. Stage #1: Pmp'd 20 bbls 140° diesel w/5% Musol @ 4 BPM w/3570 psi Stage #2: 80 bbls gel/diesel spacer @ 16-20 BPM w/3570-5440 psi Stage #3: 19 bbls gel/diesel pre-pad @ 20 BPM w/1940-5280 psi Stage #4: 24 bbls gel/diesel w/1 ppg 100 mesh @ 20 BPM w/5280-5140 psi Stage #5: 128 bbls gel/diesel pad @ 20 BPM w/5140-4760 psi Stage #6: 19 bbls gel/diesel w/3 ppg 20/40 @ 20 BPM w/4760-4790 psi ("on fly") Stage #7: 40 bbls gel/diesel w/6 ppg 20/40 @ 20-18.5 BPM w/4790-5720 psi ("batch") Stage #8: 15 bbls gel/diesel w/7.5 ppg 20/40 @ 18.5-18 BPM w/5720-6000 psi ("batch") Stage #9: 44 bbls gel/diesel flush @ 18-20 BPM w/600-4900 psi Pmp'd 1000# 100 mesh & 16,950# 20/40 in formation leaving 270# 20/40 sand in csg. Load to recover 389 bbls of diesel. Job complete @ 1255 hrs, 6/9/86. Turn well over to Production. (Note: Production to rn post frac log.) Drilling Supervisor Date STATE OF ALASKA ALASK,. ilL AND GAS CONSERVATION COMMIo,51ON REPORT OF SUNDRY WELL OPERATIONS .. Operations performed' Operation shutdown ~ Stimulate ..~ Plugging ~ Perforate,~ Pull tubing ' Alter Casing ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX l(~l~Rf~ An~hnr~n~_ Al( 9951f~ 4. Location of well at surface 1562'FSL, 354'FEL, Sec.29, T13N, RgE, UM At top of productive interval 1182' FSL, 1965'FWL, Sec.29, T13N, R9E, UM At effective depth 1166'FSL, 1814'FWL, Sec.29, T13N, R9E, UM At total depth 1157'FSL, 1739'FWL, Sec.29, T13N, R9E, UM 11. present well condition summary Total depth: measured 7595 true vertical 6402 Effective depth: measured true vertical 7482 6318 Casing Length Size Conductor 80 ' I 6 Il Surface 3727' 9-5/8" Production 7534' 7" 5. Datum elevation(DF or KB) RKB 67' 6. Unit or Property name ~',,n~rll~ I~iv~r IIn'i~ 7. Well number 3 N- ~ 8. Approvalnumber Permit #86-26 9. APInumber 50-- 029-21537 10. Pool Kuparuk River Oi 1 Pool Perforation depth: measured 7309 'MD 7334 'MD true vertical 61 89 ' TVD 6208 ' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 7207' Packers and SSSV (type and measured depth) HB-1 pkr ~ 7137' & FVL SSSV @ 1792' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth Conductor report 115'MD not available. 1070 sx PF "E" & 3764'MD 290 sx Class C 300 sx Class G 7569'MD 7337 ' MP 7364' - 7392 'MD 6210'TVD 6230' - 6251 'TVD 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 True Vertical depth 115'TVD 3598'TVD 6382 'TVD OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations X 15. I hereby certify that the foregoing i8 true and correct to the best of my knowledge Title Tubing Pressure Signed Form 10-404 Rev. 1 Copies of Logs and Surveys Run X /~C~S~r'¢E~ Associate Engineer (DAM) SWO/O02 Date Submit in Duplicate Feet ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Filial Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25521 Auth. or W.O. no. T t e AFE AK1126 Completion Nordic #1 API 50-029-21537 Operator jlA'R'C°' W.I. J ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ~Date Hour Complete 4/20/86 Date and depth Complete record for each day reported as of 8:00 a,m. 4/20/86 thru 4/21/86 4/22/86 Old TD Released rig State Alaska Total number of wells (active or inactive) on this cost center prior to plugging and I iabandonment of this well I 2300 hrs. IWell no. 3N-5 IPrlor status if a W,O, 7" @ 7569' 10.1 ppg NaCl/NaBr brine Accept ri~ @ 2300 hfs, 4/20/86. ND tree, NU & tst BOPE. Perf "A" sand f/7364'-7392' w/4" guns, 4 spf & 7309', 7334' & 7337' w/4" gun & 1 spf. Rn 2-7/8" single compl string. 7" @ 7569' 7482' PBTD, RR 6.8 ppg diesel in tbg & ann Rn 231 its, 6.5#, J-55 EUE 8RD AB Mod IPC tbg w/SSSV @ 1792', HB-1Pkr @ 7137', TT @ 7207'. Set pkr, tst tbg, ann & SSSV; OK. ND BOPE, NU & tst.tree. Displ well to diesel. Set BPV. RR @ 1745 hrs, 4/21/86. INew TD PB Depth 7482 ' PBTD Kind of rig IDate 4/21/86 1745 hrs. Rotary Classifications (oil, g. as, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing ., Kuparuk Sands Potential test data Well no. Date Reservoir I Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P, Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. Date ~, [Title Drilling Supervisor STATE OF ALASKA ALASKA O~,_ AND GAS CONSERVATION CO~v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ,/~ OIL [] GAS [] SUSPENDED~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-26 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21537 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 354' FEL, Sec.29, T13N, R9E, UM (approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3N-5 At Total Depth 11. Field and Pool TO be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. -"' Kuparuk River 0i 1 Pool 67' RKBI ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D, Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 02/1 6/86 02/20/86 02/22/86I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+~-VD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7595 'MD 7482 'MD YES [] NO~(I N/A feet MDI 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal 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 115' 24" Conductor report not acai]able. 9-5/8" 36.0# J-55 Surf 3764' 12-1/4" 1070 sx PF "E" & 290 sK Class G 7" 26.0# J-55 Surf 7569' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 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 Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED~1~ OIL-BBL GAS-MCF WATER-BBL OI"L GRAVITY-APl (cor'r) Press. 24-HOUR RATE -28. 'CORE DA'TA -. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 DAM2/WC09 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. ~ FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS We]] Hi story 32. I hereby certify that the foregoing is t~'ue and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History- Initial Report- Daily Instructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty. paris, h or borough North Slope Borough ILeaseADL 25521 or Unit ITitle Drill State Alaska Kuparuk River lWell no. 3N-5 Auth. or W.O. no. AFE AKl126 Doyon 9 API 50-029-21537 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUnspudded IDate 2/16/86 IH°ur 0300 hrs. IPri°rstatusifaW'O' 2/15/86 thru 2/18/86 2/19/86 2/20/86 2/21/86 Complete record for each day reported Date and depth as of 8:00 a.m. The above is correct Signature For form preparation and dis~ibution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 56.24% 9-5/8" @ 3764' 3785', (3670'), Cmt'g 9-5/8" Mx'g new mud ~ccept rig @ 2200 hrs, 2/15/86. NU diverter sys. Spud well @ 0300 hrs, 2/16/86. 16' @ 115'. Drl 12¼" hole to 3785', C&C, POOH. RU & rn 95 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 3683', FS @ 3764'. Cmt 9-5/8". 2117', 2.1°, N73.75W, 2116.97 TVD, 2.00 VS, .6ON, 2.06W 2432', 9.6°, S75.24W, 2429.65 TVD, 38.03 VS, 6.30S, 37.66W 2937', 20.5°, S87.25W, 2915.5 TVD, 172.7 VS, 22.3S, 171.5W 3444', 39.0°, S82.25W, 3355.7 TVD, 419.1 VS, 47.4S, 416.6W 3725', 41.3°, S83.25W, 3569.1 TVD, 601.7 VS, 70.8S, 597.9W 9-5/8" @ 3764' 4455', (670'), Drlg Wt. 8.9, PV 3, YP 2, PH 9.5, WL 16.2, Sol 4 Cmt 9-5/8" w/1070 sx PF "E" w/5#/sx Gilsonite & 290 sx C1 "G" w/2% CaCi_. Displ using rig pmp. ND diverter, NU & tst BOPE. RIH, DO crt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 4455'. 3984', 42.8°, S82.25W, 3761.4 TVD, 774.9 VS, 92.7S, 770.0W 4300', 42.6°, S81.25W, 3993.7 TVD, 988.8 VS, 123.4S, 982.1W 9-5/8" @ 3764' 6717', (2262'), Drlg Wt. 9.2+, PV 5, YP 2, PH 9.0, WL 8.0, Sol 6 Drl & surv 8½" hole to 6717'. 4712', 42.4°, S82.25W, 4297.4 TVD, 1266.5 VS, 163.4S, 1257.6W 5184', 42.7°, S85.25W, 4645.1TVD, 1585.5 VS, 198.1S, 1574.8W 5684', 44,0°, S86.25W, 5008.7 TVD, 1928.7 VS, 223.6S, 1917.1W 6092', 43.5°, S86.25W, 5303.4 TVD, 2210.8 VS, 242.0S, 2198.6W 9-5/8" @ 3764' 7595', (878'), Rn OHL Wt. 10.0+, PV 16, YP 8, PH 9.0, WL 6.0, Sol 11 Drl & surv 8½" hole f/6717'-7595', short trip, C&C, POH. RU & begin rn'g logs. 6345', 45.0°, S87.25W, 5484.7 TVD, 2387.3 VS, 252.0S, 2374.9W 6781', 44.0°, S86.25W, 5795.6 TVD, 2692.8 VS, 269.3S, 2680.0W 7157', 42.6°, S86.25W, 6069.3 TVD, 2950.7 VS, 286.2S, 2937.3W Drilling Superintendent AtlanticRichfieldCompany '~' Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish .State J Alaska North Slope Borough / Alaska Field Lease or Unit Well ~N-5 Kuparuk River ADL 25521 Auth. or W.O, no, ~Title AFE AKl126 I Drill Doyon 9 API 50-029-21537 [A.R.Co. W,I. ~Total number of wells (active or inactive) on thisI Operator ~/~'CO Alaska Inc. 56.24% Icost center prior to plugging and labandonment of this well I IH IPri°r status if a w'O' Spudded or W.O. begun Date our 0300 hrs. Spudded 2/16/86 Date and depth as of 8:00 a.m. 2/22/86 Complete record for each day reported 7" @ 7569' 7595', (0'), RR Wt. 10.0 ppg Brine Rn DIL/GR/SP/SFL f/7595'-3764', cont w/GR to surf. Rn FDC/CNL f/7595'-6986', CAL f/7595'-6180'. Make wiper trip, C&C, POOH. RU & rn 177 jts, 7", 26#, J-55 BTC csg w/FS @ 7569', FC @ 7482'. Cmt w/lO0 sx 50/50 Poz C1 "G" w/9% Bentonite, .85% CFR-2, .7% Halad-9 & 5% salt, followed by 200 sx C1 "G" w/.6% FDP-C344 & .25% HR-5. Displ using rig pmps, bump plug. CIP @ 0645 hrs, 2/22/86. ND BOPE, set pack-off & tst; OK. RR @ 1000 hrs, 2/22/86. Old TD Released rig 1000 hrs. Classifications (oil, gas, etc.) O±1 INew TD I PB Depth 7595' 7482' IDate IKind of rig 2/22/86 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production ..... Oil on test Gas per day Pump size, SPM X length I Choke size ¥.P'i C.P. Water % GOR I Gravity Allowable Effective date corrected The above is correct Signature For form pre~ara~io-n and ~istributio~, ' ' see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ~UB.~URFACE DIRECTIONAL ~URVBY J~UIDANCE [~ONTINUOUS J-~'] OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED 3N-5' (1562'FSL, 354'FEL, S29, T13N, R9E) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71386 Loaaed By: Date 06-APRIL-86 Computed PEPPEL HALSTEAD CU $ T~3MF: R' L Z S T Z :"J C-', ~ETH]DS 3F C3~DUT&TZO~ T]OL L3C&TZ3N: iNTERPD=~TiDq: VERTICAL S CT.T3~i: ~ORlZ. 3mST. 'OF S']UTH 3O 4EST ARCO ~L~SK4, INC. 3N-5 KJPARJK NgRTH SLOPE,ALaSKA CgMPUT4TIgN DATE: INTERPOLATED VALUES FOR EVEN 100 ~E:T OF TRUE SU~-SEA ~E~SURED V£RTIC~L VCRTI'hL DEPTH DEPT~ DEPTH 0.00 0.00 -57.00 100.00 100.00 33.00 200.00 ZO0.O0 133.00 300.00 300.00 233,00 ~00.00 39~.9~ 332.99 500.00 499.98 432.9~ 600.00 599.97 532.97 700.00 599.~5 632.95 800.00 799.94 732.~4 900.00 899.~3 832.93 lO00.O0 99~.~Z 932,92 llO0.OO 1099.gl 1032.91 1200.00 1199.~0 i132.~0 1300.00 1299.~9 1232,~ 1400.00 1399.~9 1500,00 1~99.88 I~32.8~ 1500.00 1599,~7 1532.~7 1700.00 1699.~? 1632,87 1800.00 1799,~6 1732.86 1900.00 1899.B5 1832.~5 2000.00 1999,53 1932.83 ZlO0,O0 2099.~2 2032,82 2200.00 21~9,55 2132.65 2300.00 2299.06 2232.05 2400.00 2398.3) 2331,09 2500.00 2496,61 2429,6i 2500.00 2594,29 2527.2~ 2700.00 2690.B7 2523.87 2800,00 2786,32 2719,32 2900.00 2880,93 2B13,93 COURSE V:~TiCaL DOGLEG DEVIATiSN 4ZI~UTH SECTIgN S=V-~ITY q~N O~G ~iN =E~2T g~S/lO0 0 0 N 0 0 ~ 0.00 0 11 N 13 21 5 -0.15 0,55 0 19 N 17 37 ~_ -0,2~ 3.15 U 26 bi 45 25 = -0,!$2 0.30 0 46 ~1 43 55 c -1,45 0,31 0 57 N 56 ~7 i -2.73 0.23 0 31 N 52 37 ~ -4,16 0,0~ 0 51 N 64 35 ~ -5.53 0,27 O 49 N 63 41 =,. -.5.90 0.2'3 O 51 N 50 i ~ -8.2a 0.13 0 50 N 57 17 ~ -9,56 0.14 0 52 N 54 Z$ 7 -10,85 C,11 0 .~2 N 23 51 '~ -12.94 :3,25 9 3~ N 15 3& i3.1~ u.O~ 0 3 ~ N 5 21 E -13.69 9.i2 0 3'3 ~ 7 30 : -13,B7 O. 13 0 49 W 4~ 55 t -14,59 0.3~ I 1 N 55 4~ E -iq,09 0.2! 1 O 5 7 11 13 1 ~9 21 33 37 5 N ~:) 43 E -17.73 50 t',J~+5 45 N -1~.~! 3.72 I1 S B'3 42 4 -i3.7~ !0 S 7~ ! W -3.12 1.66 ~7 S 70 ~ 4 10.3.~ 1.93 2 S 7~ 40 ',,1 27.0~ 35 S ?1 al ~.~ -9. 34 la S .3i 31 W 7~.17 ' ~ S ..~4 ~4 W 134._ · ~z i. )n_ 3000.00 2974.42 2'907,42 3100.00 3066,12 29~9.12 3200.00 3155.15 308~,15 3300.00 3240.49 3173.4'9 3400.00 3321.50 3254.59 3500.00 3398-97 3331.~3t 3600.00 3474.58 3407,53 3700.00 3549,74 3800,00 3615,09 3558.09 3900.00 3701.03 3534.03 PAGE 1 OAT= OF SURV~-Y: 26 M~,R 86 K=LLY SUSHINS 5LEV4TION: ENGINEER: PEOmEL 57.00 FT R~CTANGUL~D, COORDINATES HDRIZ. NOR'TH/S3OTH E4ST/WEST DIST. 0.00 N 0.00 E 0.00 0.39 N 0.14 E 0.16 J.57 N 0.20 E 0.60 ! 0~ N 0.5~ ~' 1,gO 1. ~9 N 1. 31 ~ 2, 30 2.S7 N 2.31 E 3.81 3.54 N '3.3B 4,90 q 6,54 a ~!.17 5,53 DEPARTURE ~ZIMUTH ~S MIN 6.43 N 9,3'~ E 11.13 7.30 N 10,34 E 12,65 5.20 N 11.43 E 14.07 9.25 q 1!.99 E 15.15 10.:~]._, N 12.35 ~ 16.03 11.55 N 12.59 E 16.95 12.42 N 12.76 ~ 17.31 !4.53 N i:~.5'~. = 19. ~8~ 15.~5 N 14.92 ~ 21.55 16.57 N 15,53 E 23,41 17. ?'r3 N 17.50 E 2a,66 . = 21.54 17 61 N 12,40 14.34 N 1.}6 t 14,97 1!3.41 N Il.lB W 15,28 5.55 N 27.00 W 2,3.15 1.7~ N 40.63 W 4~.. 55 ,.Z.O'~ S 74.23 W 74.26 6.23 S 103.72 W 103,91 I0.,3':? S 135'88 W 135,25 13.19 S 171.21 W 171.71 17.13 S ZlO.~5 W 211.54 23,~5 S 255.50 W 255.'~2 31.75 S 307.28 W 40,~4 S 365.21 W 367.43 50.~0 S 427.69 W ~30,61 62.09 S 492.01 W ~95.91 7~.16 S 556, 55 W 561, ~7 95.49 S 62!.51 W 627.46 ~5.52 S 535.72 W 592.49 COMPUTATION D~TE: ARCO ~LASK~, INC. 3N-5 KUPARUK NDRTH SLOPE,.~L&SKA DATE O~ SURVEY: 26 MAR 36 K~LLY '~USHING ELEVATION: ENSIN=E~: OEPO=L 57.00 FT TRU~ IE&SURED VERTICAL DEPTH D~PTq iNTE2POLaTEO VaLUS3 FOR SJB-S~ COJ~S~ V~RTiC&L D:VZ&TZJN &ZZMUTH D~TH D~G ~IN D~G EVSN 100 V~RTIC~L S~CTiON F2~T FE~T OF DOGLEg S~VERITY ~,~SU ~ECT NJRT RE HI ',"3 D~2PTH GtJL,~R C93ROIN~TES H3RIZ. SO:JTM "'~ST/WEST giST. T F~CT OEO~RTURE ~ZIMUTH DEL3 MIN 4000.00 4100.00 4200.00 4300.00 4~00.00 4500.00 4600.00 4700.00 4800.00 ~900,00 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6~00 6500 6600 6700 6800 6900 70~0 7100 7200 7300 7~00 7500 7595 ,00 ,go .00 ,00 ,00 ,00 .00 ,00 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 .O0 .03 .00 .00 .00 .OO 3775.03 3848.57 3922.1B 39 '95 · 74 4069.34 4143.00 4216.81 4290.70 ~364,51 4438,54 ~512,8~ 45~7,11 ~660.77 4734.38 4808.03 4881,90 4955.5S 5027.53 5099.59 5171.~0 5244,24 5316,57 5389,10 5460.92 5531.53 5602.52 5673.75 5745.27 5817.05 5889.35 s Z.os 6034.98 6108,50 5182,¢1 5256.55' 5330.92 6401,57 3703,03 42 39 3781,57 42 36 3855,15 42 37 3928,74 42 37 4002,34 42 33 4076.00 ~2 31 ~149,~ 42 Z1 ~223.70 42 21 4297.61 42 17 ~371,54 42 11 4a45,84 ~1 5') ~520,11 42 i4 4593,77 42 39 4667,3~ 42 33 4741,03 42 28 4314,90 42 22 488~,53 43 12 4960,63 4~ 2 5032,59 43 53 5104.80 43 ~0 5177.24 ~3 33 5249,67 43 30 5322,10 43 ~O 53)3,92 44 ~6 5454,60 44 54 5535.52 4~ ~4 5505.75 44 ~0 ~678.27 ~ 14 5753.05 ~ 53 5822.35 43 2g 5595.05 43 1~ 5967,:~3 ~2 50 6041,50 42 27 6115,41 42 12 61~9.55 41 53 6253.}2 41 55 6334.57 4! 56 758,17 925,67 393.09 960,5~ 1027,9.5 1095,30 !162,49 l?~A 7n 1363,66 1430,41 1497,11 1564,54 153Z.27 1757.30 l~m4 77 I~0~,07 2042.65 *111 55 22~'~,43 £319,90 '~'~ 74 ~ ~..~ . . . 24,~0.24., 2~30.43 2:975.07 3011,1J 337{.27 314'5.0~ 320 _~. 55 0,53 0,12 0,22 0 · 0,13 0.2~ 3, i 0 O, 13 0,14 0.!0 0,17 3,35 0 · 12 0,1 7 2 · 3 '} :3. t 7 ,3.15 3,13 O. ZO 3.45 0.4~. i3. 55 0.33 O. 2: 9.57 3 · 7') 0.92 O · 30 107, 119 · 130, 14!, 153. 164. 176, 1:37. 19 '~, 21J. !21 . :232 · 241. 249 · 257 · 265. ~73 · Z q 0 . 2~7. 294. 301 · 316 · 322 · 3'~7. 33~. 337 · 3~3. 34.~. 353. 362 · 369 · 376. 333. 3 '~ 0. 397. 92 S 752.02 W 75').72 11 S ~15o~5 W 827.47 44 S 385.59 W ~95.14 90 S 932.35 W 962,86 35 S 101~9,07 W 1030,54 35 S 1083,71 W 1093,16 12 S 1152,22 W 1165,51 53 S 121~,6~ W 1232,99 72 S 12~5.j7 N 1300,34 O1% ,1351.3~ W 1367.57 3:~ S 1417,41 W !¢3~,59 53 S !483.44 W 1501,55 '3~ S 1550,48 W 1569,15 4~ % 1517,68 W 1536,80 ~5 S 1684,30 N 1704,36 ~1 S 1751,7~ W 1771, 7:~ 39 $ 181~, ~! W 1~339,37 :91 S 1~87,:35 W 1903.64 ~3 S 195,5.94 W 1978.00 ~1 S 2025.79 W 2047,11 35 S 1334,35 W 2115.99 97 S 2162.93 W 2184,3:3 06 S 2231,51 W 2253,78 El S 2300,~1 W 232~,27 30 S 2371,37 !4 2393,85 41 S 2441,69 W 2464,21 70 S 2511,68 W 2534,!~ ~3 S 2581,35 W 2504.09 49 3 2650,69 W 2573.53 ~a S 2719,47 W £7a2,57 5S S 2787.82 W 2~11.30 37 S 2855.89 W 237~.63 15 $ 2923.34 W 2347.44 03 S 2990 34 W ~ . ~014.77 23 S 3057.08 :4 3081.~3 32 S 3123.52 W 3143.72 5~ 9 3186.63 W 3212.22 S 31 50 S 31 43 3:31 37 S 31 31 S ~1 26 S 81 21 S 31 1~ S B1 15 S 31 12 3 81 9 W W W W W W B1 47 W 81 52 W 31 56 W 32 1 W B2 8 W :32 14 'N 8~ '~0 W 9! 25 W 32 29 ;4 $2 32 W S B2 35 W S 32 37 N S 32 40 N S 82 42 N S ,32 43 W S 81 7 ~4 S 81 5 W S gl S 81 13 w. S 31 15 iq S ~1 22 W '3 31 25 ,4 S 81 32 W S BI 37 N S 31 43 W ARCO ALASKa, INC. 3N-5 KUP&RUK N3RTH SLOPE, AL~SK'~ TRUE E&SURED VERTICAL DEPTH DEPTH 0.00 0.00 1000.00 999.92 Z.O00.O0 1999.33 3000.00 2974.~Z 4000.00 ]775.03 5000.00 4512.34 6000.00 5244.24 7000.00 5952.~5 7595.00 $401.57 COMPUTaTI2N gAT:: INT=RPSL~,TED V~LJES F-~]R EVEN 1 S US-S ~ C JURE E V ERTiCA VERTICAL ]':::VIaTI]N AZi~UTr! S~:CTZO -57.00 g32.92 1932.53 c907 .~ 370~.03 5177.24 5335.05 6334.57 0 0 N 0 0 E 0.0 0 50 N 57 17 E -9.5 1 6 }! 59 ~3 ~ -17.7 21 54 S 95 15 W 171.7 42 39 S ~0 2~ W 75~.1 41 5~ S $0 11 W i430.4 4~ 33 S ~4 6 '4 ~111 ~ 43 1~ S $4 20 W 2307.6 L D']GLEG SEVERITY 'O~S/IO0 0 .O0 0.14 0.20 2.54 ,). 17 i) . 20 .1.09 ME .~ SIJ~ 6. 15. 13. 137. 22i. 301. 362. & ,] ~.. ;i'TE C~. SU"VEY:, -.. ~.~6 ~.~a,q, 86 ~LLY BUSHING ELEVATION: 57.00 FI '=NGI'q:'ER: PEPPC..L GULA~ COO'RDI{'4AT=S HSRIZ. OEP&RTURE SOUTH EAST/WEST D!ST. AZIMUTH T FEET cm¢'T 'D~(3 N~iN O0 N 0.00 E 0.00 N 0 0 E 43 N 9.08_= 11.13 N 54 42 E 57 N 16.53 _ 23.41 N 4~ 55 ~ !0 S 171.,21 W 171.71 S ~5 37 N ~2 S 751.0£ W 759.'72 S 31 50 W 3'~ S 1417.41 ~4 1.~34.59 S 31 ? W 35 5 2094.B6 ~ 2115.99 S B1 47 ~ {5 S 27~7.~2 W 2{11.30 S 82 35 W Sa S ~1~$.6B bi ~2!1.2Z S 82 45 W ARCO ALhSKA, INC. BN-5 KUPARUK NORTH SLOPE,ALASKh CO~DUT~TIDN ZNTZRDJLAT~D VALUES FDR TRUE SUS-S2A E~SURED VERTICAL VERTICAL DEPTH DEbT 9 OE~' TH 0.00 0.00 -67.00 67.00 61.00 0.00 157.00 157.00 100.00 257,00 267,00 200,00 367.01 367.90 300.00 467.02 467.00 567.D3 567.00 500.00 667.0~ 667'.00 600.00 767.05 767.00 700.00 857.05 867.00 ~00.00 967.08 967.00 900.00 1057.D9 1067.00 lOOO.O0 1157.10 1167.00 1100.00 L257,11 1267,00 1200,00 L367.11 1367.00 1300.00 [467.12 1467.00 i~00.00 L567.12 1567.00 L667.13 1667.00 1600.00 L767.14 1757.00 1703.00 [~67.15 1867.00 L957.16 1967.00 1900.00 ~067.1~ 2067.00 2000.00 ~167.24 2167.00 2100.00 ~267.71 2267,00 !368.56 2357.00 2300.00 !469.1~7 2467.00 2400.00 ~571.~8 2567,00 2500.00 !675.15 2667.00 2609.0D !779.58 Z767.00 2700.00 !885.23 2567.00 !992.01 2967.00 2900.00 ~lO0.gB 3067.00 3009.03 ~213.65 3167'00 31~0.00 ~332.12 3267.D0 320J.00 t455.32 3367.00 3300.00 ~589.92 3467.00 ~722.95 3567.00 3500.09 ~855.07 3667.00 3503.00 1989.07 3767.00 3700.0~ ~125,0~ 3867.00 380D.00 COURS~ OEVIaTIJN AZiMUTq D~G MIN D=G '0 0 N 0 O -- 0 14 N 69 33 0 18 N 5 44 ~ 0 21 N 38 53 c 0 ~Z N 42 28 ~ 0 54 N 5a 22 E 0 ~1 N 62 57 ~ 0 50 N 55 15 O 5! N 59 7 ~ 21 25 41 41 40 42 O~T5: S-ADR-.~6 EVEN 100 F~ET OF P~GE 4 DaTE DF SURVEY: 25 M&R B$ KF. LLY BUSHING ELEVATION: =NG!NEER: PEPP=L ~ cCT&N'UL~R V:RT'IC~L OOGLE'; SECTION :SEVE~.ITY NOITH/SOUTH FEET DzS/iO0 FEET 0.00 O.O0 -0.07 0.51 -0.19 3.20 -0.44 O. 2~ -1.13 0.1~ ~ ~' 0 - -3.70 ~..I'? -5,08 0.12 -o.45 0.10 -7.7'n ].!S 0.00 O.OZ 0.39 O. '? ! 1.53 3.41 4.07 4.70 5.~B 57.00 FT -17.20 ].12 16.2 -la 3~ 3 0~ 17.! -i6.34 5.3~ 17.8 -5. ~, 2.19 15.9 5.~i 2.09 11.) g!. 60 ! · 92 5.9 ~i.9~ g.i~ 2.7 ~7.32 ~.~ 1.0 97. 60 i. 55 5.~ i31.~4 I.;~7 COORDINATES qOqiZ. DEPARTURE EAST/WiST DIST, ~ZIMUTH FEET FEET DES MiN 0.00 E 0.00 0.07 E 0.07 'J.l$ E 0.42 0.37 E 1.01 E 1.89 Z Og 3.~5= ~ 4.35 4.7B E 6.27 6.10 ~ 7.70 7.39 ! N ! N 1 .N ! N 1 N ~].67 2 13,64 9.'93 '~ i2.15 11.15 E 13.56 11.52 E 14.~0 1Z.24 ~_ I5.79, ~_. 52 : 16.6B 12.71 E 17.55 12..B1 ~ 18. 33 1'3.~5,. m. 19.~2 t4.~4 E 20.9'7 4 N 2. N 5 N 3 N ~ S 15.)$ ~ 2Z.7B 17.53 = 24.50 5.55 E 15.91 · 6.77 W 13.7~ 22.21 W 23.!6 67.44 W 67.45 97.48 W 97.63 130.99 W 131.3a 12.~7 17.15 15.0! 76. '~! ~1.59 .~. ~2i.nO 168.26 W 16~3.75 211,Z6 W 211.96 262,51 W 263.70 325,22 W 327.03 401.29 W ~'33.59 571.'75 W 575. ~) 6~6.31 W .563.16 7a4. 70 W 752.31 ~35. 57 W B44. P ~G~ 5 ARCO ALASKA, INC. 3N-5 KUPARUK NORTH SLO PE,AL~SK~t iNTerPOLaTeD V~LU2~ -OR 5'VEN !00 4E4 D TRUE SU:~-S E'~ SURED VERTICqL V:RT!~'~L EPTH O~_PFH DE~TH C~:URS :~ VF=RT_. I~'<, 4L 3-VI&TiDN AZIMUTH SECTION DE':3 ~11'5t D =G ~iN FEE-T $E~T J= SU~-SEA 3USLSG ~CTAN $~V~ZTY NDqTH/ S;1TE O? SU?,¥!Y: 25 ~l~q ,~5 K-LLY ~UStIN~' ~ ELEVATION: G!JL~R ~,:.OIN~TES SOUTM EaST/W~ST T F~T HORiZ. DI.SF. 67.00 FT- OEP~RTURE ~ZIMUTH JE.G MIN 42 43 45 46 48 49 50 52 53 54 50.9~ 3957.00 3900.00 96.82 4057.00 ~+000.00 32.55 a167.00 4103.00 67.9~+ ~267.00 G200.00 03.23 4367.00 38.28 4457.00 72.88 4557.00 ~+500 .gO 08.45 4667.00 ~+500.03 44.28 4767.00 4700.00 79.83 4857.00 4800.00 42 37 S 80 15 W 934.21 42 33 S 80 i2 W 1025.82 42 !7 S 80 i~ N 1117.20 42 22 S 8~ 22 W !20{.10 42 !7 S 80 24 W 1!9~.87 42 8 S ~0 14 N 13;~9.26 ~2 3 S ~0 37 W 1473.95 42 38 S 83 ~ W 1570.35 42 32 S ?,3 13 W 1562.18 4~ 2~ S R~ 5 W 175~.6:~ 3.05 J.15 0.30 O. i ~ u. ~.6 i. 51 0.30 0.05 0 · 25 137. 152. l. sg. lq3. 1 '.-) '?. ll~. 229. 242. 253. 263. ~6.28 93 S 1016.95 54 ~ 1107.~0 ~3 S 1197.36 O5 S 1287.22 35 S 1'375.69 57 S 1465.~6 06 S 1556.i7 O! S 16a7.~1 ,~ S 173S.27 936.42 S 81 33 W 102B.39 S 81 26 W 1120.15 S 81 20 w 1211.40 S 31 16 W 1302.52 S 81 12 W 13~3.27 S 81 .3 W 1~81.35 S ~1 5 N } 1574.?~,3 S 31 9 ~ i656.72 S 81 16 N 175,]~.19 S ~1 22 N 56 57 58 6O 61 6~ 65 67 70 71 72 74 75 75 15.77 4957.00 ~909.00 54.74 5067.00 5000.00 93.35 5167.00 510O.O0 31.42 5267.00 5200.00 69.45 5367.00 5303.00 08.59 5467.00 5400.00 49.92 5567.00 5500.00 90.53 5667.00 560~.00 30.35 5767.00 5700.00 69.15 5867.00 5800.00 06.81 5357.00 5900.00 43.59 5067.00 6000.00 79.1¢ 6157.00 5100.00 14.06 6267.00 5230.00 48.32 5367.00 530J.00 95.00 5401.57 533~.~7 43 29 S 53 32 ;,,~ I~45.64 4'3 57 5 $4 16 W 1942.10 43 ~l S ,~4 i0 W 43 37 S ~ 4 W 2133.24 43 37 S ~ 5 'J 222%:.35 44 52 .5 35 45 W 2'325.07 44 ~9 S ~5 50 'W 2424.93 4~ 31 S 35 35 W 2523.79 44 I ~ S 3~ O W ~6~1 50 43 .3~ S ga 35 W ',27!7.77 2.01 0.20 0.17 0 · .31 0 · I? 1.21 0.17 0 · 77 J. 40 0 . ~ ':~ 3.~5 ~7~. 2 ~ ~ · ~ ~ 4 304. 313. ~2~ 337. 35'3. 353. 37 Z. 3~1 · 391. ~+01 . ~2 S 1,32').71 14 1859.24 70 S 1925.70 W 1~46.63 34 S ZO21.Z1 W 204i.33 08 S 2115.90 W 2137.54 90 5 2210.53 W 2232.71 76 S 2396.B6 W 2329.33 19 S 2505.05 W 2527.65 15 5 2602.45 w 2625.24 94 S 269S.~2 W 2721.44 02 S 2792.47 W ,2S15.97 33 S 2B85.32 W 2909.2~ 56 S 1976.37 W 300J.73 25 S 3055.42 'J 30'~1.2~ ;'~3 S 3155. /5 w 3181.15 64 S 3186.63 'd 3212.!2 81 27 W 81 35 W ~1 4,2 W ~1 49 W 31 55 ~ S 82 2 W ;32 11 W 32 20 W ,32 26 W 82 '31 W S 82 35 W S 32 3~ W S 82 41N S 82 43 J S ~2 45 W S 32 45 / ARCO ALASKA, INC. 3N-5 KLIPARUK NORTH SLOPE,AL~SK4 MARKER TOP KUPa~RUK ~ ,,,,, B~SE KUP~RUK C TOP KUP~RUK & BASE KUPARUK ~ PBTD TD VALUES FOR ._,:LOW K~ 72_56.00 72~2.00 ~.,~7. O0 74-33. O0 7~32.00 7595.00 DATE: uHOSEN FROM K~ 6149.90 6154.3,~ 5172.81 6317.53 6~0!.57 TV9 ! S :5 2 ' SU~-SE~ 5087.34 5105. ~1 52!~.!39 5250.53 PAGE 6 DATE DF SJRVEY: 26 4dR ~5 KELLY ~USHiNG ELEVATZON: 67.00 ENGINEER: DEDDEL FSL, SURFACE ' OCaTiON &T 354' =EL, SEC 29, T13N, R93, RECTANGULAR COORDINATES NGRTH/SCUTH EAST/WEST 37:9.96 S 2960.85 W 380.37 S 2964.B5 W .3B2.11 S 29~1.$3 W 392.66 '~ 307'~.00 W 3'~6.2:~ S 3111.55 W UM A~CO ~L~SKB, I~C. 3N-5 KUPARUK NDRTH SLDPE,AL~SK& M& RKER TOP BASE TOP BASE PBTD TD KUPARUK - KUP~RUK C KU~ ARUK ~ KUPARUK ~ CJMPUTaTiDN D,&T~: STR~TiGRAPHZC '4~'ASdR ED D=°TH 7Z55 7'"52~ . O0 7~33o00 74.9,.2°00 P~GE 7 DATZ gF SU,-~VE'¥: 25 ;'4~1R 85 KELLY 3USHING ELEVATION: 57.00 FT~ ENG',-~i,uF.R: o~ooFt ;~R!GiN= 156p' F-SL, TVJ F~,Oq Ki~ S35-SE~ SURFACE LSCATION SEC 29, T13N, TANGULA( COOROIN~TES RTH/S~UTq E&ST/WEST 61a9.~0 50Bl.~O 5!54.34 6037.34 6172.81 5105.~1 5231.0~ 52!4.09 379.96 S 2950.85 W 350.37 S 2954.88 W 3~2.1! S 2951.53 W 392,65 S 3079.03 W 3'~6.29 S 3111.56 W 404,64 S 31~5.53 W R93, UM FINAL ~EASURED DEPTH 7595.00 WELL LOZ~TI3~ TRUE VERTICAL D-PTH 5~01,57 &T T3: SJ~-SE~ V~nTZS~L DEPTH 5334.57 qON~iZONT~L 3E~TUEE DiSTaNCi &ZIMUT~ 32!2.2! S ~2 4~ SCHLUMBEROER , ~ 0 1 RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3N-S F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 26 - MAR - 86 REFERENCE 000071986 WELL 3N-5 (1562'FSL, 354'FEL, S29, T13N, R9E) HORIZONTAL PROJECTION NORTH 4000 REF 00007! 38S SCALE = ]/1000 IN/FT 3000 gooo ! ooo - I ooo -MOOO -3000 SEXJTH -4000 -SO00 WEST -4000 -9000 -2000 -1ooo o ]000 2000 3000 EAST WELL 3N-5 (15.62'FSL, 354'FEL, S29, T13N, R9E)' VERTICAL PROJECTION SOUTH -4000 -9000 -2000 -1000 0 0 !000 ~>000 3000 4000 NORTH '"i"'i'"'i'"i'"'i'"~'"!'"+'--?-" . ...... !----i.++++++.-+ i i f i i i i {--..i ....... !...;...¢--.~. -~.-.g.-~ .... i ....... ~..+..%+..~....!,..~...~..~ ....... ?"'!'"'i'"t-'~-"t"t"t"t" ......... ........ ~ .......... . ....... · ....... ?--?--.r--?---?...?---~ ....... ~--.~.-.6--+.-+.-+.-.i---~--+.. '~ .... i ~li!~'""~'"'7'"Y"'~'"~'"~'"?'"?'"f .... T"?'"?'"?'?'"?'"?'"~ ....... .... :::::::::::::::::::::::::::::::::::::: · ..~...~...~...~-.~....i...~....~...~ ....... i.-~....~--~.~.~..-~...~.,.~....~ .... i.~..?...i._~.,.+..6..~..6...? .... -..~:::[:!:';:;;:;~;:.!:;;.i' .. "~'+'"~'"'~" '!''''~' ~'': ' -.-;-...P-.-!---.~..-I ..;-4--.; ....... [ "? ? ~ ?" ? /"'~'r'?'"~'"?"'?"~"~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .. . ...... ~7~,:~ ....... :::' '"'~'"-h'?"~---{---~'-'? .... · ..6.-!--.6..~+-.6..i--~ .... . .... -..~..?..-~-..?...~-.--i.--.i....~.--?.. "t'-+'"-i'-+"f"?-~'-'!"'-~ }"+'-?--'t"-j'-'~'-'?"t'"i ......... ~...~-g...l...,~...J...;...,~... :. .,: ~ ~~'~ · -.i....i-.-i--6.!---h?--..i-.-i--. ?~: .-.~....L.~...LL.L.~...-L..i.. ?"?'+"t"t"t"t"+"-? .... pl .... ....?...¢...L.L .::,...?.,... L~ m ..... . ~ ~ { . . .... ~'--?-" .~-";--'+--";'"?---~'"-h- ' ' : ' : : · : , ..... . . . .... ~....u..:....L...~...¢...¢....~...~..~ : ?.._}...?...? ~ ~ : · ' : : , : · : : . . , HORIZ SCALE = 1/1000 IN/FT PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN VERTICAL DEPTHS WEL. L 3N-5 (1562'.FSL, 354'FEL, S29, T13N, R9E) VERTICAL PROJECTION PROJECTION ON VERTICAL PLANE 26S. - 8S. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT EXACT RADIUS OF CURVATURE METHOD TIE-IN LOCATION MEASURED DEPTH O. 0 FT TRUE VERTICAL DEPTH 0.0 FT OI STANCE NORTH 0.0 FT DISTANCE EAST 0.0 FT BOTTOM HOLE COURSE LENOTH COURSE AZIMUTH LOCAT I ON MEASURED DEPTH TRUE VERTICAL DEPTH OISTANCE SOUTH DISTANCE WEST 9212.0 FT 262,8 OEO ?S9S.0 FT 6401.? FT 404.5 FT 9186.4 FT REF 000071986 Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR,-WEI/L NAME AND NUMBER Reports and Materials to be received by Required Date Received Remarks Completion Report Well History y~ Samples Hud Log Core Chips .~~~ .... Core Description {/l~ Registered Survey Plat ~~t~o~ Survey , , Dlrectlonal Survey L ....... C_.~ ~ C/ r ,, . Production Test Reports , , - . . . . . ARCO Alaska, In~ .... Post Office ,.,,,x 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. Schl/ OH LIS Tape plus Listing One of each 3N-5 02-21-86 Run #1 0187.5-7614.5 DATE 03-11-86 TRANSMITTAL # 5593 Please acknowledge receipt and Receipt Acknowledged: ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA C_ AND GAS CONSERVATION CO¢,,MISSION ,ONTHLY REPORT OF DRILLING AND'WORKOVER OPERATIONS .% ~. Drilling well ~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-26 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21537 9. Unit or Lease Name 1562' FSL, 354' FEL, Sec.29, T13N, R9E, UN (approx.) Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 67 ' RKB 6. Lease Designation and Serial No. ADL 25521 ALK 2557 10. Well No. 3N-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of February , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ¢ 0300 hfs, 2/16/86. Drld 12-1/4" hole to 3785'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7595'TD (2/20/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7482'. Secured well & RR ~ 1000 hfs, 2/22/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 115'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3764'. Cmtd w/lO70 sx PF "E" & 290 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7569' . Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/7595' - 3764'; GR to surface FDC/CNL f/7595' - 6986' Cal f/7595' - 6180' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE- Report on~lnis form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR45 Submit in duplicate ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3N Pad (Wells 1- 18) 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, · Gruber Associate Engineer JG/tw GRU13/L45 Enclosure If RECEIVED ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ¢' ,, LOCATED IN PROTRACTED. LOCATED IN PROTRACTED SEC. 29, TI3N~ R9E~ U.M. SEC. 29~TI3N~R9E~ U.M. I - Y ' 6,013,799.67 LAT. 70°26'55.9615" 10 - Y = 6,013,799.37 LAT. 70o26'55.9519'' X ' 517,946.19 LONG. 149°51'12.938" X ' 518,221.07 LONG.149o51'04.865" 454' FEL, 1562' FSL OG · 28.2 PAD - 33.7 179' FEL, 1561' FSL OG 2 - Y ' 6,013,799.65 LAT. 70026'55.9606" 11 - Y = 6,013,799.32 LAT. 70°26'55.9508" X ' 517,971.21 LONG. 149°51'12.203" X - 518,246.03 LONG. 149°51'04.132" 429' FEL, 1562' FSL 0G = 28.2 PAD = 33.8 155' FEL, !561' FSL 0G 3 - Y ~ 6,013,799.54 LAT. 70026'55.9590" 12 - Y = 6,013,799.45 LAT. 70°26'55.9515'' X ~ 517,996.25 LDNG.149~51'11.468" X = 518,270.89 LONG.!49°51'03.403" 404' FEC, 1562' FSL OG - 28.4 PAD = 33.9 130' FEL, 1561' FSL DG ' 28.5 PAD " 34.0 4 - Y ' 6,013,799.50 LAT. 70026'55.9580" 13 - Y = 6,013,799.4~ LAT. 70°26'55.9505" X ' 518,021.16 LONG. 149°51'10.736" X = 518,295.97 LONG. 149o51'02.666" 379' FEL, 1562' FSL 0G = 28.4 PAD = 33.7 ~ 105' FEL, 1561' FSL OG · 28.5 PAD ' 34.1 '5 y - 6,013,799.~ LAT. 70~26'55.9572" - .~ 14 - Y - 6,013,799.33 LAT. 70°26'55.9491" X ' 518,046.18 LONG.149°51'10.O02" ~ X = 518,320.91 L~G.149°51'01.934" 354' FEL, 1562' FSL 0G = 28.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL OG ' 28.5 PAD ' 34.0 O 6 - Y = 6,013,799.44 LAT 70°26'55.9562" ~O O 15 - Y = 6,013,799.28 LAT. 70026'55.9480" X ' 518,071.24 LONG. 149°51'09. 266" ~ X = 518,345.77 LONG. 149°51'01.204" 329' FEL, 1562' FSL 0G = 28.5 PAD = 33.9 ~ ~0 ~ o ~ ~ 55' FEL, 1561 FSL 0G - 28.5 PAD = 34.0 7 - Y = 6,013,799.44 LAT. 70026'55.9556" ~ ~ o ~ 16 - Y = 6,013.799.25 LAT. 70°26'55.9471.' X = 518,096.21 LONG'149°51' 08' 533" ~ O ~ ~o X = 518,370.74 LONG.149o51'00.470" ~ m 30' FEL 1561' FSL OG = 28.5 PAD = 34.1 304' FEL, 1561' FSL OG = 28,5 PAD : 33.9 ~ ~ ~ , Y : 6,013,799.45 LAT. 70°26'55.9551" Y = 6,013,799.26 LAT. 70026'55.9466" 8 17 X = 518,121.15 LONG. 149°51'07.800'' ~ X = 518,395.63 LONG. 149~50' 59. 739 279' FEL, 1561' FSL 0G = 28.6 PAD : 33.9 ~ ~ ~ 5' FEL, 1561' FSL 0G : 28.5 PAD = 34.1 9 - y : 6,013,799.42 LAT. 70026'55.9542" X : 518,146.15 LONG. 149°51'07.066" ~ SEC. 28,Tt3N, RgE, U.B. 254' FEL, 1561' FSL 0G : 28.6 PAD = 34.0 ~ 18 - Y = 6,013,799.15 LAT. 70o26'55.9449" X = 518,420.80 LONG. 149°50'59.000'' NOTES zo' FWL, 1561' FSL 0G = 28.5 PAD = 34.0 I. ALL COORDINATES ARE A.S.P.,ZONE4. 2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD ~ ASSOC. 4. VERTICAL POSITIONS BASED ON MODULE PILES 3JOI-8 ~ 3JOI-4. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3090 rev.~. m m , ) CERTIFICATE OF SURVEYOR: , .E~EBY CERT~KY THAT I AM ~O~ERLY .... ~..' ' ~ ~E CO~ECT AS OF 4 JAN 86. ~ ~ .... ~ ' :- ~' I ~ ~ .... r~ r~- ~ A~UU AIOSKO. Inc. tJUI ~ ~w~ w. DRILL SITE 3N CONDUCTOR ~~, , ~.~ ~oo~e e~ AS-BUILT LOCATIONS ............................. 1)o~. No. ~s~ ~s-~ m~ ~o~E~s~o~u~ 5335 Arct/c Boutevarq. Suite 201 Ant,borage, ;la,s~a ~5J'3 ~isc~E NOT TO SCALE i i ii January 30, 1986 Mr. Jeffrey B. Kewin Regional Drilling Engineer AP, CO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 TELECOPY NO. 276-7542 Re: Kuparuk River Unit 3N-5 ARCO Alaska, Inc. Permit No. 86-26. Sur. Loc. 1562'FSL, 354'FEL, Sec.29, T13N, R9E, UM. Btmhole Loc. 1302'FSL, 1618'FWL, Sec.29, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify 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. Where 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. Ve~y~t~ly yours, C. V. Chatterton' Chairman of Alaska Oil and Gas Conservation Commission BY OP~DER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Posi Office ~,~× 100360 Anchorage, A~aska 99510-0360 Telephone 907 276 1215 January 22, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3N-5 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill 3N-5, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on February 8, 1986. any questions, please call me at 263-4970. ?S~cerel y, "//0] g~ Kewin Region21 Drilling Engineer JBK/LWK/tw PD/L209 Enclosures If you have RECEIVED JAN 2 z~ 1(386 u. ~, ~s Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -' ALASKA,JiL AND GAS CONSERVATION C~ .,IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE ~ MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 RECEIVED 4. Location of well at surface 1562' FSL, 354' FEL, Sec.29, T13N, R9E, UN (Approx.) At top of proposed producing interval JAN 2 4 1986 1321' FSL, 1864' FWL, Sec.29, T13N, R9E, UM At total depth AJ~I(~ 0il & Gas Cons. 1302' FSL, 1618' FWL, Sec.29, T13N, R9E, UM Anchorage 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 67', PAD 33' ADL 25521 ALK 2557 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 354 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7674' MD, 6389' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2253 feet. MAXIMUM HOLE ANGLE 45 oI (see 20 AAC 25.035 (c) (2) 9. Unit or lease name Kuparuk River Unit 10. Well number 3N-5 "~.~ld and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 3N-4 well ~ surface ~j' feet 18. Approximate spud date 2/8/86 2801 psig@. 80°F Surface psig@ 6247 ft. TD (TVD) 3216 21 Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Casing Weight Length MD TOP TVD (include stage data) SIZE Hole 24" 12-1/4" 8-1/2" 16" 9-5/8" 71' 62.5# 36.0# 26.0# Grade Coupling H-40 ] Weld 1-55/HF-EI~W BTC -55/HF-EI N BTC 80' 3709' 7640 ' 35' 35' I 35' 35' 34 i I 34' MD BOTTOM TVD 115i 115' 37441 3597' 7674~ 6389' + 200 cf 1070 sx PF "E" & 290 sx PF C1 ass "G" 300 sx Class "G" neat 22. Describeproposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7674'MD(6389' 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 2801 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. 3N-5 will be 25' away from 3N-4 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereb~ that the foregoing is true and correct to the best of my knowledge / / - . SIGNED ~' //~~~ ~,-~,-~,~' ~ ' TITLE The spa ~o~d ~ Regional Drilling Engineer DATE//~-' CONDITIONS OF APPROVAL Samples required Mud log required I--lYES ~NO I--lYES ,~NO Permit number Approval date Form PD/PD209 10~01 (LWK) Rev. 7~1-80 Directional Survey required ] APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE T by order of the Commission Submit in triplicate PERMIT TO DRILL 3N-5 (oont'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 the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JAN 2 4 1986 Oil & Gas Guns. ~,~mmt~ion Anchorage j 'ALASKA;" ;INC' ............ i]]'-' .............. /I~ ..... J ~N, WELL NO, 5 F .)POSED JPARUK FIELD, NORTH SLOPE, ALASKA EASTMAN WHIPSTOCK., INC. RECEIVED ~ 1000_ 2000 _ SURFACE ...... BASE PERMAFROST TVD=1717 JAN 2 4 1986 Alaska Oil & Gas Cons. Commission Anchorage 7000 . . 0 1000 2000 VERTICAL .SECTION TARGET CNTR B/ KUP SNDS TD (LO~ PT) TVD=6156 TMD=7340 DEP=3088 TVD=6247 TMD=7474 DEP=3178 TVD=6389 TMD=7674 DEP=3318 I 3000 4000 KOP TVD=2253 TMD=2253 DEP=O 3 TOP UGNU SNDS TVD=2462 TMD=2462 DEP=ll . 9 .U[LD ~ ~ ~.'I;~1 PER 100 FT :3000_ X 27, TOp W SAK SNDS TVD=3147 T!'ID=3183 DER=222 'k~, 33 K-1 2 TVD=3397 TMD=3480 DEP=381 ; . --%,./,39 EOC (9 5/8" CSG PT) ?.~ TVD=3597 TMD=3744 DEP=553 4000 ...... ~ ~ AVERAGE ANGLE ,. 5000 , TVD=5357 T1'1D=6221 DEP=2296 ~ T/ ZONE D TVD=6027 TMD=7164 DEP=2960 6000 ............. '"'-' T/ ZONE C TVD=6065 TMD=721S DEP=2997 ' '~,,,.'-T/ ZONE A TVD=6140 TMD=7323 DEP=3072 HOR I ZONT AL PROJECT I ON SCALE 1 IN. = 1000 FEET ARCO ALASKA, INC. PAD 3N. WELL NO, 5 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA EASTMAN WHIPSTOOK. INO. 21> TARGET CENTER TVD=6156 THD=?346 DEP-$088 SOUTH 242 WEST 30?8 TARGET LOCATION, 1320' FSL. 1848' FWL SEC, 29, TI3N. RgE 2000 1000 0 lOG0 4000 3000 WEST-EAST 2000 1 000 I I ~SURFACE ! 1000 I SURFACE LOCAT[ ON' 1562' FSL. 354' FEL SEC. 29. T13N. RgE TD LOCAT I ON' 1302' FSL, 1618' FWL SEC. 29, T13N. RgE S 85 DEG 30 MI N W 3088' (TO TARGET) 8O0 · . I 800..~ 700 _ 600 _ - 400 _ :300 _ 200 _ TO0 : 600 I %?.ooo~ · / J / 2000 / / / / / 1500 I I 700 600 · 800 500 I 400 300 200 .... I .... I .... ' ..... I . . ....%-,1500 500 ''~ I I I 3O, O0 ,1 O0 5OO i 3000 ! i I I I 500 I I I I I 4OO I i J 300 200 100 I@ .. i 100 8 2 KUPARUK RIVER UNIT 20" DI VE~TER SCHEMAT I C .. ., DE S CR I PT ! ON i. '1'6' C~CTOR. 2. TANi,(O STARTER t-~AD. 3. TAI',,I<OSAVER SUB. 4. TAI'~O LOhER COICK-CCt,,I~CT ASSY. 5. TAI',a<O UPPER COICK-COAt~CT ASSY. 6. 2_0' 2ex:x3 PSI DRILLING SPOOL W/I O" OUTLETS. , T. I0' HCR BALL VA~_VE,~ W/lO' DIVERTER LINI~,o V'ALVE~ OPEN AUTOMATICALLY UPON CLOSURE CF A~AR PREVENTER. 8. 20' 2CX:X:) PSI AI~IJLAR PREVENTER. MAINTENANCE & OPERAT:[ON I. UPON INITIAL INSTALLATION~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPEI~_.D PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOORS. CLOSE A~LAR PREVENTER IN THE EVENT'THAT AN II,FLUX OF ~ELLB~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANtJALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACH]: EVE DO NOT SHUT IN ¥~LL UF, OER ANY CIRCUN~TANCES. RECEIVED JAN 2 4 ,Alaska Oil &.Gas Cons. Gommi~S~sionm~.,¢~ 7 ..... DIAGRAM #1 1~-5/ 5000 PSI RSRRA BCP STA~ 1. 16' - 2000 PSI TANKCO STARTING I-.E. AD 2. II' - 3,000 PSI CASING t-.F_AD 3. I1' - 3000 PSI X I;3-5,/8" - ~ PSI SPACI~ SPOCL 4. 1~8' - ~ ~ P~ ~ 5. 1~8' - ~ ~I ~I~I~ ~ W/~ ~ KI~ LI~ 7. 1~8' - ~ ~I ~ 6 5 2 ACQ.MJLATOR CAPACITY TEST I. cH~Q< AN3 FILL' A~TCR RE,,qD~OIR TO'PRCPER LEVEL WITH HYDRAULIC FLUID. 2. A~ THAT A(X:~TCR PR~~ IS ~ PSI WITN 1500 PSI [X~TRF_AM CF T~E REGU_ATCR. 3. CEkSERVE TItlE, T]-F_N CLOSE ALL UNITS SINEJLTAhEOLSl. Y AAD RECCRD T]-E TI~E AAD F:~ RE}F, AINING AF~'F_R ALL UNITS ARE CLOSED WITH C:-LARGING PLIvP CFF. 4. REC~ ON NADC REPCRT, THE ACCEPTABLE LOAER LIMIT IS 45 SECC~ CLOSING TIIVE AhD 12.O0 PSI RE]WAINING PRES,~. 13-5/8" BOP STACK TEST I. FILL BOP STACK AhD C~ MANIFCLD WITH ARCTIC DIESEL. 2. (~CK THAT ALL LOCX ~ SCREI~ IN ~E:LLPF_AD ARE FI/_LY R~a-TRAC'TED. SEAT TEST PLUG IN ~EI.I.PF_AD WITN RUNNING J~' ~ RLIN IN LO(~ S(~. CLOSE Ah~ PI~-VENTER AAD MANUAL K~ILL A~D CNCKE LIN5 VALVES ADJACEAff TO BCP STACK, ALL OT~:R VALVES AND (~ SNOJ_D BE OPEN. 4. PRES,~ UP TO 250 PSI A~D HOLD FOR I0 MIN. IN- ~ PRES,~ TO 3000 PSI A~ HCLD FOR I0 MIN. BLOWn PRES~ TO 0 PSI. 5. C~ Ah~ PREVENTER Aha) MANUAL KILL AAD CHCKE LIN5 VALVES. CLOSE TOP PIPE RAMS AND HOR VALVES CN KILL AND CHO<E LINES. G. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. 7. CCt~TI~ TESTING ALL VALVES, LINES, AND CNCKES WITH A 250 PSI LCd/ AhD 3000 PSI NIGH. TEST AS IN STEP 4. DO NQT PRE~ TEST ANY ~ TNAT IS _NOT A FULL CLOS:[NO POSITIVE SE. AL ~ O~LY FU~ICN ~E$7 CNC~S THAI DO NO'[ FLLLY CLOSE. 8. OPEN TOP PIPE RAMS AAD CLOSE BOTTCM PIPE RA~. TEST BOTTO~ PIPE RAMS TO 250 PSI A~D 3000 PSI. 9. OPEN BOTTO~ PIPE RAMS, BACK OUT RUNNING JT AAD .~0. CLOSE BLINO RAMS AAD TEST TO 250 PSI A~D .3000 PSI. II. C~ BLIhD RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFCLD AhD LINES ARE FIJLL. CF NON-FREEZING. FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL' PIPE SAFETY VALVE, AND INSIDE BOP TO 2._50 PSI AND 3000 PSI. 13. RE(X]RD TEST ]hFC~TICN C/~ BLOHCE3T ~ TEST FC~, SIGN, AND SEND TO DRILLING SUPERVISDR. 14. PERF(~ CC~ETE BCF~ TEST AF~ NIPPLING LP A~D WEEKLY TNEREAFTER FI~ICNALLY C~TE BOM5 DAILY. RECEIV[D Alaska Oil & Gas Cons. Commis:~io~-,,. 5100~4001 REV. 2 Fee LIST FOR NEW, WELL PERMITS ompany, APPROVE DATE . :, ,... '~K /-ZT'Sd 1 Is the permit fee attached _ thru 8) (13 thru 21) (22 thru 26) '.REMARKS (6) Add: 2. Is well to be located in a de poo .............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance, from other wells .................... 5, Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is' wellbore plat included ................ 7. Is operator the only affected party ......... ........................ 8. Can permit' be approved before ten-day wait .......................... - Does operator have a bond in force Is a conservation order needed ' - ' Is administrative approval needed .................................... Is the lease number appropriate ..................................... 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 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 diverter and BOP equipment attached ....... Does BOPE ha~e sufficient pressure rating - Test to ~i~OOO psig .. Does the choke manifold comply w/API RP-53 (Feb.78).., ............... Is the presence of H2S gas probable ................................. Additional requirements ............................................. /~ o H o cn ,--] Geology: JAL Engi, D.eering: LCS MTM ~~HJH . . ~. ~ rev: 03/13/85 6.011 INITI'AL 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. RECEIVED ! 0 () 0 000 c) 00 CA~g O 00 000 000 000 00 0 0 O0 000 000 OOO 00 0 SIZE 018 004 014 002 004 002 012 006 003 001 COUg 065 065 065 o05 o65 065 o65 065 055 C t:t D E O65 -o.o 3 ~,~., ~ t:~H.',t'; : 2.'038 ~ 136 DF ENTF~ Y B I.,OCF. $ 51 ). 0 1 ~0 o .OE p~l ~PHI SP SP R h 0 sp ,~pH I OEPI: SP SO (; ,r!:, ? 1. CAP]' G/C3 CP~3 C GAP;) A F.,' t ,:< [:.': I h !:': IF' J' L, t" U :' u U (..; (" U 220 J, 2 {..) 4 6 9 v 120 44 O 0 ! () U 1 31 O 01 u 280 : 0 1 O 0 '~ 5 (': 4, 2 u o I 0 O C, C~ O0 ~ 9 (; 00 <;, 0 33O 3t0 01 0 0'0391 1 ~ 00000000000000 t 68 O000::OOO:OOOO000 1 68 0000()000000000 168 OO' I 68 oooooooooooooo I 68 o:00o000:0000000 1. 6~ 00000000000000 ! 6800,0'00 .o:oo : 543'1 I 1(:)~' ' ,3398 CALl 3,5179 Rt,.~R h 554,8t25 GR I. Ob. 3398 CaLl 3,5178 554,~125 ~,6414 8.5020 3,4182 '999,2500 4,6492 ~182 -999,2500 ,31 72 lbx 3 5432 10 ,71~8 C~LI ~ 2676 3,65o5 K:',.Ri 3 4202 6~2,3],2B GR -999 2500 9,2988 2.02. 7 3 C 2.8987 gr+(t,3125 Gq 15.8223 lb~ 73.0273 CAL, I 2.9827 XS/ka 8'!6.3125 GR 2,5Ob'J. 1. 27,71'7 3 C .:i,5428 R:'!R A 528.8125 ! . 'I 42 2 I b :': 9.1910 8, 613 2,7424 -g99,2500 lO,723~ 8,298U 2.8381 -999,2500 2 5315 8:92 8 3,4983 -999.2500 S p :",1P ;'~ t SP NPH I DEPT NPH! D~PT ~q P i'~ T RHOr, DEP~ Sp ~PHI SP R ri U ~.~ NPHJ OEPT SP SP 1 72 , 1875 G R .,99F~ .2500 ~*~RA T -9 9'4.2 5 {'.: C, I=Cal 2.2522 144,5625 -999. 2500 F'Ci';!L 1,788! -999.2500 2,1 o 1, q i L 1 i i,7t4L, G~) l!r,gbiFi:~ CALl 4'79.6 :'~06 G~ 8,6660 ].;i7t51 -999,2500 2.5237 JLa 125. 152.3 CA~I 3,5{.567 5 i 3 ' 812 5 G 3 :7 *999 0 200 ~999 2,500 -999.2500 8848 8,, 0 ~:9:9:9,~:50. '999,,.500 -999 -999 9 768 i b f,~ ~ 1.87'5 CALl 9 P, i', R g 999 G:R '999 4 O0 17 ,1875 CALl. 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C, SP -25'57.i2 Il* DLPT SP RHOL N P t":: I O g P T SP -24,57 32 Gi) -99°. 25 ~.:,,,, l~ ¢: ;~ ~ ~ - q 9 w. 25 t',: ;} ri {:: :, ;., 2,2288 9 ;3066 -999,2500 '999.2500 '999,2500 -999,2500 -999,2500 GR -999 2,6702 130'8125 -999.2500 -999,2500 ~R 2 6¢77 2500 -qO9,. -~q9,2500 GR 2,77'76 -999,2500 iIa~12 Ib~~ 9R.4648 CALl -999.250{1 R,~RA -999.2500 GR 2,8928 '999,2500 -~99,2500 2, ~ 362 1 98.9023 CALl -999.2509 . 2,7403 999 '999'2500 2, '5 5 3 0 -99'9,2500 -999,~.~00 -'999, O0 2.9495 -999,i1500 -999.2500 -999.2500 2,8147 -999i2500 -999 2500 5 0359 -999~2500 -999.2500 -999,2500 2,9143 -999.2500 -999,2500 -999,2500 2,8889 -999.2500 -999.2500 '999,2500 L~ ,250:') G~' -999: 2500 2 iL '~ 6272 -999 5 0 R ~ 9 ,2500 ~999 ,2500: 89 7 C b 9 -999 250o G~ -9 ;00 O0 3,2893 -999, -999, -999 2.89b'7 90.5273 -999 iO0 '999 ,00 lb~ CAbi 2 ti264 -999 2500 -999 2500 -999 2500 DKPT 4300, RgOh -999,25(/o 3.1155 lbo ].601~ -999,2500 -999.25U0 CALl, ~,4690 '999,2500 -999.2500 -999.2500 2.9651 i01.1623 -99q.250~ 2756 101~!523 -999.250U -999.2500 CALl R ':,iR A. -999,2500 -999,2500 -999.2500 9 ,i. 7 '/'? 3 -999. 2500 3.6~84 94.7773 -999.2500 -999.2500 CALl RmRA 3,b155 -999,2506 '999'Z500 -999,2500 1.S(:.,77 :ILL, 93.0~9F G~ -999.250u FC~L 2.57u4 93.0~98 -999.2500 -999.2500 I L N CAbI 2 4377 -999:2500 -999.2500 -999,2500 2.5 b t) <:: 1 [, ::; 3,0237 97. 652 .t -999.2500 Ib~ C A b I R ;,~ R A 2.9221 '999,2500 '999,2500 4, 'l 4 e:, ~, I L; .0 ,- '9 9 9 ,, ~ 5 0 (i I [.., -.999.250:0 ' 9 99,2500 :~,' R A T ,.,999.25 .,.9 ~ DEPT SP O E P I' SP D£PT - q '.{ 9 O~Pl' S? 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NPH 1 SP sp oap'r SP '999.2500 '99q. 25U{' '999. 2500 SP -9~9.250o GR -999,2500 99 '.3398 CAb1 -999 '999, 9'9 ~ ~: :9:99 ,:2500 I '999 ,:,~":5 O: 0 999,250V CAbI -999;2500 '999 ~ 25:0 ::{ h~ :': "~'~ 9:9'9 ~ 2500 -999,25oo G~ 55.9492 -999,2b00 Ik,{4 -999 2 0 '999; 2500 Cliff -999 -999, ~500 aaaa ~999~2500 GR 61 '999.25:00 lt~ '999 '999,2500 CALl '999 -999. 2500 Ga 57 ,2509 ~8~67 -999,2500 Ri~R~ -999 -999~2500 GR 59 -99g,2500 II..,~ -999,2500 -99 ,2500 CALl -999,2500 -999,2500 RNRA -999,2500 -qgg.25{)O GR 48.0430 -999,250o 1[.,~ -999,2500 -999.25uo Chbi -999,25U0 Z999 2~00 eaRA -999,2500 999:2500 [;~ 56.7305 :999,2bO0 iLt'* '999,2500 999.25vo (;'At,;[ -999.250,6 -999.2500 RaRA -999,2500 -999.2500 Ga 4?.7305 -9~9.2500 ib~i -999.2500 -999.2500 CALl -999,2500 OEPT' SP R ~iOt4 SP ~!PH1 SP NPHI 8P i)~3P T SP SP aPHI OEPT Rdbi~ D tj:P q' NPM1 - 999.25 0 :) ,'.., C % -999.2500 : .... ,2=0~' Iba -9:99,2500 -999.2500 Cabz -999 ,2500 ~999',2500 R~}:RA : "9:99,250:0 -999,250o G~ 42 4 80 .~50:OCAbl '999 500 '999,2500 g{'!RA '9992500 -9:99i.2:500 GR 36,:~305 ..9.),250( CALl -999.250c~ GR ::99:9,-: 2:5:0:0 999;2500 '9'9:9 i.:2500 35,5430 "999,2b0¢ -999 999 25(~{., lb~ -999 ~ 50'{ C.A'b I '-99g 2500 R~R~ -999 ,2500 ~ 50 ,2500 ;2500 '9979 .~500 2500 ,2305 -999,2500 I.b~ -999 -999,~500 CAbl 999 -999,2~00 R'4RA :999 -999,2500 GR 45 .2500 .2500 .6367 ,2500 ;2500 ,2500 ,0742 -999,2500 -999,250t~ -~99,2500 1L,r,,: -999 99.250o CAbi -999 -c~99,2500 R,uRA '999 -999,2500 GE 47 .2500 2500 '2500 ,2930 2500 '2500 · 2500 :4805 -999.2b{,0 -u99,250G lbi~t :999 -~99o2500 CAt,,l 999 -999.250~ ~,:~ 999 -999.2500 C;R 3b ,2bOO ,2500 .2500 .511.7 -999, 25(...0 '[ I.,t.; -g99.2r~{.,O I -999,2500 : SP ~999,25 0 G.~ CAbI :-99~ RR[3<~ -999,25{;~0 DRt~O -q'gg RNRA -999 ~ PM I -999 ~ 2500 ' G,R 40 .... -t ] lOl},,OOOC, SF'LU -999 2500 iLP -,999,2500 iba R~Or., -9q9.25o{} D~{H~.) -999" ' , , ~5~,~, ~,~R AT -g99,2500 Rt~RA .... ,, ..... L... i~ - 9,/. .... -999;2500 GR DgPl' 700 000~ S~'~.t -99q,25{,0 It..,t: 999,25U0 ilk SP - :~ O':.} ' 25;; ;'~.,., '':. -gga, 25~=(.. .. d;, , :9q9,2500.r' CALl' . R~C,~ -gag,Pbu'",... (:) t:: ;'~ ~ :; -999. .2bit, ~':~ac,, -999.2500 :~PdI. -"::44./~:~:<' :'~C,;L -9':~9 25&'~ f~;;' '99a 25:J~: G 52 3242 -999 -999: -999~2500 27,9111 -999 2500 -999:2500 -999.2500 -999,2500 -999,2500 36,29]0 999,~500 :999. 500 '999,2500 58.3555 -999 2500 -999 2500 -999 2500 45 1680 -999,2b00 -999.250o -999,2b00 22.0830 SP R~OB SP SP O~PT SP -999.2500 -9 r~9.25 (.' :,:, -999.2500 aRA1 -999,2 5 {'} 0 ~ · . 999,.2~ :00 -999,2b00 35;,~805 -~99,:2:5'00 -999,2500 -999~:25:00 52,6992 -99~.2509 ida -999,2500 CAhI' -999,2506 "99:9, '2500: -99 -999 -999, 2i, 2500 6992 2500 25:00 -999,2500 ibm -999.25~0 -999,2500 RNRA -999. 2500 UR -9 -999 )0 -999 14,6582 1¸I
